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186-126
WELL HISTORY FILE COVER PAGE XHVZS This page identifies oversize material and digital information available for this individual Well History file and weather or not it is available in the LaserFiche file. Please insure that it remains as the first page in this file. ~ ~ Well History File # Digital Data Added to LaserFiche File CD's - # Yes No Yes No Yes No DVD's - # Diskettes - # Oversized Material Added to LaserFiche File Maps # Yes No Yes No Yes No Mud Logs # - Other # General Notes or Comments about this file. If any of the information listed above is not available in the LaserFiche file, or if you have any questions or information requests regarding this file, you may contact the Alaska Oil & Gas Conservation Commission to request copies at 279-1433, or email us at: AOGCC_Librarian@admin.state.ak.us • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPL TION REPORT AND LOG 1a. Well Status: oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned G uspended I 1b. Well Class: 20AAC 25.105 ! it l 20AAC 25.11 d Development ❑ 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. or Aband.: November 6, 2010 •186 - 126 / 310 - 335 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 September 23, 1986 ` 50 029 - 21621 - 00 0 0 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 1259' FSL, 317' FWL, Sec. 35, T13N, R9E, UM September 29, 1986 31K Top of Productive Horizon: 8. KB (ft above MSL): 69' RKB 15. Field /Pool(s): 1006' FSL, 1760' FWL, Sec. 34, T13N, R9E, UM GL (ft above MSL): ' AMSL Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): 915' FSL, 1358' FWL, Sec. 34, T13N, R9E, UM 7960' MD / 6507' 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-529306 y- 6008254 Zone-4 8501' MD / 6924' TVD ADL 25519, 25520 TPI: x-525471 y- 6007986 Zone-4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x- 525069 - 6007894 Zone-4 1995' MD / 1988' TVD 2555, 2556 18. Directional Survey: Yes ❑ NoO 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) 1700' MD / 1699' 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 not applicable not applicable 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H -40 Surf. 110' Surf. 110' 24" 1540# Poleset 9.625" 36.0# J -55 Surf. 4244' Surf. 3758' 12.25" 1200 sx AS IV & 300 sx Class G 7" 26.0# J -55 Surf. 8475' Surf. 6903' 8.5" 335 sx Class G & 175 sx ASI 24. Open to production or injection? Yes • ❑. No a 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" 8007' 7818' MD / 6399' TVD perforations plugged 8003' MD / 6540' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. viow n' Nov DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED U � 7916'- 8019' MD 18 bbls 15.8 ppg cement Ifni .T, CA Z- 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 Sidewall Cores Acquired? Yes ❑ No 0 If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. R xx �FC NONE 'Nov 1 6 ?010 A ** 'A & JaIa cons. caortl.^<'.asSion Form 10 -407 Revised 12/2009 CONTINUED ON REVERSE ' ifgnginal only 28. GEOLOGIC MARKERS (List all formations and mawe untered): 29. W FORMATION TESTS NAME MD TVD Well tested? ❑ Yes Q 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 1700' 1699' needed, and submit detailed test information per 20 AAC 25.071. Top Kuparuk C 7856' 6427' Base Kuparuk C 7924' 6479' Top Kuparuk A 8073' 6593' Base Kuparuk A 8242' 6722' N/A Formation at total depth: Kuparuk A 30. LIST OF ATTACHMENTS Summary of Daily Operations, schematic 31. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Ga Her @ 263 - 4172 Printed Nam . C Title: Alaska Wells Manager Signatures Phone 265 -6306 Date f �IU L r 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 1a: 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 • KUP 3K -08 Ci�t" ol:43� hilfi Well Attributes _ - Max Angle 8_MD TI) _ }`i' Welibore APIlUWI Field Name W II Status Incl (') MD (111<13) Act Btm (ftKB) Iii.1Si[Z3 500292162100 _jWPARUK RIVER UNI 1 _ _ PROD_ �45.32� 5, _ 8, 501.0 Comment - HIS (ppm) Date An nrtatnon End Date KB-Grd (f0 Rig Release Date -_-� _ ... .1.,41!.;5,-4fte1��1f21p5,02J9PM SSSV_TRDP Last WO 211fi2008� 4000 9!3011_986 An-tat.. Depth (ftKB) End Date Annotation Last Mod By End Data Last Tag' CTMD 7,9780 1 10/29/2010 Rev Reason GLV C/O Imosbor 11/1 /2010 - .-- - - - - -- - - - -- Casino Strin s HANGER, 35 -! Casing Description String I... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd - - - - - CONDUCTOR 16 15 06 2 38.0 110 0 110 0 62.50 H�0 _ -A, Coring Description String 0... Str- g ID ... Top (itl(B) Sat Dapih (L.. Set Depth IT ... String Wt... String ... String Top ThN �- SURFACE 9 5/8 8 765 37.0 4,244 0 3,757.8 36.00 J - 55 Buttres .., -- -- C sing Description Str ng O. -. String ID ... Top Mal Set Depth (f... Set Depth (TV ... String Wt... String .,. String Tap Thrd CONDUCTOR, ;. d PRODUCTION 7 6.151 31.7 8,475.0 6,9034 26.00 J -55 Buttress 36 -110 Tubing Strings Tubing Description String O_. String ID .._ Top (ftKB) Set Depth (f.. Set Depth (TVD) ... Str ng W1__ Str ,g __ Strinq T p hn1 SSSV, 1,995- TUBI 31 /2 2.992 35.0 8,006.5 6,543.0 93 G L80 LULE 11LMOD C0 In letion Details _.. ' Top Depth (ND) Top Incl Nomi... jj Top (itK6) (ftKB) ( °) Item Description Comm _ ID(in) SURFACE, 35.0 35.0 0.07 HANGER Tubing Hanger 2.992 37-4,246 1,994.9 7,957.5 15.94 SSSV Safety valve, TRMAXX -5E, 3.5" 2.812 INJECTION. 78 ,02.1 6,387 -4 40.58 Locator LOCATOR L 2.950 __.. -.` _ -. 7,750 .. -. 7,802 5 6,387.6 40.58 SEAL ASSY 80-00 seals Overall 12ft ._-- 3.000 _ - B --- - -... 7,804.5 6,389.1 40.58 P- BR - I Baker "PBR" Pollsh Bore Receptacle 2.950 7,817.8 6,3992 40.54 PACKER Baker "FHL" Retrievable Packer 2.950 LOCATOR, - 7,602 - ` 7,989.4 6,530 0 40 OS SLEEVE - O Sliding Sleeve 2.812 BX Profile (OPEN 10112/2009) 2 - 812 SEAL ASSY, 7,602 8,004.5 6,541.5 40.04ILOCATOR Baker" GBH - 22 "Locator w /1'space out 2.420 PER, 7.806 - -. __ ._ PACKER, 7,818 6542.3 40.041SEALASSY 180 - Seals Overall 6.40 It 2.420 �_ _- - T bing Desc ption s" ._ String ID ... Top (ftKB) Set D pth (f... Set Depth (ND) ... String WI... String .. String Top Thrd TUBING- Original 8,002.7 8,031.1) 6,561.8 Completion Details INJECTION, Depth 7,871 (TVD) Top Intl Nomi... To (ftKB) fry Item Desuptlon Commend -. _ ID (in) 8,002 -7 6,5402 40.04 PACKER BAKER D8 PACKER IPERF, ],91E 3 8,019.4 6,552.9 40.05 NIPPLE CAMCO'D'PPLE 2.250 - M SQZ $ 8,029 -4 - 6 - ,560.6 40.05 XO � CROSSOVER 2 718" TO 3.5" TUBING 3.500 7.965 -7.999 $ -.�._ -7-- --- -- -- 8,030.2 6,561.2 40 -05 SOS 2.920 soz,_ 7,965 -7,969 Other 1n Hole ireline retrievable plugs, vatves,pumps, fish, etc.) - Top Depth (TVD) 'Top Intl SLEEVE -O, TOD /ft KB (nK8) ( °) Descrptnon Comment Run Date ID (in) 7.988 8,019.4 6 552.9 _ 40 051 PLUG 2.25" CA - 2 PLUG 10/12/2010 0.000 7,997 -9,001 - CMTSOZ, Perforations & Slots 7,945 Shoi Top (TVD) Btm (ND) Dons Top_ Lf[KI Btm_,(ftKB _ (ftKB) . _(ftKB) ..... Zone _ ` D nd ate (sh -. _ _T'Gpe Comme LOCAT , 7,916 - 0 7,934.0 6,473.8 6,487.5 C - 1, UNIT B, 12!2%1986 12.0 IPERF 120 deg. phasing; 5" Csg Gun SEAL ASSY, 3K - 08 PACKER, 8003 -, - 7,945.0 7,949.0 6,496.0 6,499.0 C -1, - UNIT B, 1011912010 6,0 SOZ 2.5" Millenium HMX 11 5" Hollow 3K-08 Carrier Scallop guns, 60 deg phase 7,965.0 7,969.0 6,511.3 6,514.3 C -1, UNIT B, 10/192010 6.0 SOZ 2.5" Millenium HMX 115" Hollow PLUG. 8,019- 3K-08 Carrier Scallop guns, 60 deg phase NIPPLE, 8,019 _ 7,997.0 $001.0 6,535.8 6,538.8 C -1, UNIT B, 10/192010 6.0 SOZ 2 -5" Millenium HMX 11 5" Hollow k0, 8,029 -- - - 3K -08 Carrier Scallop guns, 60 deg phase sos,8.030- - 8,090.0 8,120.0 6,607.0 6,629 :9�A -3, 3K -08 8!10/2008 8,10 6 -0 RPERF 2.125" ENERJET HMX, fi0 deg phase 8,16 - 0 3. 0 6, 61 6. 1 6, 616.9 l "' -__r._�. TO iRE -.__ .�.__ -. _ _- A -3, 3K -0 8 12!111986 1.0 IPERF 4" Csg Gu_n; 0 deg. phase - 8 107.0 6 619.2 6,620.0 A-3, 3K -OS 12!1/1986 1 0 IPERF 4" Csg Gun; 0 deg. phase IPERF. 8102 -8103 8,110.0' 8 6 6,623.0 A -3, 3K-08 12/1/1986 1 0 WERE 4 Csg Gun; 0 deg. phase RPERF. _ 8, 090 ' - 8 114. 8,115.0 6,625 -3 6,626 1 A-3, 3K-08 1211/1986 1.0 IPERF 4 Csg Gun; O deg. phase e toe sFRp7- 8,130.0 8,185.0 6,637.6 6,679 -6 A -2, 3K -08 &10/2008 6 -0 RP 2.125" ENERJET HMX, 60 deg phase -'° 8,140.01 _ 8,141.0 6 6,646.0 ' X - 2 - ,31(-08 _ _ 12/1/1986 1.0 IPERF 4" Csg Gun; 0 deg. phase IPERF, _ 8,110-8.111 8,144.0 8,145.0 6,648.3 6,649.0 A-2, 3K-08 12/1/1986 1.OIPERF 4 "Csg Gun; O deg. phase IPERF._ 8,114 - 8,115 _- - 8,152.0 8,153.0 6,654.4 6,6552 A- 2,3K -08 1211/1986 1.0 IPERF 4 "Csg Gun; O deg. phase ""' -` 8,156 -0 8,157.0 6,657.5 6,658.2 A -2, 3K -08 - 12/1/1986 1.0 IPERF 4" Csg Gun; 0 deg- phase .. -. _- .. .3 _ - �8,160.0 8,161.0 6,660.5 6,661 A -2, 3K -OS 12/1/1986 F 236 IPERF 4" Csg Gun; 0 deg. phase IPERF, 8,165.0 8,166.0 6,664.3 6,665.1 A -2, 3K -08 12/1/1986 WERE 4" Csg Gun; 0 deg. phase 8,110 -8.141 _ -- 169.0 8,170.0 6,667.4 6,668.2 A - 2, 3K - 08 12/1/1986 IPERF 4" Csg Gun; 0 deg. phase - _ __. �. ._ �..9._ IPERF. - -__ -- 8,16 5 8,175.0 $176.0 6,672.0 6,672.8 A -2, 3K -OS 12/1/1986 IPERF 4" Csg Gun; 0 deg. phase - - -- 8,178.0 8,180.0 - 6 675.7 6,675.8 A -2, 3K -08 - 12/111986 IPERF 4" Csg Gun; 0 deg. phase 8,1s2PS Rsi 8230.0 8,240.0 6,714.0 6 721.7 A -1, 3K OS 8/10/200 RPERF 2.125" ENERJET HMX, 60 deg phase IPERF. . .� _ . ---- _ 8,1568, 157 Notes: General & S _ - RPERF, -- - End Date Annotation 8,130 -8,185 _ _ IPERF, 8/13/2008 NO TE VIEW SCHEMATIC w /Alaska Schematic90REV 6.160 -8.161 __..... _..__- IPERF, __ - 8,165 -8,166 IPERF, _ 8,169 -8,170 - IPERF, - 8,175 -8,176 IPERF, 8,1]8 -8,180 Mandrel Details,,_ APERF, Top Depth Top Port 8,230 -8,240 .:. (TVD) Inc] OD Valve Latch SW TRO Run Sin To B (ftKB) ( °) Ma t4odN _(in) Sere Type Type (in) (psi) Run Dab Com... 6,347.6 40.37 CAMCO MMM 1 1/2 INJ IDMY I RKP 10.0001 0 PRODUCTION, _"' - _`-- �' ""_ . - . 32 - 8,475 2 7,870.8 6,439.4 40.40 CAMCO MMG 1 12 INJ OPEN 0.000 0.0 8,501 3K -08 Well Work Summary DATE SUMMARY 9/4/1'0 LOG SBHP SURVEY: LOG TERESS GRADIENT WHILE RIH, SBHP 1 *' AND 7995'(100' TVD ABOVE SURVEY) PRESSURE AT8125 -4194 PSI TEMP= 108DEGF PRESSURE AT 7995'= 4144PS1 TEMP =111 DEGF 9/16/10 TAGGED @ 8151' SLM, EST. 8164' RKB. GAUGED TBG TO 2.71" TO 8004' RKB. LOGGED PDS CALIPER FROM 8100' SLM TO SURFACE. DRIFTED TBG WITH 18.5'x 2.66" DUMMY WHIPSTOCK TO 8004' RKB. CLOSURE TESTED SSSV, GOOD. COMPLETE. 10/2/10 PERFORMED JEWELRY LOG FROM TAG AT 8170' CORRELATED TO PERFS UP TO 7400'. 10/4/10 MITOA- PASSED (NO VISABLE BH LEAK) 10/12/10 TAGGED @8138' SLM. DRIFTED TBG WITH 10'x 2.5" DD BAILER TO XO @ 7972' SLM. SET 2.25" CA -2 PLUG @ 8019' RKB. CLOSED CMU, P/T TBG 2500 PSI, GOOD. OPENED CMU @ 7989' RKB. IN PROGRESS. 10/13/10 PULLED DV FROM 7871' RKB. COMPLETE. 10/14/10 PRE CTD PT SV, MV,SSV ( PASSED) DDT SV, MV, SSV ( PASSED) DDT SSSV (FAILED) 10/19/10 PERFORATE THE FOLLOWING INTERVALS: 7997 - 8001', 7965- 7969', 7945 - 7949'. RUN 2.5" HOLLOW CARRIER SCALLOPED PERF GUNS LOADED 6SPF, 60DEGREE PHASE, WITH 4" FOOT OF LOAD. HALLIBURTON MILLENNIUM II HMX CHARGES. DEPTH CORRELATED TO HES JEWELY LOG DATED 02 OCTOBER 2010. READY FOR CEMENT SQUEEZE JOB. 10/21/10 PERFORM CEMEN SQZ ACROSS THE C SAND PERFS, LAY IN 18 BBL/15.8 CMT FROM 7916 TO 80 CORRECTED DEPTH,PERFORM 9 HESITATION SQZ TO 2100 WHP,PUSHED APPROX 5 BBL BEHIND PERFS, CIRC OUT REMAIMDER CMT FROM 7900 TO SURFACE W /1310, CHASE BIO W /SW, FP WELL,TRAP 1650 ON WH, RD MOL, 10/24/10 TAGGED TOC @ 7879' SLM WITH 2.5" BAILER.CHART RECORDED MITT PASSED. 10/29/10 MILL CEMENT FROM TAG @ 7928 CORRECTED CTMD TO 7989, MADE 3 PASSED THRU THIS ZONE W/2.98 BI CENTER MILL,POH, FP WELL, READY FOR SL, JOB COMPLETE, 10/30/10 DRIFT BLB AND 2.79" GAUGERING TO TAG @ 7949' SLM.DRIFT CDR -2 DUMMY WHIPSTOCK WITH FLEX COUPLING TO 7943' SLM. PERFORMED MITT ON CEMENT PLUG. PASSED. DRAWDOWN TBG.SET SLIPSTOP CATCHER @ 7763' SLM.PULL 1.5" DV FROM 7750' RKB. EXCERSISE TRMAXX 5E @ 1995' RKB, ABLE TO SEE FLOW TUBE MOVEMENT, AND PERFORMED 15 MIN. NO -FLOW CLOSER TEST. n SET 1.5 DV @ 7750' RKB AND P.T. TBG. TO 2000 PSI.PULLED CATCHER.SET 3' BPV plv) 1 11/5/10 RU and test BOP pump slack and cut Coil rehead CT and PU whipstock 11/6/10 Set whipstock at 7959.6' TOWS, Tagged cement at 7971'. Milled first window run to 7965.2' STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. operations Performed: Abandon n Repair w ell ❑ Plug Perforations ❑ Stimulate ❑ Other WINJ to PROD Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate 17 Re-enter Suspended Well [7 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory ❑ 1 186 -126 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic ❑ Service 17 — 50- 029 - 21621 -00 7. Property Designation; 8. Well Name and Number: ADL 25520 " 3K -08 9. Field /Pool(s): w Kuparuk River Field / Kuparuk Oil Pool 10. Present Well Condition Summary: Total Depth measured 8501 feet Plugs (measured) none true vertical 6924 feet Junk (measured) none Effective Depth measured 8386 feet Packer (measured) 7818 true vertical 6833 feet (true vertucal) 6399 Casing Length Size MD TVD Burst Collapse CONDUCTOR 110 16 110 110 0 0 SURFACE 4244 9.625 4244 3758 0 0 PRODUCTION 8475 7 8475 6903 0 0 AMEIVED Perforation depth: Measured depth: 7916 -7934, 8090 -8120, 8130 -8185, 8230 -8240 NOV 1 0 2010 True Vertical Depth: 6474 -6488, 6607 -6630, 6637 -6680, 6714 -6722 8''`oA Oil & G33 CORL COW,33k Tubing (size, grade, MD, and TVD) 2.875, J -55, 8029 MD, 6561 TVD Anftr3ge Packers & SSSV (type, MD, and TVD) PACKER - BAKER "FHL" RETRIEVABLE PACKER @ 7818 MD and 6399 TVD SSSV - Safety valve, TRMAXX -5E, 3.5" @ 1995 MD and 1988 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure I Tubing Pressure Prior to well operation 400 1 Subsequent to operation 3 3 1067 400 126 13. Attachments 14. Well Class after proposed work: Copies of Logs and Surveys run Exploratory ❑ Development Service ❑ 15. Well Status after work: Oil n Gas [7 WDSPL 17 Daily Report of Well Operations X GSTOR r7. WAG ❑ GASINJ r-1 WINJ r7 SPLUG r 16. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA if C.O. Exempt: 310 -192 Contact Bob Christensen /Darrell Humphrey Printed Name Rob art D. Christensen Title Production Engineering Specialist Signature Phone: 659 -7535 Date 0 ) RBDMS N O V I 0 /7 Form 10 -404 Revised 7/2009 Submit Original Only 3K -08 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary Depressure reservoir due to CDR2 CTD pressure drilling limits. 10/04110 MITOA - Passed 10109/10 lWell put on production I i KU P 3K -08 C OI10C�hillip5 eu Attributes Max Angle & MD TI) Ahi ka IrzC. Wellbore API /UWI Field Name Wall Status Inc, I °) MO (RKB) Act Stm (RKB) 500292162100 KUPARUK RIVER UNIT PROD 45.32 5,000.00 8,501.0 Comment HYS (ppm) nno Date Atation End Data KB2rrd (R) Rig Release Date - SSS WO: Well COnb : - 3K-0B 7 1 V: TRDP Last 2/16 12008 40.00 9/30/1986 mabc Annotation Oeplh (RKB) End Date Annotation Last Mod By End Data Last Tag: CTMD 7,978.0 1029/2010 Rev Reason: GLV C/O Imosbor 11/1/2010 -- - - - - -- - - -- - Casio Strings HANGER, 35 ram Casing Description String 0... String ID ... Top (ItKB) Set Depth (f... Set Depth (TVD) ... String Wt... String String Top Thrill - - - -- - -- - - - CONDUCTOR 16 15.062 38.0 110.0 110.0 62.50 H -40 Casing Description String 0... string to... Top (RKB) Set Depth It Set Depth (TVD) ... String Wt... String... String Top Thrtl SURFACE 9 5/8 8.765 37.0 4,244.0 3,757.8 36.00 J -55 Buttress Casing Description String 0... String ID ... Top (ftl(B) Set Depth (r.. Set Depth (TVD)... String Wt... String ... String Top Thiel cor40uc7oR, PRODUCTION 7 6.151 31.7 8,475.0 6,903.4 26.00 J -55 Buttress 3 &1 R Tubing Strings Tubing Description String 0... String ID ... Top (ftNB) Set Depth ( /... Set Depth (TVD) ... String Wt... String ... String Top Thrtl SSSv, t 9% j TUBING 3 1/2 2.992 35.0 8,006.5 6,543.0 9.30 L -80 EUE8rdABMOD Com letion Details Top Depth ITVD) Top Incl Noml... Top (RKB) (RKB) ( °) Item Description Comment to lin) SURFACE. A 35.0 35.0 -0.07 HANGER Tubing Hanger 2.992 37 -4,244 1,994.9 1,987.5 15.94 SSSV Safety valve, TRMAXX -SE, 35" 2.812 INJECTION, 7,802.1 6,387.4 40.58 LOCATOR Locator 2.950 7,750 7,802.5 6,387.6 40.58 SEAL ASSY 80-40 seals Overall 12 R 3.000 7,804.5 6,389.1 40.58 PBR Baker "PBR" Polish Bore Receptacle 2.950 7,817.8 6,399.21 40.54 PACKER Baker "FHL" Retrievable Packer 2.950 LOCATOR i 7,989.4 6,530.0 40.05 SLEEVE-0 Sliding Sleeve 2.812 BX Profile (OPEN 10/122009) 2.812 SEAL ABBY, _ 7,602 8,004.5 6,541.5 40.04 LOCATOR Baker" GBH - 22" Locator w /1'space out 2.420 PBR, 7,804 PACKER, 7,818 _ - 8,005.5 6,542.3 40.04 SEAL ABBY 80-32 Seals Overall 6.40 R 2.420 Tubing Description String 0... String ID ... Top (RI4B) Set Depth If... Sat Depth (TVD) ... String Wt... String ... Suing Top Third - Original 27/8 8,002.7 8,031.0 6,561.8 Completion Details INJECTION, Top Depth 7,871 (TVO) Top Incl Nomi... Top (RKB) (RKB) (°) Item Description Comment ID (In) 8,002.7 6,540.2 40.04 PACKER BAKER DB PACKER IPERF, 7,91&7,934 8,019.4 6,552.9 40.05 NIPPLE CAMCO'D' NIPPLE 2.250 Soz 8,029.4 6,560.6 40.05 XO CROSSOVER 2 7/8" TO 3.3" TUBING 3.500 7'945 -7'949 8,030.2 6,561.2 40.05 SOS 2.920 7.98.5 - 1969 Other In Hole Wireline retrievable plugs, valves, pumps, fish, etc. Top Depth (TVD) Top Incl SLEEVE -O, Top (RKB) (RKB) ( °) Description Comment Run Dat 7 •8,019.4 6,552.9 40.05 PLUG 2.25" CA -2 PLUG 10/12/20 soz, 7,997 -8,ao1 CMT SOZ, Perforations & Slots 7,945 Shot Top(TVD) Btm (TVD) Dan. Top (RKB) Bt. (RKB) (RKB) (RKB) Zone Data (.h... Type Comment LOCATOR, 7 ,916.0 7,934.0 6,473.8 6,487.5 C -1, UNIT B, 1201986 12.0 IPERF 120 deg. phasing; 5" Csg Gun SEAL ASSY,, 3K -08 PACKER, 8,003 7,945.0 7,949.0 6,496.0 6,499.0 C -1, UNIT B. 10/192010 6.0 SOZ 2.5" Millenium HMX 11 5" Hollow 3K -08 Canter Scallop guru, 60 deg phase 7,965.0 7,969.0 6,511.3 6,514.3 C -1, UNITS. 10/192010 6.0 SOZ 2.5" Millenium HMX 11 5" Hollow PLUG, 8,019 3K -08 Carrier Scallop guns, 60 deg phase NIPPLE, 5.019 7,997.0 8,001.0 6,535.8 6,538.8 G7, UNIT B. 10/192010 6.0 SOZ 2.5" Millenium HMX 11 5" Hollow x0, 8,029 3K -08 Carrier Scallop guru, 60 deg phase SOS.8,030 8,090.0 8,120.0 6,607.0 6,629.9 A-3, 3K -08 8110/2008 6.0 RPERF 2.125" ENERJET HMX, 60 deg phase 8,102.0 8,103.0 6,616.1 6,616.9 A -3, 3K-08 12/1/1986 1.0 IPERF 4" Csg Gun; 0deg. phase 8,106.0 8,107.0 6,619.2 6,620.0 A-3, 3K-08 12/1/1986 1.0 IPERF 4" CS9 Gun; 0deg. phase IPERF 8,10IPERF , 8,110.0 8,111.0 6,622.3 6,623.0 A -0, 3K-08 1211/1986 1.0 IPERF V' Csg Gun; 0 d ph ase P g ggpg Rp 8,114.0 8,115.0 6,625.3 6,626.1 A -0, 3K-08 12/1/1986 1.0 IPERF 4" CSg Gun; 0 deg. phase 8,1o IPERF. 7 8,130.0 8,185.0 6,637.6 6,679.6 A -2, 3K-08 8/10/2008 6.0 RPERF 2.125" ENERJET HMX, 60 deg phase IPERF, 6,140.0 8,141.0 6,645.2 6,646.0 A -2, 3K-08 12/1/1986 1.0 IPERF 4" Csg Gun; 0 deg. phase 8,110-8.111 8,144.0 8,145.0 6,648.3 6,649.0 A -2, 3K-08 12/1/1986 1.0 IPERF 4" Csg Gun; 0 deg. phase IPERF, 6 ,152.0 8,153.0 6,654.4 6,655.2 A -2, 3K-08 1211/1986 1.0 IPERF 4" Csg Gun; 0 deg. phase 8,1148,175 8,156.0 8,157.0 6,657.5 6,658.2 A -2, 3K-08 1211/1986 1.0 IPERF 4" Csg Gun; 0 deg. phase 8,160.0 8,161.0 6,660.5 6,661.3 A -2, 3K-08 121111986 1.0 IPERF 4" CS9 Gun; 0 deg. phase IPERF, 8,165.0 8,166.0 6,664.3 6,665.1 A -2, 3K-08 12/1/1986 1.0 IPERF 4" Csg Gun; 0 deg. phase 8'14°-8'141 8,169.0 8,170.0 6,667.4 6,668.2 A -2, 3K-08 1211/1986 1.0 IPERF 4" Csg Gun; 0 deg. phase IPERF, 8,175.0 8,176.0 6,672.0 6,672.8 A -2, 3K-08 12/1/1986 1.0 IPERF 4" Csg Gun; 0 deg. phase 8.144 -8,145 8,179.0 8,180.0 6,675.1 6,675.8 A -2, 3K-08 12/1/1986 1.0 IPERF 4" Csg Gun; 0 deg. phase IPERF, 8.152 -8.153 8,230.0 8,240.0 6,714.0 6,721.7 A - 1, 3K - 08 8/10/2008 6.0 APERF 2.125" ENERJET HMX, 60 deg phase IPERF, 6,156 -8,157 Notes: General & Safe RPERF, End Data Annotation 8,130$785 IPERF, 8/132008 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0REV 8,760.8,761 IPERF, 5,163 -8,166 IPERF, e l69 -8,170 IPERF, 8,175-8,176 IPERF, 8,179-8,180 Mandrel Details RPERF, Top Depth Top Port 8,230 -8,240 (TVD) Incl 1 OD Valve Latch Size TRO Run Stn Top(RKB) (RKB) (°) Make Model I (in) Sem Type Type (in) (psi) Run Date Com... 1 7,750.3 6,347.6 40.37 CAMCO MMM 1 12 INJ DMY RKP 0.000 0.0 10/3012010 PRODU-8TION, 2 7,870.8 6,439.4 40.40 CAMCO MMG 1 12 IM OPEN 0.000 0.0 10/13/1010 TD (3K-05), 8,501 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. October 21, 2010 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforating Record: 3K -08 Run Date: 10/19/2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention o£ Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3K -08 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 21621 -00 NOV 15 2010 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Minton Wood 6900 Arctic Blvd. U Lb (0 - t ' Anchorage, Alaska 99518 Office: 907 - 273 -3527 v g s L-f Fax: 907 - 273 -3535 klinton.wood al ib t c ©m Date: Signed: a a ' i • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. October 20, 2010 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Jewelry Log: 3K -08 Run Date: 10/2/2010 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 3K -08 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 21621 -00 $ *W NGN 1 5 2010 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wooctg.h Vb on.com-, e�2 Date: Signed: • • ~~Q~C~ 0~ p~Q~~Q /,E,..~..~a....~ Darrell R. Humphrey Production Engineering Specialist ConocoPhillips Alaska, Inc. ~ t P.O. Box 100360 ~ Anchorage, AK 99510 `~ Re: Kuparuk River Field, Kuparuk Oil Pool, 3K-08 Sundry Number: 310-192. Dear Mr. Humphrey: .,~~, ~} I~ , 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 rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this ~~' day of June, 2010. Encl. • Conoco~Phillips June 21, 2010 Dan Seamount AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 33 W. 7~' Ave. Ste. 100 Anchorage, AK 99501 C~ Robert Christensen/Dan•ell Humphrey Production Engineering Specialists. Greater Kuparuk Unit , NSK-69 PO Box 196105 Anchorage, AK 99519-6105 Phone: (907)659-7535 Fax: 659-7314 Dear Mr. Seamount, ConocoPhillips Alaska, Inc. requests approval to convert Kuparuk We113K-08 from Water Injection Service to Oil Production service. Enclosed you will find 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. for 3K-08 (PTD 186-126). If you have any questions regarding this matter, please contact myself or Robert D. Christensen at 659-7535. Sincerely, ~-~r-ccc~~, Darrell R. Humphrey Attachments Sundry application Well schematic STATE OF ALASI(A ALASICA~IL AND GAS CONSERVATION COMMISSI APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ~~ 1. Type of Request: Abandon ~ Plug for Redrill ~ Perforate New Pool ~" Repair w ell ~ Change Approved Program Suspend r Plug Perforations r Pbrforate ~ Pull Tubing ~ Time Extension Operational Shutdow n r I~-enter Susp. Well r Stimulate ~ Alter casing r Other: WINJ to PROD C~ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory ~? 186-126 ' 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic ~ Service r 6. API Number: 50-029-21621-00' 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes ^ No r 3K-08 9. Property Designation: 10. Field/Pool(s): ADL 25520. Kuparuk River Field / Kuparuk 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): 8501 6924 8386' 6833' none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 110 16 110' 110' SURFACE 4244 9.625 4244' 3758' PRODUCTION 8475 7 8475' 6903' Pertoration Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 16-7934, 8090-8120, 8130-8185, 8230-8 6474-6488, 6607-6630, 6637-6680, 6714-6722 2.875 J-55 8029 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER -BAKER "FHL" RETRIEVABLE PACKER MD= 7818 TVD= 6399 SSSV -Safety valve, TRMAXX-5E, 3.5" MD= 1995 TVD= 1988 12. Attachments: Description Summary of Proposal ~ Detailed Operations Program ~ BOP Sketch [' 13. Well Class after proposed work: Exploratory r Development ~ Service r 14. Estimated Date for Commencing Operations: 6/24/2010 15. Well Status after proposed work: WDSPL ~ Suspended r Oil ~. Gas [! 16. Verbal Approval: Date: Commission Representative: WINJ ~ GINJ ~` WAG (- Abandoned r GSTOR (i SPLUG C 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Bob ChristenseNDarrell Humphrey Printed Name Darrell R. Humphrey Title: Production Engineering Specialist Signature Phone: 659-7535 Date ~ -~ . , Commi n Use I Sundry Number. ~ (~ _ ~ ~~ Conditions of approval: Notify Commission so that a representative may witness Plug Integrity ~ BOP Test ~` Mechanical Integrity Test [ Location Clearance r Other: ~ "~~~ 17 L~.~ Subsequent Form Required: /~ , L~/0 c,/ ( Approved by' COMMISSIONER Alaska pil €~ Gau Cuts. Commission APPROVED BY ~nC~tgr3' THE COMMISSION Date: 2 0R~(~~I~~~•. G.Ly~o Form 10-403 Revis .~UN 2 $ ~`•{` V („M ~ ~~, Submit in Duplicate ~„Zg~'`' 3K-08 DESCRIPTION SUMMARY ~3K-08 A CTD sidetrack on 3K-08 is planned for December of 2010. A recent bottom-hole pressure survey confirmed that the pressure exceeds the CDR2 CTD pressure drilling limit. The proposal has been made to depressurize 3K-08 and the surrounding area by converting it to production. Required time for adequate depressurization is predicted anywhere from 3 to 6 months. By the end of 2010 the pressure should be adequate to drill the 3K-08 CTD sidetrack ~/~ ~ ~~r ~~ s ~onocoPhillips Af:ivl;t. Irx; ... w. RANGER, 35 CONDUCTOR, 0.110 sssv,ls9s 6URFACE, 04 244 INJECTION, 7.750 LOCATOR, 7,902 SEAL AB6Y, 7.902 PBR, 7804 PACKER.7,918- INJECTION, _ 7,871 IPERF, _ 7,916-7,934 SLEEVE-0, 7.989 NIPPLE. 8.019 X0, B,D29 505. 8.030 IPERF. 9,1D2-8,103 RPERF, 8,090-8,720 IPERF, 8.106-8.1 D7 IPERF, B,11D8,111 IPERF, 8,1148,715 IPERF, 8.140.8.141 IPERF, 8.144-8.145 IPERF, 8,152-8,153 IPERF, 8,156-8,157 RPERF. _ 8,130b,1 BS IPERF, 8,1fi0A,i61 IPERF, _ 8,165-8,168 IPERF, _ 11,169-8,170 IPERF, 8,175-8,176 IPERF, _ 8,179-8,180 SLM KUP 4.0 ~ 6!7/2010 Rev Rea. 'ing 0... String ID ... Top (ftKB 16 15.062 0.0 ~ing 0... string ID ... Top (RKB 9 5!8 8.765 0.0 ~ing 0... String ID ... Top (RKB 7 6.151 0.0 1nao... smnglD.. rop(mte; 31/2 2.992 35.0 Inc ncl Max An le Incl I°) MD II 45.32 )ate KB G 2/16/2008 ~.pth (TVD) ... string WI 110.0 62.50 ~pM (ND)... String Wl 1,757.8 36.00 pM (TVD) ~~~ string WI ',903.4 26.00 ptn (rvD) ... suing wt ,543.0 9.30 Comment a_, ... 3K-08 I 9/30/1986 ast Motl Entl Data Imosbor 6/18/201 Top (TVD) Btm (TVD( Dent Top (RKB) Bon (RKB) (RKB) (RKB( Zone Dab (en... Type Comment OD Valve Latch Size TRO Run Stn Top (RNB) (RKB) (°) Make Motlal (In) Serv Type Type (In) (psi) Run Dab Com... • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Injection Profile: 3K-08 Run Date: 2/17/2010 March 17, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3K-08 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-21621-00 Injection Profile Log 1 Color Log 50-029-21621-00 ~~~~;~;~~~ ~~'r? ~ ~ 101+ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. ~ C Anchorage, Alaska 99518 U Office: 907-273-3527 Fax: 907-273-3535 rafael.barreto@halliburton.com ., b~ ' ,~-3 Date: 6~ P ~~~- ~2~ Signed: • MEMORANDUM To: Jim Regg ~~~~ ~V l JCf~ P.I. Supervisor I FROM: Chuck Scheve Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 20, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3K-08 KUPARUK RIV iJNIT 3K-08 Src: Inspector NON-CONFIDENTIAL Reviewed Bye P.I. Suprv Comm Well Name: KUPARUK RIV UNIT 3K-08 Insp Num: mitCS090515161311 Rel Insp Num: API Well Number: 50-029-21621-00-00 Permit Number: 186-126-0 Inspector Name: Chuck Scheve Inspection Date: 5/15/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3K-OS ' Type Inj. N 'rVp 6398 IA 900 2260 2200 2200 P.T.D I86IZ6o TypeTest SPT Test psi ~ 1599.5 A loo loo loo ioo Interval a~rRTST p~ P Tubing zzoo zzoo zzoo zzoo Notes: Pretest pressures observed and found stable. Well demonstrated good mechanical integrity/ `~ id19 t' ~t ~ 4P G:: L~~L'~ Wednesday, May 20, 2009 Page 1 of ] 05/12/09 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # :~ ~ ~>A q ~ ~, { way AY ~ ~ 2009 ~las~ qil ~~s C~. ~Onlr~li~si0~ ~I1chOr~~ Log Description NO. 5228 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 3A-18 AYS4-00069 PERF/SBHP SURVEY L 04/26/09 1 1 3C-08 6146-00033 GLS s / - 04/21/09 1 1 2M-25 6148-00034 GR/TEMPLOG !~}(- 04/22/09 1 1 1R-19A AYS4-00065 _ SBHP SURVEY -rC ~'- 3fo 04/23/09 1 1 3G-13 AYS4-00067 ` SBHP SURVEY - 04/24/09 1 1 3G-05 AYS4-00066 SBHP SURVEY 04/24/09 1 1 3F-07 6148-00038 SBHP SURVEY 04/24/09 1 1 3F-08 B14B-00037 SBHP SURVEY 04/24/09 1 1 3M-25A 8146-00040 SBHP SURVEY 3 04/25/09 1 1 3K-08 B14B-00039 SBHP SURVEY C/ 04/25/09 1 1 2N-318A AWJI-00026 MEM BHP SURVEY -Q 04/27/09 1 1 2Z-07 8146-00045 SBHP SURVEY L 04/29/09 1 1 2Z-01A 8146-00044 SBHP SURVEY '~-_ ~ 04/29/09 1 1 3K-102 ANHY-00080 GLS 04/30/09 1 1 2W-06 B04C-00036 PRODUCTION PROFILE 05/02/09 1 1 2W-12 B04C-00037 PRODUCTION PROFILE - p 05/03/09 1 1 3C-02 604C-00045 POWERCUTTER W/SBHP SURVEY- 05/09/09 1 1 1 J-120 604C-00043 GLS - ~ 0® 05/08/09 1 1 31-11 B04C-00044 SMALL TBG PUNCH W/SBHP 05!08/09 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • ~~~ ~~ E i.,. ~w I 1p( t / } ~~`-i {~i ~I ~~ f~; ~~ l~~ ,,1~ ~~OJ a ALASSA OIL ArTD GA5 C01~5ER~ATIOAT COM11'IIS5IOr1T CANCELLATION SUNDRY APPROVAL N0.304-190 Mr. Perry Klein Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. .;-,.~1,;~~~u~~~,`, ~ ~' ~ ~ ~,'~: P.O. Box 100360 Anchorage, AK 99510-0360 RE: Cancellation of Sundry Approval 304-190 (KRU 3K-08) PTD 186-126 Dear Mr. Klein: 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Pursuant to ConocoPhillips Alaska, Inc. (CPAI)'s request dated March 30, 2009 the Alaska Oil and Gas Conservation Commission (Commission) hereby cancels Sundry Approval 304-190, which allows continued water injection. Kuparuk River Unit (KRU) well 3K-08 exhibited pressure communication between the tubing and tubing-casing annulus. Approval to continue water only injection was contingent on CPAI implementing several conditions set out in the sundry approval. CPAI replaced the tubing during a rig workover in February 2008 as authorized by S>.tndry Approval 308-012. A successful mechanical integrity test was performed by rig personnel on February 23, 2008 after replacing the tubing. The Commission witnessed a passing MIT on May 1, 200.8 after recommencing injection. The completed work was reported to the Commission on Form 10-404, Report of Sundry Operations, dated March 31, 2008. Consequently, Sundry Approval 304-190 no longer applies to operation of this well. Instead, injection in well KRU 3K- 08 will be governed by provisions of the underlying Area Injection Order No. 2B. DONE at Anchorage, Alaska and dated April 7, 2009. Daniel T. Seamount, Jr. Chair v ~ Cathy . Fo rster Commissioner u SARAH PAL/N, GOVERNOR ~?:.-'~ ~~m: r;f'a "~ ~ 144 • ConocoPhillips aas~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 30, 2009, Mr. Dan Seamount Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 ~-= ._ a* ~~~ ~~~y ~ ~~ "~ ~~~ ~t ~ ~; ~,. ~ ~, ~~~ ~~~~ ,~~~® Subject: 3K-08 (PTD 186-126) request for cancellation of sundry approval # 304-190 Dear Mr. Seamount: ConocoPhillips Alaska requests cancellation of sundry (304-190). The approval, originally issued June 1 2004, for continued water injection with T X IA communication is no longer needed. The tubing was replaced during a recent rig work over, Feb 2008. The well passed a State witnessed MITIA on 5/01/2008. If you require any additional information please contact myself or MJ Loveland at 659-7043 Perry Klein Well Integrity Project Supervisor > 6ae SEA ~ ®2QC~~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 14~35~;~ (~~' G6c ~-fUOS ~0~~„ j~S`00 REPORT OF SUNDRY WELL OPERATIONS ~l~c~c~;~u~ 1. Operations Pertormed: Abandon ^ Repair Well ^ Plug Pertorations ^ Stimulate ^ Other ^ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate Q Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConOCOPhillips Alaska, InC. Development ^ Exploratory ^ 186-126 / ` 3. Address: SVatigraphic ^ Service ^/ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-21621-00 • 7. KB Elevation (ft): 9. Well Name and Number: RKB 69' 3K-08 8. Property Designation: 10. Field/Pool(s): ADL 25520 ~ Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 8501' feet true vertical 6924' feet Plugs (measured) Effective Depth measured 8386' feet Junk (measured) true vertical 6833' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 110' 110' SURFACE 4175' 9-5/8" 4244' 3758' PRODUCTION 8406' 7" 8475' 6903' V Perforation depth: Measured depth: 7916'-7934', 8090'-8120', 8130'-8185', 8230'-8240' rti l d t th c~ ' 6 8 1 ' ' ' '- '`~ ;a g,yk+ rr~ 4; , ~'~r~a~ A fiCi" ~'' `~ ~~~~ rue ve ca ep : 6474 - 4 , 6607-6630 , 67 8 , 6637-6680 4 6722 Tubing (size, grade, and measured depth) 3.5", L-80, 8031' MD. /~~~ J~ Packers ~ SSSV (type & measured depth) Baker'FHL' retriev. Pkr, Baker DB pkr @ 7818', 8003' SSSV @ 1995' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 373 Subsequent to operation shut-in - -- 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service Daily Report of Well Operations _X 16. Well Status after work: Oil^ Gas^ WAG^ GINJ^ WINJ ~ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.O. Exempt: none contact John Peirce @ 26 5-6471 Printed Name John Peirce i Title Phone: 265-6471 Wells Group Engineer ~~ ~~~~~ ~t Date ~ gnature ~ S . r.. , Pre ared b Sharon All u -Drake 2 3-4612 Form 1 -404 Revised 04/2006 Submit Original y~~'~~ DATE SUMMARY 3K-08 Well Work Summary . 8/5/08 DRIFT W/ 10' x 2.125" STEM 69' SLM. JOB COMPLETE. 8/7/08 ATTEMPTED TO PERFORAT ' 6 SPF, 2 1/8" PEJ FROM 8230'-8240'. PRIMACORD WAS DAMAGED WHILE RIH AND GUN DID NOT FIRE. RD FOR THE NIGHT, WILL RETURN IN THE MORNING. ~ 8/8/08 PERFORATED 2 1/8" 6 SPF POWER ENERJETS FROM,8230'-8240', 8165'-8185', AND~~ CHARGE DATA: PENE 30.4", ENTRANCE HOLE: 0.32" RD FOR THE EVENING WILL RETURN IN THE MORNING 8/9/08 PERFORATED WITH 2 1/8" 6 SPF 45 DEG PHASING POWER ENERJETS. -INTERVALS: 8130'-8145', 8135'-8145', 8100'-8120'. ONLY THE TOP 5' OF THE FIRST 15' GUN FIRED RAN A 10' GUN FROM 8135'-8145'. - TOOL BECAME STUCK AT 2.25" NIPPLE AT 8120' AFTER FIRING 20' GUN FROM 8100'-8120'. PUMPED 40 BBLS WATER TO DELODEGE TOOL. -CHARGE DATA: PENE 30.4", ENTR. HOLE 0.32" - RIG DOWN FOR THE EVENING WILL RETURN IN THE MORNING TO SHOOTfINAL 10' GUN. 8/10/08 PERFORATED FROM 8090'-8100' WITH A 10', 6 SPF 45 DEG 2 1/8" POWER ENERJET PERF GUN. -CHARGE DATA: PENE 30.4", ENTR HOLE 0.32" DID NOT TAG TD, WELL LEFT SHUT IN ConocciF'hitlips ~~ ~{ P11!lSn.~., r. I'. HANGER, % 16anearleaar~~l coNDUCroR,_ e-110 sssv,1,99s- SURFACE..- bJ,266 sEAL Assv. r.eo2 PBR, ],806 - PACKER, 7,818 INJECTION.- _._ 7,e71 IPERF, __ 7,916-I,934- SLEEVE, 7,969 SEAL NIPPLE. xo. sos, e iaa.lm IPERF. 8,1108."' - IPERF, 8.t 168,115 (PERF. 8,160$.161 IPERF, 8.1658,166 IPERF. 8.1698.170 IPERF, 8,1758,176 (PERF. 8,119$160 KU P 110.0 710.0 Depth (ft... Set Depth (1YI UCTION ~ 7 ~ 6.151 ~ 0.0 ~ S, rig Strings _ _ ___ _ Description ',OD(inl ID (inl iTOp(ft... Set Depth (ft G ~ 3112 ~ 2.992 i 35.0 8,006.5 3K-08 9/3011986 . Gratle Top Connection J-55 bade-'.Top Connection L$0 EUE 8RD 35.OIHANGER Tubing Hanger 2.992 1,994.9 SSSV Satey valve, TRMAXX-fiE, 3.5" 2.812 7,802.SISEAL ASSY 80-00 seals Overall 12 ft 3.000 7,804.5 PBR Baker "PBR" Polish Bore Receptacle 2.950 7,817.8 PACKER Baker "FHL" Retrievable Packer 2.950 7,989.4 SLEEVE ~ Sliding Sleeve 2.812 BX Profile 2.812 8,003 611X0 Cross over Sub 2 450 8,005.511 SEAL ASSY 80.32 Seais Overall 6 40 ft 2.420 Tubing Description IOD (in) IID (inl Top (ft... Set Depth (fiK... Set Depth (ND) (ftKB) YVt (IbalR) Grade Top Connection 'TUBING-Original ~. 2718 8,002.7: 8031.0 6.567.8 Com letion Details Top(ftK8) kem Description Comment ID (in) I 8,002.7 PACKER I BAKER DB PACKER I '~ 8019.4 NIPPLE IICAMCO'D'NIPPLE 2.250 8 029.4 XO CROSSOVER 2 7!8" TO 3.5" TUBING 3.500 -- 8,030.2 SOS i _ 2920 .___-_.- _._. _____._--__ Perforations Top Bbn Shot Top Btm (TVD) (TVD) Dens (ftKB) (HKB) (fiK8) (fiK8) Type Zone (sho... Data Comment 7,916.0' 7 934.0 6,473.8 6 487.5 (PERF C-1, UNIT B, 12.0 1212/1986 120 deg. phasing; 5" Csg Gun 3K-08 8,090.0 8,120.0 6,607.0 6,629.9 RPERF A-3, 3K-OS 6 0 8!10/2008 2.125" ENERJET HMX, 60 deg phase 8,102.0 8,103.0 6,616.1 6 816.9 (PERF A-3, 3K-08 I 1.0 12/1/7986 4" Csg Gun; 0 deg. phase 8,106.0 8,107.0 6,619.2 6,620.0 (PERF IA-3, 3K-08 ~ 1.0 12/1/1986 4" Csg Gun; 0 deg. phase 8,110.0 8,111.0 6,622.3 6,623.0 (PERF A-3, 3K-08 'i 1.0 12/1/1986 4" Csg Gun; 0 deg- phase 8 114.0 8,115.0 6,625.3 6,626.1 (PERF A 3 3K-08 I 1.0 72/1/1986 4" Csg Gun' 0 deg phase 8 130.0 8,785.0 6,637.6 6,679.6~RPERF A 2 3K-OS 6.0 8/10/2008 2.125" ENERJET HMX, 60 deg phase 8,140.01 8,141.0 6,645.2 6646.0',IPERF A-2, 3K-08 1.0 12/1/1986 4" Csg Gun; 0 deg. phase 8, 144.Oj 8,145.0 6,648.3 6649.0 IPERF A-2, 3K-08 1 0 72/1/1986 4"Csg Gun; 0 deg. phase 8,152.0 8,153.0 6,654.4 6,655.2 (PERF A-2, 3K-08 1.0 12/1/1986 4" Csg Gun; 0 deg. phase 8,156.0 8,157.0 6,657.5 6,658.2 (PERF A-2, 3K-08 1.0 12/1/7986 4" Csg Gun; 0 deg. phase 8,160 0 8,161.0 6,660.5 6,661.3 IPERF A-2, 3K-08 1.0 12/1/1986 4" Csg Gun; 0 deg. phase 8,165.0 8,166.0 6,664.3 6,665.1 (PERF ~A-2, 3K-08 1.0 12!1/1986 4" Csg Gun; 0 deg. phase 8,169.0 8,170.0 6,667 4 6,668.2 (PERF jA-2, 3K-08 I 1.0 12/1/7986 4"Csg Gun; 0 deg. phase 8,775.0 8,176.0 6,672.0 6,672.8 (PERF ~IA-2, 3K-08 ~ 1.0 1211/1986 4" Csg Gun; 0 deg. phase 8,179.0 8,180.OI 6,675.1 6.675.8 IPERF A-2, 3K-08 ~ 1.0 1211/1986 4" Csg Gun; 0 deg- phase 8,230.0 ~. 5,240.0' 6,714.0 6,721.7IAPERF A-1, 3K-08 _ - I 6.0 8/7012008 L 2.125" ENERJET HMX, 60 deg phase I~_Eed DGefiefal ~ Safety_._ _ __ ___ ate Annotation _ 8/1372008 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 MandrelDetails --- ~ - ' Set Depth _ ___ - -- Part Top ITVDI 1 Valve Latch Size TRO Run Sin lfiKel (fiK6) Make Model OD(in) TYPe TYPe (in ) (Psi) Run Date CammaM ~1 7,750.3 6,543.OI CAMCO MMM '~ 1 1/2 DMY IIRKP i 01 0.01 3/14/2008 2 7,87Q8. 6,543.OI CAMCO .MMG 1 7/2~DMY IRK 0~. 0.0 2/23/2005 _ I APERF, 8,2308,260 -- PRODUCTION. 08,675 TD. 8.501 • MEMORANDUM TO: ~ Pim Rpggisor ~~~~ S'1 ~! ~~' FROM: Lou Grimaldi Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, May O5, 2008 SIBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3 K-08 KLPARUK RIV UNTT 3K-O8 Src: Inspector NON-CONFIDENTIAL Reviewer! Bv: P.I. Suprv~ r Comm Well Name: KUPARUK RN UNIT 3K-08 Insp Num: mitLG080sO1112~50 Rel Insp Num: API Well Number: 50-029-2 1 62 1-00-00 Permit Number: i 86-126-o Inspector Name: Lou Grimaldi Inspection Date: ~~ 1!2©08 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Niin 60 Min. Well 3K oa ;Type Inj. TVD - 6399 1800 ~, IA I lao --- --- 1780 1780 186160 i SPPT 'I - P.T. - iTypeTest Test psi -+- I 1s99.7s '~pA aao slo - ' -- slo -- slo --- - - Interval mzTAL p/F P ~ Tubing ,, z37s z3r j z37s z3r NOteS' ~ 1 bbl to pressure up, bled IA w/ no gas observed (fluid packed). Good initial test. ~'4+DIJ lViri~ ~ ~ 200 Monday, May 05, 2008 ~ Page I of l • Page 1 of 2 • Maunder, Thomas E (DOA) From: Packer, J.Brett [J.Brett.Packer@conocophillips.com] Sent: Monday, April 07, 2008 11:56 AM To: Maunder, Thomas E (DOA} Subject: RE 3K-08 (186-126 8~ 1R-36 (201-227) Yes, it was Nordic got rid of Nabors 3S last December so now we only have the one workover rig. ,~ Brett ~'ac~r 93ri1ding sZ 21~e~s 4Notf~gverEngineer ~~ APR ~ ~ ZoQ 'Work# 265-6845 CeQ# 230-8377 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, April 07, 2008 11:52 AM To: Packer, J.Brett Subject: RE: 3K-08 (186-126) & 1R-36 (201-227) Thanks Brett. That should work. tf I see other items to include, I will send a message. Could you tell me what rig did the work? I suspect Nordic 3. Tom From: Packer, J.Brett [mailto:J.Brett.Packer@conocophillips.com] Sent: Monday, April 07, 2008 11:40 AM To: Maunder, Thomas E (DOA} Subject: RE: 3K-08 (186-126) & iR-36 (201-227) Tom, I'll forward this to the workover rig supervisors and make sure they include this information on the summaries. ,7. Brett Packer Ong sZ'cNe[)s ~Norkover Engineer ~ork# 265-6845 Celr# 230-8377 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, April 07, 2008 11:29 AM To: Packer, J.Brett Cc: Eggemeyer, Jerome C. 4/7/2008 • Page 2 of 2 • Subj~t: 3K-08 (186-126) & 1R-36 (201-227) Brett, I am reviewing the 404s submitted for the work on 3K-08 and 1 R-36. With regard to the work summaries, the detail is pretty good however there are a few items. I am not sure how the information is best captured so it prints on the report. I have spoken with Jerome on some of these items on the drilling side. 1. The rig is not identified. Might the rig name be specified when the accept time is noted? 2. In 3K-08, the initial BOP test information is more complete than 7 R-36. In particular, it is noted which Inspector waived witness of the test. This is information that should be included. Thanks in advance for you reply. Call or message with any questions. Tom Maunder, PE AOGCC 4/7/2008 ~ ~ STATE OF ALASKA F~E~EIii~D APR 0 1 2008 ALASKA OIL AND GAS CONSERVATION COMMISSION IaSka Oii & Gas Cons. C01Tlmissior REPORT OF SUNDRY WELL OPERATION- anchnranp 1. Operations Performed: Abandon ^ Repair Well ^~ Plug Perforations ^ Stimulate ^ Other ^ Alter Casing ^ Pull Tubing ^/ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: COnOCOPhillips Alaska, InC. Development ^ Exploratory ^ 186-126 / 3. Address: Stratigraphic ^ Service ^/ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21621-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 69' 3K-08 8. Property Designation: 10. Field/Pool(s): ADL 25520, ~CL~K-355ft„'~, ,2, ~r~ Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 8501' feet true vertical 6924' feet Plugs (measured) Effective Depth measured 8384' feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 110' 110' SUR. CASING 4175' 9-5/8" 4244' 3758' PROD. CASING 8406' 7" 8475' 6903' Perforation depth: Measured depth: 7916' - 8180' true vertical depth: 6474' - 6676' Tubing (size, grade, and measured depth) 3.5", 2-7l8", L-80, J-55, 8006', 8031' MD. Packers &SSSV (type & measured depth) pkr- Baker FHL retriev. ; BAKER'DB' pkr= 7818' ; 8003' Camco TRMAXX-5E SSSV= 1995' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI Subsequent to operation SI 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ^' Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^ Gas ^ WAG ^ GINJ ^ WINJ ^~ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.O. Exempt: 308-012 contact Brett Packer @ 265-6845 Printed Name Brett Packer Title Wells Group Engineer Signature ~,'"~.~~ ~~ Phone 265-6845 Date ~[% r /~j Form 10-404 Revised 04/2004 l c~ Submit Original Only • • ~~...` ' ~o~c~c+>~Phlt1lp~ ~i~sk~, I~t~" -- --- _ - API: 500292162100 WeII T e: INJ TUB1~ - SSSV Type: TRDP Orig 9/30/1986 (0-6~. oD:a.soo, Com letion: ID:2.ssz) Annular Fluid: Last W/O: 2/16/2008 Reference Lo Ref Lo Date: TUBING Last Ta :8384 TD: 8501 ftK6 ps4o-so31, Last Tag Date: 12/7/1986 Max Hole Angle: 45 deg Coil 5000 OD2.875, ID:z.441) ,Casing String -ALL STRINGS Descri tion Size To Bottom CONDUCTOR 16.000 0 110 SUR. CASING 9.625 0 4244 PROD. CASING 7__.000 0 8475 Tubing String -TUBING Pert (7916-7934) KRU 3K-08 I Anale Ca) TS: 140 dea Ccil 7853 Size To Bottom TVD WI Grade Thread 3.500 0 8006 6543 9.30 L-80 EUE AB MOD 2.875 7640 Perforations Summary interval TVD 8031 6562 _ Zone Status Ft SP 6.50 F Date J-55 T EUE AB MOD Comment 7916 - 7934 6474 - 6488 C-1,UNIT B 18 12 12/2/1986 IPERF 120 deg. phasing; 5" Csg Gun 8102 - 8103 6616 - 6617 A-3 1 1 12/1/1986 IPERF 4" Cs Gun; 0 de hase 8106- 8107 6619- 6620 A-3 1 1 12/1/1986 IPERF 4" Cs Gun• 0 de hase 8110- 8111 6622- 6623 A-3 1 1 12/1/1986 IPERF 4" Cs Gun• 0 de hase 8114- 8115 6625- 6626 A-3 1 1 12/1/1986 IPERF 4" Cs Gun; 0 de hase 8140 - 8141 6645 - 6646 A-2 1 1 12/1/1986 IPERF 4" Cs Gun; 0 de hase 8144- 8145 6648- 6649 A-2 1 1 121111986 IPERF 4" Cs Gun• 0 de hase 8152 - 8153 6654 - 6655 A-2 1 1 12/1/1986 IPERF 4" Cs Gun; 0 d hase 8156 - 8157 6657 - 6658 A-2 1 1 12/1/1986 IPERF 4" Cs Gun; 0 de hase 8160 - 8161 6661 - 6661 A-2 1 1 12/1/1986 IPERF 4" Cs Gun; 0 de hase 8165 - 8166 6664 - 6665 A-2 1 1 12/1/1986 IPERF 4" Cs Gun• 0 de hase 8169 - 8170 6667 - 6668 A-2 1 1 12/1/1986 IPERF 4" Cs Gun; 0 de hase 8175- 8176 6672- 6673 A-2 1 1 12/1/1986 IPERF 4" Cs Gun• 0 de hase 8179- 8180 6675- 6676 A-2 - -- Gas Lift Mandrels/Valves St MD ~TVD ~ Man Mfr ~ Man Type ~ V Mfr ~ 1 1 V Type ~ 12/1/1986 IPERF V OD ~ Latch ~ Port 4" Csg Gun- 0 deg. phase ~ ~ TRO ~ Date Run ~ Cmnt 1 7750 6347 CAMCO MMM DMY 1.5 RKP 0.000 0 3/14/2008 Injection Mandrels/Valves St MD I TVD I Man Mfr Man Type V Mfr I V Type i V OD Latch Port TRO Date Run Cmnt 2 7871 6440 CAMCO MMG DMY t5 RKP 0.000 0 2/21/2008 --- Ot11e~ lugs, equip., etc.) -COMPLETION _ 2.950 2.813 3.250 2.420 Perf (8102-8103) Pert (8106-8107) Perf (8140-8141) Perf (8144-8145) Pert (8152-8153) Pert (8156.8157) Perf (8169-8170) PROD. CASING (0-8475, OD:7.000, Wt:26.00) Pert (8179-8180) • Time Logs Date From To Dur S De th E. Depth Phase Code Subcode__T COM ___ 02/18/2008 01:30 04:00 2.50 7,610 5,765 COMPZ RPCOh PULD P Pooh laying down 60 jts 2 7/8 production string, sssv. RD Schlumber er S ooler. 04:00 11:00 7.00 5,765 0 COMPZ RPCO PULD P Continue to Pooh laying down 2 7/8 8rd J-55 Production string and tallying all. 11:00 12:00 1.00 COMPZ RPCOh OTHR P Clear and clean rig floor. Clear pipe shed of production string. Change over to DP handlin a ui ment. 12:00 16:30 4.50 COMPZ RPCO OTHR P Continue to load pipe shed w/ remaining DP and DC's. Load Fishing e ui ment and stra BHA. 16:30 17:00 0.50 COMPZ RPCOh OTHR P Set Wear ring. 17:00 19:00 2.00 0 307 COMPZ FISH PULD P P/U and MU Fishing BHA #2 19:00 00:00 5.00 307 5,151 COMPZ FISH TRIP P P/U and drift DP as Rih w/ BHA #2 02!19/2008 00:00 04:30 4.50 5,151 7,639 COMPZ FISH TRIP P Continue to Rih PU DP o TOF 7 04:30 05:00 0.50 7,639 COMPZ FISH CIRC P Gather parameters 152k up wt,85k do wt, 115k Rot wt. 46 rpm's @ 5,300 ft/Ibs. Circ 57 bbls @ 5 bpm @ 1050 si. 05:00 05:30 0.50 COMPZ FISH MILL P Rotate down and dress off tbg stub and en a e fish while circ 2 bpm @ 460 psi and pressure increased to 700 psi when OS grapple and pack off came en a ed w/ stub. 05:30 07:00 1.50 7,639 7,520 COMPZ FISH PULL P Pull up to 7520' and circ bottoms up 5 b m 1050 si. 07:00 12:00 5.00 7,520 307 COMPZ FISH TRIP P Blow down top drive. Pooh f/ 7520' up wt 155k, 85k do wt. 12:00 12:30 0.50 307 0 COMPZ FISH PULD P Pooh w/ BHA #2 to fish. 12:30 13:30 1.00 0 COMPZ FISH OTHR P Change over to tbg equipment. 13:30 14:00 0.50 COMPZ FISH PULL P Lay down cut joint inside overshot. 14:00 14:30 0.50 COMPZ RIGMN RGRP P PJSM, Crane out Eckle Tongs. 14:30 16:00 1.50 COMPZ FISH PULL P Continue to Pooh laying down fish. 20' stub, 3 jts tbg, GLM, 1 jt tbg, 10' u 't, OEJ Overshot. = 182.87' 16:00 17:30 1.50 COMPZ FISH OTHR P Break down overshot and change out grapple to 3.250 nominal catch. Chan a over to DP E ui ment. 17:30 18:30 1.00 0 301 COMPZ FISH PULD P Pick up and make up fishing BHA #3 18:30 23:30 5.00 301 7,566 COMPZ FISH TRIP P Rih w/ DP from derrick. 23:30 00:00 0.50 7,566 7,710 COMPZ FISH TRIP P PU singles from 7566' to 7710.0' Page 2 u# 5 • Time Logs _ _ ____ Date From To Dur S Depth E. De th Phase Code Subcode T COM 02/20/2008 00:00 01:00 1.00 7,710 7,804 COMPZ FISH CIRC P Space out and Circ 57 bbls @ 5 bpm @ 1050 psi. Gather Parameters. 155k up wt, 90k do wt, 115k Rot wt @ 41 rpm @ 5000 ft/Ibs free torque, circ 2 b m 480 si. 01:00 01:30 0.50 7,804 7,774 COMPZ FISH FISH P Engage TOF @ 7,804.0' Circ down @ 2bpm 480 psi and see overshot engage fish - SPP came up to 1000 psi. Shut down pump and PU w/ 165k up wt. Attempt to come down and set down hi h. 01:30 02:30 1.00 7,774 7,774 COMPZ FISH CIRC P Circ BU @ 4 bpm @ 950 psi. Blow down To Drive. 02:30 03:30 1.00 7,774 6,875 COMPZ FISH TRIP P Pooh to 6875.0' 03:30 06:00 2.50 6,875 6,875 COMPZ RIGMN' SVRG P Slip and cut drill line 06:00 07:00 1.00 6,875 6,875 COMPZ RIGMN' SVRG P Service rig /top drive. 07:00 11:30 4.50 6,875 475 COMPZ FISH TRIP P Flow check, POH 3-1/2 DP to BHA. 11:30 15:00 3.50 475 0 COMPZ FISH PULD P Handle fish BHA #3. Recover seal assy, 4 jts tbg, blast jt, 200.33' of pkr, 2 mandrels & etc. All components heavily scaled. Holes in tbg above seal assy. Continued cork screwing. LD all BHA com onents. Clear floor. 15:00 16:00 1.00 COMPZ FISH OTHR P Change over to DP Equipment and clean floor 16:00 20:00 4.00 0 0 COMPZ FISH WOEQ X Contact engineer and discuss running clean out BHA. Wait on tools for clean out run to come from Deadhorse. 20:00 21:30 1.50 0 331 COMPZ FISH PULD P MU Clean out BHA #4 BHA 21:30 00:00 2.50 331 3,720 COMPZ FISH TRIP P Rih w/ DP 02/21/2008 00:00 03:00 3.00 3,720 7,785 COMPZ FISH TRIP P Continue to Rih f/ 3,720.0' to 7,785.0' Gather arameters 03:00 06:30 3.50 7,785 8,005 COMPZ FISH CIRC P Work cs scraper across ro osed FHL I and continue to clean out to 8,004.5' mule shoe depth w/ KB Correction. No- o on too ofd packer 7,997'. Had to rotate through perfs w/mill and scraper. Recovered packer element while circulating. Finished bottoms up and reverse 2 tbg vol. Then circulated 1 tb vol. rior to Pooh. 06:30 10:30 4.00 8,005 223 COMPZ FISH TRIP P Pooh 3-1/2 DP to BHA 10:30 12:00 1.50 223 0 COMPZ FISH PULD P Flow check, LD BHA #4. 12:00 13:30 1.50 0 0 COMPZ RPCOh OTHR P Clear floor, prep for completion. Ready i e shed. 13:30 14:00 0.50 0 0 COMPZ RPCO RURD P Re-install wear ring pulled with csg scra er. F'~c~e 3 of ~ C7 • i Time Logs _ Date From To Dur 5 De th E. Depth Phase Code Subcode T COM 02/21/2008 14:00 16:30 2.50 0 220 COMPZ RPCOh RCST P PJSM, Commence MU seal assy /pkr com onents. Flow check, RIH same. 16:30 23:00 6.50 220 7,996 COMPZ RPCOh TRIP P Rih w/ DP f/ 220.0' to 7,996.0'. 23:00 23:30 0.50 7,996 8,005 COMPZ RPCO CIRC P Circulate 60 bbl DP Volume @ 2 bpm @ 480 psi. Slide seals in to DB Packer while circ ?bpm @ 200 psi. Seen pressure increase shut pump_ down, and continue to slide seals into 8,005.0' and set 10k down. 23:30 00:00 0.50 8,005 8,004 COMPZ RPCO DHEO P Close bag and pressure IA to 500 psi, no returns up tubing. Drop ball and rod w/ bottom of seals 8,004.0' 02/22/2008 00:00 01:00 1.00 8,004 COMPZ RPCOti OTHR P wait on ball and rod to RHC plug @ 7,984'. RU head in. 01:00 02:00 1.00 7,809 COMPZ RPCOh PACK P Pressure u to 2 ~ ~ nd set FHL packer ~ 7,810' w/ bottom of seals Ca) 8,004'. Pressure u to 2 500 on IA for 30 min. and chart.- had 60 psi lost - good test. Shear out of PBR w/ 1,500 psi on DP and sheared @ 25k osw of 155k up wt. Bled off DP and pull seals out of PBR 7,797' 02:00 03:00 1.00 7,767 COMPZ RPCO OTHR P Clear pipe shed of DC's and DP. Pump dry job to help clear DP of Kill fluid residue while la in down DP. 03:00 12:00 9.00 7,767 0 COMPZ RPCO TRIP P Pooh laying down 3-1/2 DP 12:00 12:30 0.50 0 0 COMPZ RPCOh PULD P Flow check, LD test pkr / BHA. 12:30 13:00 0.50 0 0 COMPZ RPC06 RURD P Clear floor, make ready comp run tools. 13:00 13:30 0.50 0 0 COMPZ RPCO RURD P Pull wear bshg. 13:30 16:30 3.00 0 2,826 COMPZ RPCOh RCST P PJSM, commence run 3-1/2 completion. MU seal assy, flow check, RIH same. Follow with 3-1/2 tb to 2,826.0' 16:30 17:30 1.00 2,826 COMPZ RPCO OTHR P RD Eckle tongs. Load control line s ool ands ooler to ri floor. 17:30 21:00 3.50 2,826 5,820 COMPZ RPCO RCST P Continue to Rih w/ 3 1/2 completion f/ 2,826.0' U 5,820.0'. Slip die in Gavin air slips broke, but was recovered. A 5/16" dia. x 6.5" pin was not recovered. 21:00 21:30 0.50 5,820 COMPZ RPCO OTHR P RU control line to SSSV and pressure u to 5,200 si. Confirm valve is o en. 21:30 00:00 2.50 7,484 COMPZ RPCO RCST P Continue to Rih f/ 5,820.0' to 7,484.0'. 02/23/2008 00:00 02:00 2.00 7,484 7,812 COMPZ RPCO RCST P Continue to Rih f/ 7,484.0' to 7,990.0' circulate @ 1 bpm @ 200 psi. up wt 102k, do wt 73k, Block wt 35k. Slide into PBR w/ seals 7 804' and seen ressure increase. Bleed off tbg and continue to slide into 7,812.0' Pressure to 500 psi and verify seals in PBR. Mark i e and ull out of PBR. Page 4 of 5 • Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T CO_M 02/23/2008 02:00 03:30 1.50 7,812 7,773 COMPZ RPCOh HOSO P Space out and MU hanger. Tie in control line and re -o en SSSV. 03:30 04:30 1.00 7,773 7,810 COMPZ RPCO CIRC P Circ 200 bbls of 1% by CRW 132 w/ Kill weight fluid. Circ 1 bpm and slide into PBR w/ Seals, seen pressure increase. Land hanger and RILDS. Final de the =seal ass 8005, slide sleeve 7989, mandrel 7871, FHL pkr .7818, PBR 7801, Mandrel SOV 7750, SSV 1995, tb h r 35 ft. 04:30 07:00 2.50 7,810 7,810 COMPZ RPCOh DHEQ P RU /test tb 2500 si / 30 min. Bleed tbg to 1750 psi. Test 3-1/2 X 7 ann to .2500 psi / 30 min. Bleed tbg to 0 psi. SOV shear at 1450 psi. Bleed all pressures, circ /confirm SOV fully open. Bleed control line to 0 psi. Test SSV to 1000 psi. Bleed all pressures. All tests successful. No re-tests. 07:00 08:00 1.00 7,810 7,810 COMPZ RPCO OTHR P RD Lines and Set BPV 08:00 14:00 6.00 7,810 COMPZ RPCO NUND P ND ROPE NU Tree 14:00 16:00 2.00 COMPZ RPCO SFEO P Test Tree and Pack off 250/5,000 psi for 10 minutes. 16:00 16:30 0.50 COMPZ RPCO OTHR P Pull BPV 16:30 19:30 3.00 COMPZ RPCOh FRZP P RU to freeze protect w/ LRS. Pressure test lines, pump 80 bbls diesel for freeze protect 2 bpms @ 1,350 psi. RD LRS and aloow well to u-tube for 1 hr. 19:30 20:00 0.50 COMPZ RPCOh OTHR P Blow down all lines and kill manifold. 20:00 22:30 2.50 COMPZ RPCOh OTHR P Bring the lubricator, Set BPV w/ Lubricator. Final pressures tbg 350 si, IA 350 si and OA 180 si. 22:30 00:00 1.50 COMPZ RPCOti OTHR P Clean cellar, tear down handy berm and prep to RDMO. Rig released @ 23:59 hrs on 2-23-08. P~qe a ,af 5 . ~ ~ 3K-08 Well Events Summary • DATE SUMMARY 2/9/08 ATTEMPTED RUN SSSV LOCK OUT TOOL, ENCOUNTERED SCALE AT 3' SLM. GAUGED TBG TO 2.32" TO SSSV. DRIFTED TBG WITH 20' x 1-7/8" TO 7728' SLM. BROACHED SCALE TO 2.365" TO 87'. IN PROGRESS. 2/10/08 BROACHED TUBING RESTRICTIONS FROM 87' TO 1400'. LOCKED OPEN SSSV AT 1796' RKB. WELL READY FOR E/L TBG PUNCH. 2/13/08 JET CUT 2 7/8" TUBING AT 7640'. CUT LOCATION IS 10' INTO THE 184th JOINT BELOW THE SSSV. SAT DOWN IN CORKSCREWED TUBING AT 7661' WITH 2 ~~ ~_ 3/10/08 Brine Swap, displaced visc brine from tubing & I/A with S/W CRW-132. Jetted top of RHC plug @ 7970 CTMD. Freeze protected I/A & Tubing. Turned over to S/L. 3/13/08 PULLED BALL & ROD @ 7957' SLM, PULLED SOV FROM ST# 1 @ 7750' RKB, ATTEMPT SETTING DGLV IN ST#1, JOB ONGOING. 3/14/08 SET DV IN ST#1 @, 7750 RKB, PULLED RHC PLUG BODY @ 7989' RKB, ATTEMT TO SET 2.81" X PLUG IN SSD @ 7989' RKB, TAGGED @ 8300' SLM, SET 2.25" CA-2 BLANKING PLUG @ 8020' RKB, JOB ONGOING. 3/15/08 MIT IA TO 2500#, PASSED, MIT TBG. TO 2500#, PASSED, JOB COMPLETE. 3/16/08 BLEED T/IA/OA TO 0 PSI, INSTALL ENERGIZING JEWELRY 3/17/08 PULL 2.25" CA-2 PLUG @ 8020' RKB, JOB COMPLETE. ~~~~-,~ • SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 ~{~~~J~ JAN 2 2 2008 ,~~~ Re: Kuparuk River Field, Kuparuk River OiI Pooi, 3K-08 `~~ Sundry Number: 308-012 Brett Packer Wells Group Engineer Conoco Phillips Alaska Inc. PO Box 100360 Anchorage, AK 99510 Dear Mr. Packer: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this Letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this day of January, 2008 Encl. Sincerely. • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 14, 2008 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: • ~~~ Alaska ~i1 ~- ~~~ ~~'~~, Commission An~ht~~age ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Well 3K-08 (PTD# 186-126). Injection well 3K-08 was originally drilled in September 1986 as a 2'/8" selective single producer. In March 1990, the well was converted to an injector. Shortly after the workover in April 1990, it became apparent that the tubing was corkscrewed when tools kept getting hung-up in tubing and the set down depth depended on the backside pressure. In July 2003, pressure was noticed on the IA and each time it was bled, it would pressure back up. The well was granted a temporary waiver to inject water only with the IA below 3000 psi. The well continued to pass an MITIA but the IA would continuously fail a drawdown test. It was determined to be a one-way packer leak. In June 2006, a WRP was set at 6015' MD and the well failed an MITIA indicating at this time, either atwo-way packer leak or TxIA communication. The well has been SI since 5/14/06, and the last calculated SBHP on 12/22/06 was 3863 psi based upon a surface pressure of 1425 psi. Mid-pert depth is 6577' TVD which makes the MASP 3205 psi using a 0.1 psi/ft gradient. As mentioned before, we cannot get tools down this well due to the corkscrewed tubing, so the SBHP must be calculated. The current SBHP is expected to be lower due to offtake in this area. The current plan is to inject seawater to the formation, let the well stabilize, and calculate the SBHP to determine the needed kill weight fluid. The BOP's will be tested to a minimum of 3500 psi during the workover. Utz ~ r~i~ at; The purpose of the proposed work is to pull the 2'/" completion dowr,~o the `DB' packer at 8003' and upsize the tubing to 3'/2' which will allow for future CTD si '"! opportunities; as well as repair the corkscrewed tubing and TxIA communication. We will recomplete the well as a selective single just as it is now. Attached is a proposed schematic along with a general workover procedure. If you have any questions or require any further information, please contact me at 265-6845. Sincerely, Brett Packer Wells Engineer CPAI Drilling and Wells OR161NAL '. t~J'-S l ~ ~ 7~d~ STATE OF ALASKA ~) ,~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~( APPLICATION FOR SUNDRY APPROVAL !~ 20 AAC 25.280 1. Type Of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other ^ Alter casing ^ Repair welt Q Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^~ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 186-126 3. Address: Stratigraphic ^ Service Q 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-21621-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? YeS ^ NO ^~ 3K-08 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25520, ALK 2556 RKB 69' Kuparuk River Field /Kuparuk Oil Pool 12. P RESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8501' 6924' Casing Length Size MD TVD Burst Collapse CONDUCTOR 110' 16" 110' SUR. CASING 4175' 9-5/8" 4244' PROD. CASING 8406' 7" 8475' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7s1 s' - a1 sa' saga' - ss~s' 2-7/8" J-55 8031' Packers and SSSV Type: Packers and SSSV MD (ft) pkr-- CAMCO'HRP-I-SP' ; BAKER'DB' pkr-- 7826' ; 8003' SSSV= SSSV SSSV= 1796' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: 21-Feb-2008 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ~ WDSPL ^ Commission Representative: 18. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Brett Packer @ 265-6845 ine r Title: Wells Group Eng Printed Name B Packer c/ / r~l Signature -- '' `~~~f/" l„ ~~ Phone 265-6845 Date t r.~ ~ d Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness y Plug Integrity ^ BOP Test [~ Mechanical Integrity Test ~ Location Clearance ^ Other. ~J~ ~. M`L ~~ r`-~~s ~`~~®~ ~ST ~ \'~ ~~~ ~ J~YS l ~-~v\~ES ~ C'Ci.'l"~S ~Gf\l`Rl Subsequent Form Required: ~--~ S S~~F ~c~~ ~ ~ 2ao$ APPROVED BY /~, /~ ~ ~ Q Approved by: MMIS MISSION Date: / / Form 10-403 Revised 06/2006 v ~~ ~ ~ ~ ~ ~ ~ v h L S'~i~lic~ l6 l•/G-~ Kuparuk 3K-08 Injector . General Workover Procedure Pre-Riq Work 1. Bullhead seawater to formation, let WHP stabilize, record SWHP, calculate SBHP @ mid-pert. 2. RU Slickline: Lock out SSSV, drift for tubing punch, freeze protect. 3. RU Eline: Tie into jewelry log, punch holes as deep as possible 4. Function test the lock-down screws. 5. Set BPV. 6. Prepare location for arrival of Workover Rig General Workover Procedure 1. Verify Sundry approval acquired 2. MIRU Nordic 3. 3. Circulate KWF and bullhead to formation. Set BPV. 4. ND tree. MU blanking plug. NU and pressure test BOPE to 250/3,500 psi • The tubing is corkscrewed, and we have been unable to get tools down for an accurate SBHP. • The last SBHP was calculated to be 3,863 psi on Dec. 22, 2006, based upon a surface pressure of 1425 psi and mid-pert depth of 6577' TVD. At this pressure, the MASP is expected to be 3205 psi using a 0.1 psi/ft gradient. The current pressure is expected to be lower due to offtake in the area. • Prior to rig arrival, we will inject seawater to the formation, let the well stabilize, and calculate the SBHP to determine the needed KWF. 5. Pull the 2 '/8" completion down to the `DB' packer at 8003' MD. 6. Change out tubing head to accommodate 3-%2" tubing. 7. Run 3-'h" selective single completion. 8. Set upper packer, shear out of PBR. 9. Circulate corrosion inhibited brine. 10. Space out and land completion. RILDS. 11. Pressure test tubing to 2500 psi. Bleed down to 1750 psi. Test IA to 2500 psi for 30 min. and record on chart recorder. 12. Bleed tubing to zero, which should shear the SOV. 13. Freeze protect well. Set two-way check. 14. ND BOP, NU tree & test to 250/5000 psi. 15. Set BPV and RDMO Workover rig. Post-Riq Work 1. Pull BPV 2. RU Slickline: Pull ball & rod, pull RHC plug body, pull SOV, replace w/ DV. 3. Return to injection • Well: 3K-08 2008 RWO PROPOSED COMPLETION API: 500292162100 PTD: 186-126 Wellhead: CIW Gen IV Xmas Tree: 3-1/8"", 5K psi Lift Threads: 3.5" EUE 8rd BPV: CIW 3"'H' • Tubing = 3'/2', 9.3 ppf, L-80, EUE 8rd Mod • 3.5" TRMAXX-5E SSSV @ -1800' w/ 2.813" X profile. • Baker PBR seal assy. at 7794' • Baker 3-1/2" x 7" FHL Pkr @ 7826' '• Baker 3-1/2" CMU w/ 2.75" D profile @ 7964' II • Baker locator w/ 5' seals at 8001' I• Baker'DB' packer at 8003' Directional: Max Incline: 45.3° @ 5000' MD Max Dogleg: 4.2°/100' @ 2700' MD Conductor: 16", 62.5#, H-40 at 110' Surface Casino: 9.625", 36#, J-55 at 4244' Production Casino: 7", 26#, J-55 at 8475' Gas Lift Mandrels: MD TVD Tvpe 7756 6352 KBMG-SOV Infection Mandrels:. 7865 6435 KBMG-DV Perf Zones C-1, B-4: 7916' - 7934' (12 spf) A3: 8102' - 8114' (1 spf) A2: 8140' - 8184' (1 spf) Fill at: 7550' WLM Last Updated: 7-Jan-08 TD: 8,501' RKB Updated by: JBP . . Conoc;Phillips Alaska ,.:"'¡ J'UL 0 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 28, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 6"' , ~ \fb SCANNED AUG 0 1 l007 Dear Mr. Maunder: Enclüsed please fmd a spreadsheet with a list of wells from the Kuparuk field (KRU). Some of these wells were found to have a void in the conductor by surface casing annulus. The volume of annular void subsequently was filled with a corrosion inhibiter 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. Please call Perry Klein or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, ) --\"/ 7/'L'itlo? Perry Kl . ConocoPhillips Well Integrity Supervisor . . jUL 3 1 2007 '> )~ ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 7/28/2007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTO# cement pumped cement date inhibitor sealant date ft bbls ft na qal 3K-1 186-101 19' 2.6 19" 7/7/2007 7 7/27/2007 3K-2 186-102 53' 7.2 9" 7/7/2007 3.7 7/22/2007 3K-3 186-103 43' 5.8 11" 7/7/2007 4.2 7/27/2007 3K-5 186-123 66' 9.0 26" 7/7/2,007 9.6 7/22/2007 3K-6 186-124 58' 7.9 13" 7/10/2007 4.8 7/22/2007 3K-7 186-125 70' 10.5 35" 7/7/2007 13.2 7/22/2007 3K-8 186-126 54' 4.0 9" 7/10/2007 3.6 7/22/2007 3K-9 186-174 26' 9.0 16" 7/10/2007 6 7/22/2007 3K~ 11 186-164 .' 43' 6.5 21" .. 7/10/2007 7.8 . '. . 7/16/2007' 3K-13 186-136 8" none 8" 7/10/2007 3.1 7/16/2007 3K-14 186-137 8" none 8" 7/10/2007 3.1 7/16/2007 3K-15 186-138 50' 6.0 22" 7/10/2007 8.4 7/22/2007 3K-16 186-139 46' 7.0 27" 7/10/2007 9.6 7/22/2007 3K-17 186-152 56' 8.0 30" 7/10/2007 10.7 7/22/2007 3K-18 186-151 38' 5.5 23" 7/10/2007 8.4 7/22/2007 . MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Regg V f I P.I. Supervisor ') ')ê11 511 0(,; DATE: Wednesday, May 17,2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLlPS ALASKA INC 3K-08 KUPARUK RIV UNIT 3K-08 Src: Inspector /'1.1 .... r \~' \':6'0 FROM: Chuck Scheve Petroleum Inspector Well Name: KUPARUK RIV UNIT 3K-08 API Well Number 50-029-2 I 62 I -00-00 Inspector Name: Chuck Scheve Insp Num: mitCS0605 I 5065235 Permit Number: 186-126-0 Inspection Date: 5114/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I 3K-08 !Type Inj. I W I TVD : 6405 i IA ! 2750 ! 3040 I 2750 ! ! I I I P.T. I 1861260 ITypeTest I SPT I Test psi I 1601.25 ! OA I 400 I 450 I 400 I i I , I Interval REQVAR P/F F ,/ Tubing I 2620 I 2620 2620 ! I , Notes This Well has a waiver for Tubing x lA comunication but has previously passed MITs. Attempts to pressure test the IA today unsucessful with pressures bleeding back to starting conditions in less than 5 minutes NON-CONFIDENTIAL Reviewed By: P.I. Suprv 58f.2- Comm SCA~VNEC JUN .1 ~ 20Gb Wednesday, May 17,2006 Page I of I 3K-08 (PTD 186-126) Failed MITlA e Tom, 3K-08 (PTD 186-126) produced water injection failed a witnessed MITIA 05/14/06. This is a waiverd well with a historic 1 way packer leak. The well was shut in 05/14/06 following the failed MITIA I've enclosed a 90 day TIO plot and a well bore schematic. Sincerely Perry Klein ~. ';- 'J:" Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1244 «3K-08.pdf» «3K-08 90 day TIO plotJPG» Content-Description: 3K-08.pdf Content-Type: application/octet-stream Content-Encoding: base64 90 day TIO Content-Description: 3K-08 90 day TIO ploUPG Content-Type: image/jpeg Content-Encoding: base64 1 of 1 5/15/2006 1 :26 PM e e KRU 3K-08 API: 500292162100 Well Type: INJ AnQle (â1 TS: 40 dea ícfJ 7853 SSSV Type: TRDP Oria Comoletion: 9/30/1986 Angle@TD: 39 dea æv 8501 SSSV Annular Fluid: Last W/O: 2/28/1990 Rev Reason: Waiver Water (1796-1797, Iniection OD:2.875) Reference LOQ: Ref Loa Date: Last Update: 12/4/2004 Last Taa: 8384 ID: 8501 ftKB Last .ate: 12/7/1986 Max Hole Anale: 45 dea ícfJ 5000 Gas Lift Description Size Too Bottom TVD Wt Grade Thread ,drel/Dummy CONDUCTOR 16.000 0 110 110 62.50 H-40 Valve 1 SUR. CASING 9.625 0 4244 3758 36.00 J-55 fl756-7757, PROD. CASING 7.000 0 8475 6903 26.00 J-55 OD:5.460) ¡î¡ûìii Size 1 TOD Bottom I TVD I Wt 1 Grade Thread SBR 2.875 1 0 7826 I 6405 1 6.50 1 J-55 EUE AB MOD (7809-7810. 2.875 1 7826 8031 1 6562 1 6.50 1 J-55 EUE AB MOD OD:2.875) Interval TVD Zone Status Ft SPF Date Type Comment 7916 - 7934 6474 - 6488 C-1,UNIT B 18 12 12/2/1986 IPERF 120 deg. phasing; 5" Csg TUBING Gun (0-7826, 8102 - 8102 6616 - 6616 A-3 0 1 12/1/1986 IPERF 4" Csa Gun' o dea. phase OD:2.875. 8106 - 8106 6619 - 6619 A-3 0 1 12/1/1986 IPERF 4" Csg Gun' o dea. ohase ID:2.441 ) 8110 - 8110 6622 - 6622 A-3 0 1 12/1/1986 IPERF 4" Csa Gun' 0 dea. ohase PKR 8114 - 8114 6625 - 6625 A-3 0 1 12/1/1986 IPERF 4" Csa Gun; 0 dea. phase fl826-7827, OD:6.151) 8140 - 8140 6645 - 6645 A-2 0 1 12/1/1986 IPERF 4" CSQ Gun' 0 dea. ohase 8144 - 8144 6648 - 6648 A-2 0 1 12/1/1986 IPERF 4" CSQ Gun; 0 dea. ohase 8152-8152 6654 - 6654 A-2 0 1 12/1/1986 IPERF 4" Csg Gun; 0 dea. phase Injection 8156 - 8156 6657 - 6657 A-2 0 1 12/1/1986 IPERF 4" CSQ Gun' 0 dea. ohase andrelNalve 8160 - 8160 6661 - 6661 A-2 0 1 12/1/1986 IPERF 4" Csa Gun' 0 dea. phase 2 8165 - 8165 6664 - 6664 A-2 0 1 12/1/1986 IPERF 4" CSQ Gun; 0 dea. ohase (7865-7866. 8169 - 8169 6667 - 6667 A-2 0 1 12/1/1986 IPERF 4" CSQ Gun; 0 dea. ohase - I--- 8175-8175 6672 - 6672 A-2 0 1 12/1/1986 IPERF 4" CSQ Gun; 0 dea. ohase TUBING - I-- 8179 - 8184 6675 - 6679 A-2 5 1 12/1/1986 IPERF 4" CSQ!Ïäì 0 dea. ohase fl826-8031 , - I--- OD:2.875, - I--- ID:2.441) - I-- St MD TVD Man Man Type V Mfr V Type VOD Latch Port TRO Date Vlv - I--- Mfr Run Cmnt 1 I 77561 63521 Merla 1 TGPD DMY 1 1.5 TG I 0.000 0 2/28/1990 I Injection andrelNalve St MD TVD Man Man Type V Mfr V Type VOD Latch Port TRO Date Vlv 3 Mfr Run Cmnt fl964-7965, 2 7865 6435 Merla TMPD CV 1.0 BK 0.000 0 2/25/1990 3 7964 6511 Merla TMPD CV 1.0 BK 0.000 0 2/25/1990 PKR Depth TVD Type Descriotion ID (8003-8004, 1796 1794 SSSV Cameo'TRDP-1A-SSA'. 2/20/00 - Pulled Frac Sleeve. 2.312 OD:6.151) 7809 6392 SBR Cameo 'OEJ' 2.312 7826 6405 PKR Cameo 'HRP-1-SP' 2.347 8003 6540 PKR Baker 'DB' 3.250 8020 6553 NIP Cameo 'D' Nipple NO GO 2.250 NIP 8031 6562 SOS Cameo 'PE-500' 2.441 (8020-8021, 8031 6562 TTL 2.441 OD:2.875) i,i'iii Date Note 5/20/1990 Determined the TBG is CORKSCREWED ícfJ 7550' ISLM\: See WSR's 4/11/90 to 5/20/90 2/5/2000 CONFIRMED CORKSCREWED TUBING POSSIBLY FROM 6000' TO 7737 WLM SEE WSR. TTL 11/112004 WAIVER WATER INJECTION ONLY - T x IA COMMUNICATION (8031-8032, OD2.875) Perf - - (8102-8102) - - Perf - - (8106-8106) = = Perf - - (8140-8140) - - Perf = - (8144-8144) - - - Perf - - (8169-8169) - - Perf - - (8179-8184) - - - - - Re: CPAI Kuparuk Wells 3K-08 and 3K-09 ;¡..~ NSK Problem Well Supv wrote: Lou, Below is a follow-up on the 2 wells you discussed with Wrongway during state SVS testing. The injection rate on 3K-08 was reduced from 400 bpd to 200 bpd, subsequently reducing the IA pressure from 3050 psi to 2910 psi. The OA pressure on 3K-09 was bled from 925 psi to 500 psi. The OA pressure will be monitored for a pressure build up rate. Please call with any questions. Brad Gathman ConocoPhillips Alaska Inc. Problem Well Supervisor 907-659-7224 SC,ANNED MAY 2 {3 200S Thanx Brad, I appreciate your attention to this matter. 1 of 1 5/6/2005 4:25 PM 1. Type of Request: Abandon ~ -0 -¥~~ STATE OF ALASKA RECEIVEDJ ALASKA OIL AND GAS CONSERVATION COMMISSION V APPLICATION FOR SUNDRY APPROVAL MAY 202004 ~ 0 20 AAC 25.280 -^l3ska Oi! & 5:::1 :..;::;~..~. ~.......~:¡'¡~;j 0 Suspend Operation Shutdown 0 Perforate U 'it'~~~c8r I r Disp. 0 0 -" .." 0 P"9 P"om"'" 0 Stirn,"'" 0 TIm, """00 '$f(%.~" [2] 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 4. Current Well Class: 5. Permit to Drill Number: ~ ~ Alter casing Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 69' Development Stratigraphic 0 0 Exploratory 0 Service 0 .186-126 6. API Number: 50-029-21621-00 9. Well Name and Number: 3K-08 10. FieldlPool(s): Kuparuk Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): Junk (measured): 6833 MD 110' TVD 110 Burst Collapse 8. Property Designation: Kuparuk River Unit 11. Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 8501' 6924' 8386 Casing Length Size CONDUCTOR 110' 16" SUR. CASING 4175' 9-5/8" PROD. CASING 8406' 7" 4244' 8475' 3758 6903 Perforation Depth MD (ft): 7916-7934,8102-8184' Packers and SSSV Type: pkr= CAMCO 'HRP-1-SP'; BAKER 'DB' SSSV= SSSV 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Perforation Depth TVD (ft): 6474-6488,6616-6679' Tubing Size: 2-7/8" Tubing Grade: J-55 Tubing MD (ft): 8031' August 1. 2003 Date: Packers and SSSV MD (ft) pkr= 7826'; 8003' SSSV= 1796' 13. Well Class after proposed work: Exploratory 0 Development 0 15. Well Status after proposed work: Oil 0 Gas 0 WAG 0 GINJ 0 Service 0 Plugged 0 WINJ 0 Abandoned 0 WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name derry DethlefSO~ Signature 7~ c. Commission Use Only [Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ~ ~ \\:.. Q. C)\-J ~ ..30 Ý - 19 iJ Contact: Jerry Dethlefs @ 659-7224 Title: Problem Well Supervisor Phone 659-7224 Date ~~,- Plug Integrity 0 BOP Test 0 Mechanical Integrity Test ~ Location Clearance 0 Other: t\\'\ \.~ <:)..~ ~~~~ ~~" ~\\ ~~~~d ~D ~~N\C8-. <::..~ V\ ""~'1 ÐIê (\~Es<:;'~/ ~'ð"-\\'\""\ ~\>~~\I;'--~ ~~ <t)0-'\\ \J'J~'\. ,,~~,,"~~a(¡\ Subsequent Form Required: Cr;&;;[J::::] ~¡f1r.~d 3)/ Jtì:1JTJ ;" i'Júrm:m IIDtS BFL Approved by: COMMISSIONER BY ORDER OF THE COMMISSION JtJN O.~ 1nnA Daæ f; /i ;6 t/ Form 10-403 Revised 2/2003 . ORIGINAL SUBMIT IN DUPLICATE ~ ~ .- ConocoPhillips Alaska, Inc. Kuparuk We1l3K-08 (PTD 1861260) SUNDRY NOTICE 10-403 REQUEST 5/18/04 The purpose of this Sundry Notice is for approval to inject water into Kuparuk well 3K-08 that shows indications ofT x IA communication. 3K-08 is a water injection well that has been shut-in since 11/10/03 due to a damaged flowline. The flowline will be repaired in the next few weeks and the well returned to injection. 3K-08 passed MIT-IA tests 07/07/03, 08/02/03, and recently on 05/17/04 (test form attached). The MITs pass solidly. However, the tubing and IA pressures tend to track. Bleed events have shown that the IA will not readily bleed down below tubing pressure and will equalize rapidly after bleeding. It is unknown what the leak mechanism is-the tubing is corkscrewed and wireline tools cannot be run into the well. Likely candidates are a leaking SBR or leaking packer. ConocoPhillips proposes the following plan for returning this well to service: 1. Receive AOGCC approval for a 2-year period; 2. The well will be used for water-only injection; 3. Daily flow rates and wellhead pressures will be reported on the Monthly Failed MIT Report; 4. MIT tests will be performed on the IA every two years; 5. The AOGCC will be notified should MIT tests fail or if rates/pressures indicate additional problems exist. NSK Problem Well Supervisor 05/18/04 SSSV (1796-1797, 00:2.875) SBR (7809-7810, 00:2.875) TUBING (0-7826, 00:2.875, 10:2.441) Injection \1andrelNaive 2 (7865-7866, 00:4.750) Injection \1andrelNalve 3 (7964-7965, 00:4.750) PKR (!KXJ3.8004, 00.6.151) NIP (8020-0021, OD:2.875) Perf (8102-8102) Perf (8140-8140) Perf (8169-8169) Perf (8179-8184) ~ ~ ConocoPhillips Alaska, Inc. ~ :&1 'k ., KRU 3K-O8 .3K"ÐS API: 500292162100 SSSV Type: TRDP Well Type: INJ Orig 9/30/1986 Completion: Last W/O: 2/28/1990 Ref Log Date: TD: 8501 ftKB Max Hole Angle: 45 deg @ 5000 Angle @ TS: 40 deg @ 7853 Angle @ TD: 39 deg @ 8501 Annular Fluid: Reference Log: LastTag: 8384 LastTa~ Date: 12/7/1986 OáaingString -ALLSTRIIfGS Description Size Top Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 110 110 62.50 H-40 SUR. CASING 9.625 0 4244 3758 36.00 J-55 PROD. CASING 7.000 0 8475 6903 26.00 J-55 :Tubing;String";TUBÎNG (O~inåIConìPtëtion TBG$TRlNG' ;,eft.in ;Hole. fl '_6' o.8Ø31'i .' Size I Top Bottom I TVD I Wt I Grade I Thread 2.875 0 7826 6405 6.50 J-55 EUEABMOD 2.875 7826 8031 6562 6.50 J-55 EUEAB MOD Perforations Sl.fmmar9 .. ".. . .." . Interval TVD Zone Status Ft SPF Date Type Comment 7916-7934 6474-6488 C-1,UNIT 18 1212/2/1986 IPERF 120deg.phasing;5"Csg B G~ A-3 0 12/1/1986 IPERF 4" Csg Gun; 0 deg. phase A-3 0 12/1/1986 IPERF 4" CsQ Gun; 0 deg. phase A-3 0 12/1/1986 IPERF 4" CsQ Gun; 0 deg. phase A-3 0 12/1/1986 IPERF 4" CsQ Gun; 0 deg. phase A-2 0 12/1/1986 IPERF 4" CsQ Gun; 0 dell. phase A-2 0 12/1/1986 IPERF 4" CsQ Gun; 0 deg. phase A-2 0 12/1/1986 'PERF 4" Csg Gun; 0 deg. phase A-2 0 12/1/1986 IPERF 4" CsQ Gun; 0 deg. phase A-2 0 12/1/1986 IPERF 4" CsQ Gun; 0 deg. phase A-2 0 12/1/1986 IPERF 4" Csg Gun; 0 deg. phase A-2 0 12/1/1986 IPERF 4" Csg Gun; 0 deg. phase A-2 0 12/1/1986 'PERF 4" Csg Gun; 0 deg. phase A-2 5 12/1/1986 IPERF 4" CsgGun; 0 .de~.phase Rev Reason: Temporary Waiver Last Update: 8130/2003 8102-8102 6616-6616 8106-8106 6619-6619 8110-8110 6622-6622 8114 - 8114 6625 - 6625 8140 - 8140 6645 - 6645 8144 - 8144 6648 - 6648 8152-8152 6654-6654 8156-8156 6657-6657 8160 - 8160 6661 - 6661 8165-8165 6664-6664 8169-8169 6667-6667 8175 - 8175 6672 - 6672 8179 - 8184 6675 - 6679 Ga$ Lift MandteisNalves . St I MD I TVD I :~ I :v;: I V Mfr I V Type I V OD I Latch I Port I TRO I ~~~ I C~~t 1 7756 6352 Merta TGPD DMY 1.5 TG 0.000 0 2/28/1990 h')jectJoDlllan1trelsNåJVe$ . ... St MD TVD Man Man V Mfr V Type V OD Latch Port TRO Date Vlv Mfr Type Run Cmnt 2 7865 6435 Merta TMPD CV 1.0 BK 0.000 0 2/25/1990 3 7964 6511 Merta TMPD CV 1.0 BK 0.000 0 2125/1990 Other (.1109S, e.auip.,èt<::. - JEWEL.RY.(Originat TBG STRING L"efto in.Hore fir_ )' (HRP;1.iSP J:iKft> to; Depth TVD Type Description ID 1796 1794 SSSV Camco'TRDP-1A-SSA'. 2120/00 - Pulled Frac Sleeve. 2.312 7809 6392 SBR Cameo 'OEJ' 2.312 7826 6405 PKR Cameo 'HRP-1-SP' 2.347 8003 6540 PKR Baker 'DB' 3.250 8020 6553 NIP Cameo 'D' Nipple NO GO 2.250 8031 6562 SOS Cameo 'PE-500' 2.441 8031 6562 TTL 2.441 GeneraFNotei¡' .' Date Note 5/20/1990 Determined the TBG is CORKSCREWED @ 7550' (SLM); See WSR's 4/11/90 to 5/20/90 2/512000 CONFIRMED CORKSCREWED TUBING POSSIBLY FROM 6000' TO 7737 WLM, SEE WSR. 8/3/2003 TEMPORARY WAIVER: T x IA COMMUNICATION, IA < 3000 psi (EXPIRES 211/2004) ~ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Tom_Maunder@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; and Jim_Regg@admin.state.ak. OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. KRU 3K-08 05/17/04 Rogers I 8auvajeau NA Packer Depth Pretest Initial 15 Min. 30 Min. we1l13K-08 I Type Inj IN I T.V.D. I 6402 I Tubing I 811 511 511 511'ntervall 0 P.T.D. 1861260 Type Test P Test psi 1601 Casing 1940 3000 2950 2940 P/F P Notes: Well not injecting-flowline repairs in progress. MIT for AOGCC approval with T x IA communication weill I Type Inj I I T.V.D. I I Tubing I P.T.D. Type Test Test psi 1500 Casing Notes: weill I Type Inj I I T.V.D. I I Tubing I P.T.D. Type Test Test psi 1500 Casing Notes: weill I Type Inj I I T.V.D'I I Tubing I P.T.D. Type Test Test psi 1500 Casing Notes: weill I Type Inj I I T.V.D. I I Tubing I P.T.D. Type Test Test psi 1500 Casing Notes: Test Details: I Interval I P/F I Interval I P/F I Interval I P/F Intervall P/F TYPE INJ codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover 0 = Other (describe in notes) MIT Report Form Revised: 05/19/02 MIT KRU 3K-08 05-17-04.xls 5/18/2004 ./""""'., ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Tom_Maunder@admin.state.ak.us and Bob_Fleckenstein@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk/ KRU/ 3K 08/02/03 Arend - APC we1l13K-08 1 Type Inj 1 P.T.D. 1861260 Type Test Notes: MITIA for diagnostics s P Packer Depth Pretest Initial 15 Min. 30 Min. I T.V.D. I 6540 1 Tubing I 25001 25001 25001 25001 Interval I 0 Test psi 1635 Casing 2600 3500 3450 3450 P/F P OA 0 0 0 0 well P.T.D. Notes: Test Details: TYPE INJ codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover 0 = Other (describe in notes) MIT Report Form Revised: 05/19/02 KRU MIT 3K 08-02-03.xls 5/18/2004 ~ ~ UI C File Review Date: May 28, 2004 Subject: CPAI KRU Well3K-08 PTD#: 403-304-190 AIO2B \ ~ Tom Maunder, P .E. W-~~(' ( 186-126 Orders: Reviewers: Initiating Action: Application for Waiver to Continue Injection with T x IA Communication Review Summary 1. This well was drilled in October 1986. 2. Nothing remarkable is reported for either hole section and both casing strings were run and cemented successfully. Cement is not reported to surface on the surface casing, but no top job was performed. 3. The well was Arctic Paked, not long after drilling was completed. 4. It is reported that a CBL was run 11/15/86. I have performed the MIT II spreadsheet calculation and sufficient cement was pumped. I examined the bond log in the log files. The presentation is not the best. There is cement indicated across the perforated intervals, however the cement quality degrades about 60' above the top perf. Some better quality is evident beginning about 200' above the perforations, however overall the bonding quality is generally poor. John Boyd performed a MIT Part II in May 1988. His calculations are not correct although he does conclude that sufficient cement was pumped to cover the interval. He notes that "Adequate bonding appears above the perfs", although the log presentation is generally poor. 5. Examination of the RBDMS production report for the time prior to conversion shows that the well essentially did not produce any water. 6. The well was fracture stimulated in January 1987. No problems were reported. 7. In September 1987, a 403 was submitted proposing to convert the well to water injection service. 8. There is no report of the initial MIT when converted. 9. In February 1990, the well was worked over to repair corkscrewed tubing. 10. The record reports that the well passed a MIT after the workover and the information was sent to Lonnie Smith. 11. In September 1991, corkscrewed tubing was again noted and permission received to estimated the injection split between the A and C sands. 12. There is no further information in the file until the stimulation reported below. 13. The well was stimulated again in February 2000. No sundry was submitted prior to performing the work. 14. According to the RBDMS injection report, no MI has ever been injected into the well and the well has not been in service since early July 2003 15. According to CPA!, the well will successfully pass a standard MIT however the tubing and IA pressures tend to track and bleeding is not effective. 16. I have not found any document submitted by CPA! reporting any communication. ~ 1'""'"\ " 17. CP AI desires to return the well to service, proposing to keep the well in water only service, submit the monthly monitoring information and perform a MIT-IA every 2 years. Review Conclusions: 1. 3K-O8 is within the effective area of AID 2B. 2. No problems were reported drilling any hole section or cementing any casing. Cement to surface was not stated, however no remedial activity was performed. 3. A bond log was run in the 7" casing and an MIT II analysis was performed in May 1988. Based on the volume pumped, more than sufficient cement was pumped. The bond log in the file generally indicates poor cement quality. Some isolation is evident and likely was "improved" while the well was produced. 4. Isolation is supported by the production report that shows the well essentially produced no water. S. According to CP AI, the well will pass a standard MITIA, however communication is evident when the well is operating. "One way" leaks are known to exist in other wells. 6. CP AI has proposed to keep this well in WATER ONLY service, add this well to the monthly monitoring list and perform a MIT-IA every 2 years. These are the standard conditions that have been applied to wells with similar leaks. Recommendation 1. I recommend approval ofCPAl's request with the following exception. A CMIT may be necessary if a differential pressure cannot be maintained between the tubing and IA. ,......, ,.-..... MECHANICAL INTEGRITY REPORT . OPER & FIELD WELL NUMBER A\~Cv Kv~~~vk k\~,LJ --j ~ - (? WELL DATA '. i I "' TD: 2'£" \() MD b q ~~.. TVD; PBTD: 2 J ¿!~' MD 6ð" y(f "øTVD Casing :q7¿r'1 -2r Shoe: '/:>1/1.// MD Liner: ) 1\ d r Shoe: 8'7"7 S-,r MD ¡i;..ic,. Tubing: ~ 7?rl Packer' 'f1)~2 MD TVD; DV: MD TVD TVD ~ ,,\ TVD; TOP: :'v"-\"'. MD TVD; Set at ~O311' Hole Size 3//'!< and /~Ý.r/( r ; Perfs 7 '1'1 G to '?J!Y,r MECHANICAL INTEGRITY - PART #1 Annulus Press Test: IP 15 min 30 min Comments: . ?1'1:::,/82"'" 8 ,., J Y' 'Y'/" , -'W'-::' J .Joe -;' 'r c ;>~ :;::. . /:::::'8 v MECHANICAL INTEGRITY - PART #2 ( 7'>-;< 'f:¿- -:;,. ,/'/~' Cement Volumes: Amt. Liner 335..}')( ; Csg )00 J'f.- ; DV Cmt vol to cover perfs (111'75 -3226),/(126";- (gço::J -?v')~r).:;:?6¿?+- ( P,YJ-"--~9/~J, logy:=:. 11-1-9"';-6/ =27 J-\-- -A e~VtI' De,,-fJ. \ '" . ~ -_./ , Theoretical TOC ?2'::--J1:ì :::::dl."lP'I'~."'I/Qðý':" ",I__{. tI\.'?Jé:;-" .D'\ C~~\ ~ "PI c~r"~._""",--~ (\-'-- ¡\~c 56 'à.9 / t)~ ;J Cement Bon~ rI; (Yes or No) Ya..J ; In AOGCC File YLJ (L (L, ;::jfÇ' '":5 ~ CBL E 1 t b f B " "': ...L f 'f" ^ C va ua ion, zone a ove per s ,-,""(d f 1-:::.: ¿- ~r7'-1 (ptr_e-t(ð "T' ...)" h 2000 f'Þ' A./.\ v .-1, ~O,. íÜ 0.. rp€'~' ( o.b::Nc ~'-f.1', Production Log: Type ; Evaluation ft ~-f-.:: CONCLUSIONS: . Part #1: Part 1/:2: \N\~<:c\'r.Q"': \, \. .-¡ f . -1--",11'" ~ CI ; €!'ð. /5 /;., cV\ ,+~~G,J æ $'-//-<3'( 'V" #: rev. OS/20/87 C.O28 1U>: l\..UparUK lYUI r--. ~ 5Mbject: RE: Kuparuk MIT From: NSK Problem Well Supv <nI617@conocophillips.com> Date: Thu, 20 May 2004 10: 15 :31 -0800 To: Thomas Maunder <tom_maunder@admin.state.ak.us> Tom, No, there isn't any tbg pressure data for the MIT. Based on monitoring over the past year, the tbg pressure has been running about 100 psi less than the IA pressure. Marie -----Original Message----- From: Thomas Maunder [mailto:tom maunder@ad~in.state.ak.us] Sent: Thursday, May 20, 2004 10:01 AM To: NSK Problem Well Supv Subject: Re: Kuparuk MIT Jerry, There is no tubing pressure noted on the MIT report. information?? Tom Do you have any NSK Problem Well Supv wrote: Tom: Attached is an MIT form for Kuparuk well 3K-08. I am sending a 10-403 approval to you via mail for approval to inject with T x IA communication. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7224 «MIT KRU 3K-08 05-17-04.xls» 1 of 1 5/20/2004 10:57 AM RE: 3K-08 . Subject: RE: 3K-08 From: NSK Problem Well Supv <n1617@conocophillips.com> Date: Thu, 20 May 2004 10:47:14 -0800 To: Thomas Maunder <tom_maunder@admin.state.ak.us> '.. Tom, I double checked the files with the hope that maybe the corkscrewed note was inadvertently carried forward after the WO, but no such luck. The tbg is definately still corkscrewed after the 1990 WOo The workover was done 2/90 and SL diagnosed corkscrewed tbg in 5/90. corkscrewed tbg symptoms in the wellfile since the 5/90 work. There are several other reports of Thanks for asking about this. ) Marie -----Original Message----- From: Thomas Maunder [~~_iJ!:C?: .:t:o.~-:,,!~~~de~~_a..c!r:!1..J-_~.:..?taJ:~..:9~ ..:..1:l§'] Sent: Thursday, May 20, 2004 9:55 AM To: NSK Problem Well Supv Subject: 3K-08 Marie or Jerry, I was just looking through the well file as I work on the sundry for 3K-08. In the new application it is noted that there might be cork screwed tubing. This is interesting since prior to converting the well to injection in 1990 a workover needed to be performed due to cork screwed tubing. Coincidence?? Tom ) 1 of 1 5/28/2004 9:29 AM Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth NO. 2926 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 07/31/03 Field: Kuparuk Well Job # Log Description Date BL Color CD 16-10 i ~_~ )~' I,_'~.© SBHP 07/21/03 ! su,v 1D-140 ~-~ ~ SBHP 07122/03 1J-10 ~.,~-~7~ ~ SBHP 07121/03 26-01 ~ ~-~...~ PRODUCTION PROFILE .07/19/03 26-02 ~[- ~ PRODUCTION PROFILE 07/20/03 2S-14 ~- ~ ~ ~ PRODUCTION PROFILE 07/23/03 2E-~ ~ ~.g]_..~:~ PRODUCTION PROFILE 07/18/03 3F-13A ~C( ~'-~:~'~ LDL 07/17/03 3K-08 ~'~ ~ LDL 07/25/03 3M-03!~~ IL~ LDL 07/24103 36-~9 ~-~ PERF/JEWELRY/& INITIAL SBHPS 07/11/03 DATE: ' ' ': ~ Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other__ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__ RKB 69 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic_ Anchorage, AK 99510-0360 service__x Kuparuk Unit 4. Location of well at surface 8. Well number 1259' FSL, 317' FWL, Sec. 35, T13N, R9E, UM (asp's 529304, 6008253) 3K-08i At top of productive interval 9. Permit number / approval number 1006' FSL, 1760' FEL, Sec. 34, T13N, R9E, UM (asp's 525469, 6007986) 186-126 At effective depth 10. APl number 50-029-21621 At total depth 11. Field / Pool 915' FSL, 1358' FWL, Sec. 34, T13N, R9E, UM (asp's 525068, 6007894) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 8501 feet Plugs(measured) R~C~'IVED true vertical 6924 feet Effective depth: measured 8386 feet Junk(measured) ~AF{ ~ 7 2001 true vertical 6833 feet ~t;'.i5J~a 0il & Gas C,;~;ts. [;ommissi¢,; Casing Length Size Cemented Measured Depth *~'tt'~('~J~'~'[i'~'i{~ertical Depth CONDUCTOR 110' 16" 1540 Sx Poleset 110' 110' SURF CASING 4175' 9-5/8" 1200 Sx AS IV & 300 Sx 4244' 3758' Class G PROD CASING 8406' 7" 335 Sx G & 175 Sx AS I 8475' 6903' Perforation depth: measured 7916 -7934'; 8102'; 8106'; 8110'; 8114'; 8140'; 8152'; 8156'; 8160'; 8165'; 8169'; 8175'; 8179 - 8184' true vertical 6474 - 6488'; 6616'; 6619'; 6622'; 6625'; 5545'; 6654'; 6657'; 6661'; 6664'; 6667'; 6672'; 6675 - 6679' Tubing (size, grade, and measured depth) 2.875", 6.5#, J-55, Tubing @ 8031' MD. Packers & SSSV (type & measured depth) Camco 'HRP-I-SP' Packer @ 7826' MD; Baker 'DB' @ 8003' MD. Camco 'TRDP-1A-SSA'. 2/20/00 - Pulled Frac Sleeve @ 1796' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation - - 630 - 2900 Subsequent to operation - - 675 - 2800 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations __X Oil m Gas __ Suspended _ Service ~(Water Inj).~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~'~'"~ Prepared by J°hr;' P~irce 265-6471 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE'~ 3K-08i DESCRIPTION OF WORK COMPLETED HIGH PRESSURE BREAKDOWN TREATMENT 2/16100: MIRU & PT equipment. Pumped a Fullbore High Pressure Breakdown treatment through the open perforation intervals located at: 7916 - 7934' MD 81 O2' MD 8106' MD 8110' MD 8114' MD 8140' MD 8152' MD 8156' MD 8160' MD 8165' MD 8169' MD 8175' MD 8179 - 8184' MD Pumped Stage #1: a) 300 bbls Slick Seawater @ 21 bpm, followed by b) Shutdown. ISIP @ 3295. Pumped Stage #2: c) 400 bbls Slick Seawater @ 21 bpm, followed by d) Shutdown. ISIP @ 3245. Pumped Stage #3: e) 676 bbls Slick Seawater @ 21 bpm 7 7300 psi, followed by f) Shutdown. Returned the well to water injection & obtained a valid injection rate. ATTACHMENT 1 KUPARUK RIVER FIELD CONSERVATION ORDER 198 RULE 4 - INJECTIVITY PROFILES THIRD QUARTER 1991 SUBMITTAL WELL NUMBER AP1 DATE OF DATE OF DATA TYPE NUMBER INITIAL PROFILE/ PROFILE/ 50- INJECTION SURVEY SURVEY lA-14 02920706 2/22/83 7/29/91 SPINNER 1F-04 IF-il 1F-15 1G-05 1G-06 1Q-Il 1Y-13 2A-08 2B-09 2K-06 3A-07 3K-08 3M-21 02920811 10/28/85 1/2/91 SEP ZONE 02920993 8/12/84 8/1/91 SEP ZONE 02921025 8/16/84 4/28/91 SPINNER 02920908 02920890 02921216 02920903 10320049 2921082 10320110 12/6/87 7/28/84 11/16/85 10/28/85 2/24/88 11/24/85 4/9/91 4/28/91 3/1/9o 9/28/91 7/1/91 7/31/91 9/3/91 9/2/91 REASON FOR PROFILE/ SURVEY FOLLOWUP FOLLOWUP FOLLOWUP FOLLOWUP SPINNERS_- FOLLOWUP SEP ZON~%~ ~.~ ~4~LLOWUP SPINNE~~ ~ ~OWUP C~ c~ F~OWUP HEP ~ONE SPINNER ~' INITIAL SPINNER INITIAL 2144400 1/12/91 6/4/91 SEP ZONE INITIAL 3/4/90 4/20/88 9/26/91 4/20/91 2921621 2921739 ESTIMATE (PER INITIAL 9/9/91 VARIANCE) SEP ZONE FOLLOWUP WELL COMPLETION A&C SS A&C SS A&C SS A&C SS A&C SS A&C SS A&C SS A&C S A&C SS A&C SS A&C S A&C SS A&C SS A&C SS ZONES TAKING WATER INJECTION BWPD 498 884 5.1 MMSCFD 0.5 MMSCFD 4.88 MMSCFD 1.22 MMSCFD 1196 1104 140 4560 1000 4200 315 3185 1045 6185 1297 2029 463 4443 2400 0 1090 960 635 115 170 1530 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Pull tubing Alter casing 2. Name of Operator 15. Type of Well: Development ARCO Alaska. If3(;;, Exploratory 3. Address Stratigraphic P. O. Box 100360, Anchorage, AK 99510 Sewice 4. Location of well at surface 1259' FSL, 317' FWL, SEC.35, T13N, R9E, UM At top of productive intewal 1006' FSL, 1760' FWL, SEC.34, T13N, R9E, UM At effective depth 930' FSL, 1428' FWL, SEC.34, T13N, R9E, UM At total depth 915' FSL: 1358' FWL: SEC.34: T13N~ R9E~ UM 12. Present well condition summary Total Depth: Stimulate Plugging ~ Perforate Repair well Other measured 8 5 0 0' feet Plugs (measured) true vertical 6922' feet 6. Datum elevation (DF or KB) RKB 69' 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3K-08 9. Permit number/approval number 86-12§ / 91-271 10. APl number 50-029-2162100 11. Field/pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured 8 386' feet Junk (measured) true vertical 6 8 3 3' feet Structural Conductor 80' surface 4 2 0 7' Intermediate Production 8 4 4 3' Liner Perforation depth: measured 7916'-7934', Cemented Measured depth True vertical depth 110' 110' 4244' 3757' 8475' 6903' 1 6" 1540ft POLESET 9-5/8" 1200 SX AS III & 300 SX CLASS G 7" 335 SX CLASS G & 175 SX AS I 8102', 8106', 8110', 8114'; 81'40', 8144', 8152', 8156' 8160', 81 65', 81 69', 8175', 8179'-8184' true vertical 6473'-6487', 6616', 6619', 6622', 6625', 6644', 6647', 6660', 6663', 6666', 6671', 6674'-5576' Tubing (size, grade, and measured depth) 2-7/8 J-55 TBG w/TAIL @ 8035' Pa~em ~d SSSV (~ ~d m~r~ ~p~) HR-1-SP PKR ~ 7830'~ DB PKR ~ 8007'/CAMCO TRDP-1A-SSA SSSV ~ 1790' 13. Stimulat~n ~ ~ment squ~ze summary RULE 4 SU~I~AL A~ACHED Intewals treated (measure) Treatment description in~uding v~um~ us~ ~d fin~ pr~surel 14. Prior to well operation Reoresentaflve Daily Averaae Production or Iniectiorl Dsm OiI-Bbl Gas-lVlcf Water-Bbl Casing Pressure Tubing Pressure Subse~luent to operation 15. Attachments 16. Status of well classification as: · Copies of Logs and Surveys run __ Water Injector _X Daily Report of Well Operations ~ Oil Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service Form 10-404 Rev 09/12/90 Title Petroleum Engineer Date 3/'¢¢'/¢-~ SUBMIT IN DUPLICAT~= STATE OF ALASKA ~ O~.AND ~ ~A~(~ APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Opera~ Shutdown _ Re-enter suspended well Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate __ Chant~e approved pro, ram _ Pull tubing _ Variance X Perforate _ 2o Name of Operator 5. Type of Well: Expiratory _ Stratigraphic _ Service _ ARCO Alaska. Inc, 3. Address P. O. Box 100360, Anchora~le, AK 99510 4. Location of well at surface 1259' FSL, 317' FWL, Sec. 35, T13N, R9E, UM At top of productive interval 1006' FSL, 1760' FWL, Sec. 34, T13N, R9E, UM At effective depth 930' FSL, 1428' FWL, Sec.34, T13N, R9E, UM At total depth 915' FSL~ 1358' FWL~ Sec. 34~ T13N~ R9E~ UM 12. Present well condition summery Total Depth: Effective depth: measured true vertical measured true vertical 80' 4207' 8500' 6922' 8386' 6833' 16" 9 5/8" 8443' 7" feet Plugs (measured) feet Norle feet Junk (measured) feet None Other Structural Conductor Surface Intermediate Production Uner Perforation depth: 6. Datum elevation (DF or KB) RKB 69 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 3K-08 9. Permit number 86-126 10. APl number so-029-21621 11. F~d/Po~ Kuparuk River Field ~ Kuparuk River Oil Pool C.,ernented Measured depth True vertical depth 1540# Poleset 1 1 0' 1 1 0' 1200 Sx AS III & 4244' 3757' 300 Sx Class G 335 Sx Class G & 8475' 6903' 175 Sx AS I 8140', 8144', 8152', 8156', 6644', 6647', 6654', 6657', measured 7916'-7934', 8102', 8106', 8110', 8114', 8160', 8165', 8169', 8175', 8179'-8184' true vertical 6473'-6487., 6616', 6619', 6622', 6625', 6660', 6663', 6666', 6671', 6674'-6678' Tubing (size, grade, and measured depth) 2 7/8" J-55 w/ tbg tail at 8035' Packers and SSSV (type and measured deplh) HR-I-SP pkr at 7830'7 DB pkr at 8007' & TRDP-1A-SSSA SSSV at 1790' 13. Attachments Description summary of proposal .~. 14. Estimated date for commencing operation AS~,~ o~ _ 16. If proposal was verbally approved Name of approver Date approved Service Water I n!ector Conditions of al~oval: Noti~/ Commission ~o r~:we~tati~ me¥ ~ IAl~'o~al No. Plug integrity ~ BOP Test_ Location clearance__ ~--'~/ --~ ?' / Mechanical Integrity Test ._. Subsequent form require 10-~rov~O. Ccpy I /r Returned Approved by order of the Commission '~,,~:w ~ ~MITH Commissioner Date ~-i ~ .... -I i Form 10-403 Rev 09/12/90 SUBMIT IN TRIPLICATE 15. Status of well classification as: _ Suspended _ Attachment Kuparuk Well 3K-08 Appl~tion for Sundry Approval Arco Alaska, Inc requests permission to report estimated A/C split information on Kuparuk Well 3K-08 to satisfy the AOGCC data reporting requirements specified in Rule 4 of Conservation Order Number 198. This well has a tubing restriction above the top packer making it impossible to obtain A/C split information with conventional spinner surveys. KUPARUK WELL 3K-08 APl #: 500292162100 SPUD DATE' O9/23/86 ADL LEASE: 25520 CO~TKDN DATE: 1 ~ PERMIT #: WORKOVER DATE: 88-126 Z/90. ORIGINAL RKB: SURFACE LOCATe: 125~F~317'FWl...~,T13N,RgE TOP OF KUPARUK: 1006'FSL, 1760'I~C34,T13N,RgE TD LOCATION: 915'FSL, 1358'FWI.,SEC34,T13N,R9E 69 TUBING SPOOL: 35 PAD ELEVATION: WELLTYPE: WATER INJECTOR CASING and TUBING DETAILS SIZE WEIGHT GRADE DEPTH !6" 62.5~ ~ 110 9.625' 36~ J-55 4244 7' 26~ J-55 8475 2.875' 6.5# J-55 ABM 8035 BTM LINER DETAILS SIZE WEIGHT GRADE TOP TUBING JEWELRY ITEM TYPE ID DEPTH SSSV CAMCO TRPO-I~ 2.312' 1796 SSR CAMCO OEJ 7805 PKR CAMCO HRP-1-SP 7830 PKR BAKER DB 8007 N~ CAMCO 'D' NIPPLE 2.25' 8024 SHROUT CAMCO PE-500 8034 MISC. DATA DESCRIPTION DEPTH KICK OFF POINT: 1500 MAX HOLE ANGLE: 4~ deg 5(X)O HOLE ANGLE THRU KUP: 40 cleg LAST TAG DATE: RATHOLE: ft FISHK)B,.qTRUGTION: POSSIBLE CORKSCREWE0 TBG PBTD: 8386 L. C. aA~ LJFT lad FLOW INFORMATION VALVE PORT 8TN DEPTH MANDREL SIZE SIZE I /"756 MERLA TGPD i 5= .DV 2 7869 MERLA TMPD 1' .CV 3 7968 MERLA TMPD 1' ,CV INTERVAL 8102-.8102 8106-8106 8110-.8110 6114.-8114, 8140-8140 8144-81,44 8152-8152 815&,815~ 8160-6160 8165..8165 81'79-.8184 &! 1,: -&l 1¢ PERFORATION DATA ZONE FT SPF PHASE COMMENTS Cl 16 12 0 12/2/86 A3 0 1 0 12/2/86 A3 0 1 0 12/2/86 A3 0 1 0 12/2/86 A3 0 1 0 12/2/86 .42 0 1 0 12/2/86 .42 0 1 0 12/2/86 .42 0 1 0 12/2/86 A2 0 1 0 12/2/86 ,42 0 . 1 0 12/2/86 A2 0 1 0 12/2/86 A2 5 1 0 12/2/86 REVISION DATE: 7/20/90 REASON: WORKOVER ARCO Alaska, Inc. ~ Post Office Box 100360 Anchorage, A~aska 99510-0360 Telephone 907 276 1215 April 2, 1990 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached in triplicate are multiple Applications for Sundry Approvals on the following Kuparuk wells. Well Action Anticipated Start Date 3H-04 Stimulate April, 1990 3K-08 Perforate April, 1990 3Q-11 Perforate April, 1990 KRU State #1 Stimulate April, 1990 If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Operations Engineer CC: J. Gruber ATe 1478 J. R. Brandstetter ATe 1120 L. Perini ATe 1130 KeEl .4-9 w/o attachments ARCO Alaska, Inc. is a SL, bsidiary of AtlanticRichficldCompany I~I STATE OF ALASKA '~I ALA~,A OIL AND GAS CONSERVATION COMM~o,51ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Alter casing _ Change approved program _ Suspend _ Operation Shutdown _ Re-enter suspended well _ Repair well _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate X Other _ 6. Datum elevation (DF or KB) 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1259' FSL, 317' FWL, Sec. 35, T13N, R9E, UM At top of productive interval 1006' FSL, 1760' FWL, Sec. 34, T13N, R9E, UM 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service RKB 69 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3K-0~) 9. Permit number 86-1~6 At effective depth 930' FSL, 1428' FWL, Sec.34, T13N, R9E, UM At total depth 915' FSL~ 1358' FWL~ Sec. 34~ T13N~ R9Er UM 12. Present well condition summary Total Depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 8500' true vertical 6 9 2 2' measured 8386' true vertical 683 3' Length Size 80' 16" 4207' 9 5/8" 8443' 7" measured feet Plugs (measured) feet None feet Junk (measured) feet None Cemented 10. APl number so-029-21 621 11. Field/Pool Kuparuk River Field APR - 5 !990 Ai~$k-3..0il & Gas Cons, C0m~[Ss[0~, 'AnchOrage Measured depth '~rue vertical depth 1540# Poleset 110' 110' 1200 Sx AS III & 4244' 3757' 300 Sx Class G 335 Sx Class G & 8475' 6903' 175 Sx AS I 7916'-7934', 8102', 8106', 8110', 8114', 8140', 8144', true vertical 6473'-6487', 6616', 6619', 6622', 6625', 6644', 6647', Tubing (size, grade, and measured depth 2 7/8" J-55, tbg w/tail @ 8035' Packers and SSSV (type and measured depth) HR-1-SP pkr @ 7830'~ DB pkr @ 8007' & TRDP-1A-SSSA SSSV @ 1790' 13. Attachments Description summary of proposal ~ Detailed operation program _ 8152', 8156', 8160', 8165', 8169', 8175', 8179'-8184' 6654', 6657', 6660', 6663', 6666', 6671', 6674'-6678' BOP sketch 14. Estimated date for commencing operation 4/15/90 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil ' Gas B Suspended Service 17. I he~(certify,~that the foregoing is true and correct to the best of my knowledge. Si~ned ~~(~. ~ Title Sr. Operations Engineer FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity B BOP Test~ Location clearance Mechanical Integrity Test~ Subsequent form require 10-./y-o~-i IApproval No. Approved by the order of the Commission ~...~[~i',~AL SIGNED ~Y LONNIE C. SMITH co mmissioner Dat~ Form 10-403 Rev 5/03/89 SUBMIT IN TRIPLICATE Kuparuk Well 3K-8 A Sand Reperforation ARCO Alaska, Inc. requests permission to reperforate the A Sand in Kuparuk Well 3K-8. This well was originally perforated using selective shots between 8102'-8184" MD. We now plan on blanket perforating the A Sand between 8228'-8240', 8130'-8165', and 8090-8118' MD. The expected BHP is 2700 psi. No BOP equipment will be needed. RECEIVED APR - 5 ~990 Anchorage ARCO Alaska Inc. is a subsidiary of Atlantic Richfield Company AR3B-6OO1-A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown __ Pull tubing Z Alter casing Stimulate __ Plugging Perforate Repair well X Pull tubing Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service .Z~ ,-~ 1259' FSL, 317' FWL, Sec. 35, T13N, R9E, UM At top of productive interval 1006' FSL, 1760' FWL, Sec. 34, T13N, R9E, UM At effective depth 930' FNL, 1428' FWL, Sec. 34, T13N, R9E, UM At total depth 915' FSL, 1358' FWL, Sec. 34, T13N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 8 5 0 0' feet Plugs (measured) 6 9 2 2' feet 6. Datum elevation (DF or KB) 69' RKB 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3K-8 9. Permit number/approval number 86-126/90-016 10. APl number 50-02~-21621 11. Field/Pool Kuparuk River Oil Pool Effective depth' measured 8 3 8 6' feet Junk (measured) true vertical 6833' feet Casing Length Size Cemented Measured depth True vertical depth Structural 80' 1 6" 1540# POLESET 1 1 5'md 1 1 5'tvd Surface 4207' 9-5/8" 1200 sx AS III & 4244md 3757'tvd Intermediate 300 SX Class G Production 801 3' 7" 335 Sx Class G & 8475'md 6903'tvd Liner 175 SX AS I Perforation depth: measured 7916'-7934', 8102', 8106', 8110', 8114', 8140', 8144',8152', 8156', 8160', 8165', 8169', 8175', 8179'-8184' true vertical 6473'-6487', 6616', 6619', 6622', 6625', 6644', 6647', 6654', 6657', 6660', 6663', 6666', 6671', 6674'-6678' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, J-55 tbg W/ tail @ 8031' Packers and SSSV (type and measured depth) Camco "HR-I-SP" Pkr @ 7826', Baker "DB" Pkr @ 8003', Camco "TRDP-1A" SSSV @ 1796' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation (producing) Subsequent to operation (injecting) 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations Z Representative Daily Average Production or Injection Data '" ~ .~...;.i i.,.;:i' ire ~' Oil-Bbl Gas-MCf Water-Bbl Casing Pressure Tubing Pressure 16. Status of well classification as: Water Injector X Oil _ Gas Suspended Service _~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 05/17/89 Title Area Drilling Engineer SUBMIT IN DUPLICATE ARCO 0~! and Gas Company Well History - Initial Report - Dali Inetructlonl: Prepare and submit the "lnlUII Report" on the first Wednesday after a well is spudded or workover operations are started. Dally work prior to sPudding should be summarized on the form giving inclusive dates only. District ARCO ALASKA INC. Field KUPARUK RIVER Auth. or W.O. no. AK4427 ICounty. parish or t)orougl~ NORTH SLOPE BOROUGH Lease or Unit ADL: 25202 Title WOR~OV~R State KRU 3K-8 Well no. Operator ARCO Spudded or W.O. begun Date and depth as of 8:00 a.m. 02/27/90 ( TD: 0 PB: 8386 SUPV:DB 02/28/90 ( TD: 0 PB: 8386 SUPV:DB IDate ~our 2/26/90 p6:00 Complete record for each day reposed NORDIC #1 CIRC BEFORE POOH W/TBG 7"@ 8475' MW: 0.0 8.5 SW RU HARD LINE TO FLOW LINE. FILL PITS WITH SW. PULL BPV. SICP=1400 PSI, SITP=600 PSI. BLED DOWN TUBING AND ANNULUS TO FLOWLINE. PUMP 100 BBLS SW DOWN TBG. CIRC SW THRU OPEN GLM TAKING RETURNS TO MANIFOLD BLDG AT 2 BPM. OVERDISPLACED BY 40 BBLS. SITP=SICP= 0 PSI. SET BPV, ND TREE, NU BOPS, PULL BPV. TEST BOPS TO 3000 PSI, CO HYDRAULIC CHOKE, RETESTED OK. PULL TBG HGR, 46K PULL, PULLED CLEAR OF OEJ, REDRESS HGR. CIRC TO CLEAN HOLE. DAILY:S52,637 CUM:$52,637 ETD:SO EFC:$52,637 PULL DV FROM GLM 7"@ 8475' MW: 8.5 8.5 SW CIRC HOLE CLEAN. MONITOR WELL FOR 15 MIN, 2 BBL LOSS. POOH W/TBG, REPLACED BOTTOM 7 CORKSCREWED JTS. RIH W/ 2-7/8" COMP ASSY (243 JTS, ONE GLM, SSSV). STAB OEJ OVER SLICK STICK, SPACE OUT WITH OEJ 1' ABOVE PKR. RUN 8' AND 6' PUPS ONE JT BELOW HGR. MU CONTROL LINE AND TEST OK TO 5000 PSI. LAND TBG AND RILDS. TEST ANNULUS TO 2500 PSI FOR 15 MIN, NO LOSS. SET BPV, ND BOP, NU TREE. TEST TREE TO 5000 PSI OK. RU OTIS TO PULL DV FROM GLM AT 7756'. DAILY:S29,704 CUM:$82,341 ETD:SO EFC:$82,341 ARCO W.I. 55.0000 Prior status it a w.o. The above IS correct SIgnatur~/~P--g~ For form preparation e~d distribution, see Procedures Mang~J Section 10, Drilling, Pages 86 AR3B-459-1-D Number all daily well history forms consecutively as they are prepared for each well. iPage no. / .. · ARCO~ and Gas Company .t NF Daily Well History-Final Reporl Instructions: Prepare and submit the "FIRM ~R~tt" on the first Wednesday after allowable has been assigned or well is Plugged. Abandoned, or Sold. "Final Ral3ort" should be submitted elto ,~t operations ere suspended for an indefinite or al3l~reciable length of time. On workovers when an official test is not required upon coml31etion, re;)ort coml31elJon and rel:~reeentative test data in blocks Drovided. The "Final Report" form may be used for reporting the entire operation if space is available. County or Parish NORTH. ST.O?E BOROUGH Field Lease or Unit IWell no. KU?ARUK RIVER ADL: 25520 KRU 3K-8 Title WORKOVER District ARCO ALASKA INC. Auth. or W.O. no. AK4427 Ol:)eretor ARCO Spudded or W.O. begun Date and depth as of 8:00 a.m. Accounting cost center code State 03/01/90 ( TD: 0 PB: 8386 SUPV:DB A.R.Co. W.I. 55.0000 Date 2/26/90 :Complete record for each day reposed NORDIC #1 Iotal number of wells (active or inactive) on this oat center prior to plugging and bandonment of this well our I Prlor status if a W.O. I 0:600 REL RIG @ 1600 HRS 2/28 7"@ 8475' MW: 0.0 DIESEL RIH WITH OTIS SLICKLINE AND PULL DUMMY AT 7756'. REVERSE CIRC DIESEL INTO ANNULUS AND TBG. SITP=SICP=700 PSI. CLOSE SSSV, BLED TBG TO O PSI TO TEST SSSV, OK. OPEN SSSV, RIH AND SET DUMMY AT 7756'. POH AND RD OTIS. PRESSURE TEST ANNULUS TO 2500 PSI FOR 30 MIN, LOST 60 PSI, OK. AOGCC-LONNIE SMITH WAIVED WITNESSING, FAXED COPY OF NOTES AND PRESSURE CHART TO AOGCC. BLED ANNULUS, SET BPV, SECURE WELL, RELEASE RIG @ 1600 HRS, 2/28/90. DAILY:S32,964 CUM:$115,305 ETD:SO EFC:$115,305 Old TD New TD PB Depth Released rig Date Kind of rig Classifications (oil, gas, etc.) Type completion (single, duel, etc.) Producing method Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval DII or gasTest time Production OII on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Drilling, Pages 86 and 87. AR3B-459-3-C Number all daily well history forms consecutively es they ere prepared for each we I. i Page no. Dlvl~lofl cf AtlentlcRIchfieldCompen' ALA~. ~ OIL AND GAS CONSERVATION COMI~ .ON ~ APPLICATION FOR SUNDRY APPROVALS0 1. Type of Request: Abandon _ 2. Name of Operator Suspend Alter casing _ Repair we Change approved program ~ !1 _~_ Plugging _ ~ Pull tubing _~_ 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service ARCO Alaska. Inc, 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1259' FSL, 317' FWL, Sec. 35, T13N, R9E, UM At top of productive interval 1006' FSL, 1760' FWL, Sec. 34, T13N, R9E, UM Operation Shutdown _ Re-enter suspended well _ Time extension Stimulate Variance _ Perforate _ Other _ 6. Datum elevation (DF or KB) RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 3K-8 feet 9. Permit number 86-126 At effective depth 930' FSL, 1428' FWL, Sec. 34, T13N, R9E, UM At total depth 915' FSL~ 1358' FWLr Sec. 34~ T13Nr R9E~ UM 12. Present well condition summary Total Depth: measured 8 5 0 0' true vertical 6 9 2 2' feet Plugs (measured) feet None Effective depth: measured 8386' feet Junk (measured) true vertical 6 8 3 3' feet None Casing Length Size Cemented Structural Conductor 8 0' 1 6" 1540# Poleset Surface 4207' 9 5/8" 1200 Sx AS III & Intermediate 300 Sx Class G Production 844 3' 7" 335 Sx Class G & Liner 175 Sx AS I Perforation depth: measured 10. APl number 5o-029-21621 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool . ,. Measured depth ' Tt:~b";:i~:i,b~l depth 110' 110' 4244' 3757' 8475' 6903' 7916'-7934', 8102', 8106', 8110', 8114', 8140', 8144', 8152', 8156', 8160', 8165', 8169', 8175', 8179'-8184' true vertical 6473'-6487', 6616', 6619', 6622', 6625', 6644', 6647', 6654', 6657', 6660', 6663', 6666', 6671', 6674'-6678' Tubing (size, grade, and measured depth 2-7/8" J-55, 6.5# tbg w/ tail @ 8035' Packers and SSSV (type and measured depth) Camco HR-1-SP pkr ~ 7830'~ Baker DB pkr @8007', Camco TRDP-1A-SSA SSSV @ 1790' 13. Attachments Description summary of proposal X Detailed operation program _ BOP sketch ~ Proposed workover will repair buckled tubing and allow well 14. Estimated date for commencing operation 15. February 1990 16. If proposal was verbally approved Name of approver Date approved to be converted to injection. 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. FOR COMMISSION USE ONLY Date J/~/~'~..~ Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test Mechanical Integrity Test'~/ -- Approved by the order of the Commission Form 10-403 Rev 06/15/88 IAppr°val y~ Location clearance ~ I Subsequent form require 10- ~o/--)-. ~,~3~3rOVeCt Retut~e SUBMIT IN TRIPLICATE KUPARUK RIVER UNIT 3K-8 Workover Procedure SUMMARY: Kuparuk Well 3K-8 will be worked over to repair buckled tubing. The corkscrewed tubing will not allow the bottom gas lift valve to be replaced with a dummy as required for conversion to injection. The tubing above the retrievable packer will be pulled and inspected. Necessary replacements will be made and the tubing will be rerun to allow this well to begin water injection. A prior sundry application has been approved to convert this well to injection (Appr. No. 7-611). PROCEDURE: 1. Move in and rig up Nordic #1. 2. Displace tubing and annulus with seawater. 3. Nipple down tree and nipple up BOPE. Test same. . Pull out of hole with tubing. Inspect tubing for buckling before rerunning. Remove all gas lift mandrels except for one above retrievable packer (with dummy valve installed). . Run in hole with completion string. Displace annulus with diesel before locating into top of retrievable packer. . Notify AOGCC and perform MIT on annulus for conversion to injection. 7. Nipple down BOPE and install tree. 8. Secure well and release rig. 6 5 4 3 1. 9 5/8' CASING HEAD 11' - 3000 PSI FLANGE 2. 11' - 3000 PSI X 7 1/6' - 3000 PSI TUBING HEAD 3. 7 1/6' - 3000 PSI X 11' - 5000 PSI CROSS-OVER AND SPOC~ 4. 11' - 5000 PSI BUND RAMS 5. 11' - 5000 PSI PIPE RAMS 6. 11' - 5000 PSI ANNULAR ACCUMULATOR CAPACITY TEST 1. CHECKANDFLL~TC~RE~TO~ LEVEL WITH HYORA~ RUE). 2. ASSURE THAT ACCUMUI.ATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNS'TREAM OF ~ ~T~ 3. C~SERVE ~ THEN CA. Q6E ALL uNrr~ SlMUI,TANE(X,ISt.Y AND BOP STACK TEST 1. FlU. BOP STACK AND MANIFCXJ) WITH BRINF_ CHECK THAT ALL ~ SCREW~ ARE FULLY RE11:IACTED. 2. PREDETERMINE DEPTH THAT TEST I:q.Ul3 WlU. ~F. AT AND ~=AT 3. CLOSE AN~ ~ AND ~S AND BYPASS VALVES 4. TEST AU. ~EHTS TO 250 PSI AND HOI. D R3R 10 MINUTES. INCREASE PRESStJRE TO 3000 PSI AND HOLD R3R 10 MINUTES. 5. OPEN ~LAR PREVENTER AND CLOSE PIPE RAM~ 6. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. 7. CLO6E VALVES DFtECTLY UPSTREAM OF CHOKE& BLEED [:X:)WNSTREAM PRESSURE TO ZERO PSI TO TEST VALVE~ TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AM3 WITH ZERO PSI ~TREAI~ BLEED 8. OPEN PIPE RAMS. BACKOFF RUNNING JOINT AND PUU. OUT OF HOLE. 9. CLOSE BUND RAMS AND TEST TO 30(X) PSI FOR 10MINUTES. BLEED TOZF. RO~ 1 0. ~ BUND RAMS AND RECOVER TEST PLIJ~ MAKE SURE MANIFOLD AND UNES ARE FUM. OF BRINE AND AU. VALVES ARE SET IN THE 1 1. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSE)E BOP TO 3000 PSI WTTH KOOMEY 14. SIGN AND SEND TO DRI.UNG StJI:~RVlSOR. 1 5. PERF43::IM(X3MPI. ETEBOPETEST~AWEEKANDRJNCTIONAII Y KUPARUK WELL 3K-08 APl il: 500292162100 SPUD DATE: 09/23/8~ AD[, LEASE: ' 25520 COMPLETION DATE: 12/02/8~ PERMIT Il: WORKOVER DATE: 88-126 SURFACE LOCATION: 125g'FSL,317'FWL, SEC3~.T13N.RgE TOP OF KUPARUK: 100~'FSL. 1760'FWL. SEC34,T13N.RgE TO LOCATION: 915'FSL, t 358'FWI. SEC34,Tt 3N,RgE Al ~1~1~ me IdD. I:I<B t~ IN~ ot ~lUil;m~nt unlmm ~ ~ ORIGINAL RKB: 69 CASING IlXl TUBING DETAILS SIZE WEIGHT GRADE DEPTH 16' ~2.5t H-40 110 9.625' 36# J-55 4244 TUBING SPOOL: 35 WELLTYPE: PRODUCER d .4ER DETAILS SIZE WEIGHT GRADE TOP BTM PAD ELEVATION: 35 STN 1 4 $ GU UR and FLOW INFORMATION VALVE OEPTN MANDREL SIZE 2'~3o MERLA TMPO 1.0" 4~gl MERLA TMPO 1.0' ~ MERLA TMPO 1.0' ~ MERLA TMPO 1 .o' ~ MERLA TMPO 1.o' 72~3 ,MERLA'IMPO , 1.0.' ' 27&1 ~ERLA TGI~) 1.5' 71~ MERLA TMI:~ 1.0' ~ MERLATMPO 1.0' PORT SIZE o.156 o.156 0¥ 0.156 , .DV CV CV TUBING JEWELRY ITEM TYPE ID DEPTH SS~V CAMCO TI:~-I A~ 2.312' 1790 SSR CAMCO OEJ 780~ PKR CAMCO HRp-I-sP 7830 PKR BAKER I~ HOQO CAMGO '0' NIPPLE I.NI'ERVAL. 79/G, PERFOFLATION DATA ZOf~ FT GPF PHASE COMIdENTS c I,g /Z -~,'~ I OO 5' C, GG GUN ,,t o° S'CSOGUN MISC. DATA DESCRIPTION DEPTH KIGK OFF POINT: 1500 MAX HOLE ANGLE: 4S.S dee SO00 HOLE ANGLETHRU KUP: 402 d~g. ~ TAG DATE: 06/0647 ~ REVlS~ DATE: 12/01 ~: NEW SCHEMATIC .,~" STATE OF ALASKA I~..., AL b,.^ ...,L AND GAS CONSERVATION CO :,~lON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well ~ Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other j~ 2. Name of Operator ARCO Alaska, Inc 3. Address PO Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1259' .FSL,. 3.17' FNL, Sec.35 T13N RgE At top cT proauct~ve interval ' ' ' 5. Datum elevation (DF or KB) RKB 69 6. Unit or Property name Kuparuk River Unit 7. Well number 3K-8 8. Permit number Permit #86-126 9. APl number 5O-- 029-21621 feet 1006' FSL, 1760' At effective depth 930' FSL, 1428' At total depth 915' FSL, 1358' 11. Present well condition summary Total depth: measured 8500' ND true vertical 6922' ND FWL, Sec.34, T13N, R9E, UM FWL, Sec. 34, T13N, R9E, UM FWL? Sec.34: T13N, RgE: UM 10. Pool Kunaruk River Oil Pnnl ! feet feet Plugs (measured) None Effective depth: feet feet Junk (measured) None measured R386' true verticalS833 ND ' MD Casing Length Size Cemented Measured depth True Vertical depth Structural 80' 16" 1540# Poleset Il0' MD Il0' TVD Conductor Surface 4207' 9-5/8" 1200 SX ASIII & 4244' MD 3757' TVD XXX~knxtRl~l~;l~Rte 300 SX Class G Production 8443' 7" 335 SX Class G 8475' MD 6903' TVD xxx~J4~e~xxxx & 175 SX ASI Perforation depth: measured 7916'-7934', 8102', 8106', 8110', 8114', 8140' 8144' MD 8152', 8156', 8160', 8165', 8169', 8175', 8179' -8184' MD true vertical6473,_6487, 6616' 6619' 6622' 6625' 6644' 6647' TVD 6654', 6657', 6660', 6663', 6666', 6671', 6674'-6678' TVD Tubing (size, grade and measured depth) 2-7/8", J-55, tbg w/tail @ 8035' Packers and SSSV (type and measured depth) HR-I-SP pkr Fa 7RRfl'. I~R pku, Fa Rfln7' ~ Tpnp_l~,.c;c;a qc;qv Fa 17cid, 12.Attachments DescriPtion summary of proposal ~ Detailed operations program [] Convert well from oil producer to water injector 13. Estimated date for commencing operation October 1, 1987 BOP sketch [] Date approved Alaska 0ii & ?s, 14. If proposal was verbally approved Name of approver 15. I hereby certify that the foregoing is true anAcorrect to the best of my knowledge Signed .~_'~ ~.,~~q}-~ Title Sr. Operations Engineer Dateg/16/87 Conditions of approval Commission Use Only Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearanceI Approved by ~,: :~ . ............... ~,, Commissioner by order of ¢ .c~ 2 ..~../~.~ the commission Date '-' Form 10-403 Rev 124-85 Submit in triplicate(~ ARCO Alaska, Inc Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: May 12, 1987 Transmittal f! 5976 RETURN TO: ARCO Alaska, Inc.' Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted her&with are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2Z-7 3K-9A 3K-8 3K-17 lA-10 3Q-16 lA-2 3Q-15 3M-6 3M-2 3M-5 3M-7 3M-4 3M-3 3M-1 2Z-5 2Z-5 CET Log 4-20-87 8275-8597 CBL 11-14-86 5408-7460 CET 11-15-86 7148-8376 CET 11-15-86 7940-9400 CET' 11-21-86 8650-8936 CBL 12-20-86 5349-7173 CET 12-21-86 7095-7781 CBL 12-20-86 5453-7360 CBL 4-30-87 5300-7312 CBL 4-28-87 6500-8295 ' CBL 4-28-87 6200-8795 CBL 4-30-87 6300-8359 CBL 4-28-87 7950-9845 CBL 4-28-87 5800-7933 CBL 4-28-87 4900-7187 Squeeze & Plug/Retainer Record 4-30-87 8090-8144 CET 4-30-87 7000-8324 Receipt Acknowledged: DISTRIBUTION: NSK Drilling Mobil SAPC ,El l) a :Oll & Gas Cons. Commission Anchorage S tare..of.i~ Alaska ~ (+sepia)':.~?~ BPAE Chevron · . . :'.~ . '..~,.. ...~. ~.: . ~ Union Vault (film) ARCO Alaska, Inc. is a Subsidiary o! AllanllcRichfieldCompan¥ ALASKAtuiLAND GAS CONSERVATION C ,~tMISSION ,..-.,. ' WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL F~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 86-126 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21621 4. Location of well at surface 9. Unit or Lease Name 1259' FSL, 317' FWL, Sec.35, T13N, R9E, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 1006' FSL, 1760' FWL, Sec.34, T13N, R9E, UM 3K-8 At Total Depth 11. Field and Pool 915' FSL, 1358' FWL, Sec.34, T13N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0il Pool RKB 69'I ADL 25520, ALK 2556 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 09/23/86 09/29/86 01/06/87* N/A feet MS L 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+'PdD) 19. DirectionalSurvey I 20. Depth where SSSV set 121. Thickness of Permafrost 8500'MD 6922'TVD 8386'MD 6833'TVD YES r~ NO [] 1786' feetMD 1700' (A.pprox) 22. Type Electric or Other Logs Run D I L/SFL/SP/Cal/GR/FDC/CNL, CET/GR/CCL, GCT 23. CASING, LINER AND CEMENTING RECORD , , SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD ' AMOUNT PULLED 16" 62.5# H-40 Surf 110' 24" 1540# Pol eset 9-5/8" 36.0# J-55 Surf 4244' 12-1/4" 1200 sx AS IV & 300 sx (:lass G 7" 26.0# J-55 Surf 8475' 8-1/2" 335 sx Class G & 175 sx AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) , , See attached. 2-7/8" 8031' 7826' & 8003' 26. ACID, FRACTURE, CEMENT SQUEEZE, DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL. USED See attached Addem~Jum, dated 02/17/87, for Fracture dar.. 27. N/A PRODUCTION TEST Date First Production I Method of Operation (FlOwing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIo TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED.1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 28. CORE DATA , Brief,description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. I~one ..... t V[:[) '~'. ~! .~', '1% m' ""'"'~ t:'~ b'~.?,.?,;. I --> .c.;t::'.i / ,,r,~.~.~ ~.~;¢. e ~t . *Note: Drilled RR 09/30/86. Well perforated & tubing run 12/02/86. WC2: 037: DAN I Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit. in duplica~. ' GEOLOGIC MARKERS FORMATION TESTS " , , NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 7856' 6427' N/A Base Kuparuk C 7924' 6479' Top Kuparuk A 8073' 6593' Base Kuparuk A 8242' 6722' , :31. LIST OF ATTACHMENTS ... Addendum,. (dated 02/17/87). 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed__ ~0 ~7'~/'~/ _.Z~ J./L~'~_ ~ TitleAssOCiate Engi neet Date-~3 ~~7 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 Well Completion or Recompletion Report and Log 3K-8 (cont.) Item #24 Perforation Depths' MD TVD 7916 8102 8106 8110 8114 8140 8144 8152 8156 8160 8165 8169 8175 8179 -7934'* 6473 6616 6619 6622 6625 6644 6647 6654 6657 6660 6663 6666 6671 -8184' 6674 -6487' -6678' Perforated w/1 spf, 0° phasing *Perforated w/12 spf, spiral phasing WC2/O37a 02/24/87 ADDENDUM WELL: 10/30/86 11/15/86 1/o6/87 3K-8 Arctic Pak w/175 sx AS I, following by 56 bbls Arctic Pak. Rn CET/GR/CCL f/8376' - 7148'. Rn GCT gyro f/surf - 8328'. Make GR/JB rn to 8381' WLM PBTD. RD Schl. Frac Kuparuk "A" sand perfs 8102' 8106' 8110' 8114' 8140' 8144' 8152' 8156' 8160' 8165' 8169' 8175' & 8179' - 8184' per procedure dated 12/12/86 as follows: Stage 1: 47 bbls diesel w/10% Musol @ 5.5 BPM, 4270 psi Stage 2: 90 bbls gelled diesel @ 20 BPM, 6600 - 5400 psi Stage 3: 20 bbls gelled diesel pad @ 20 BPM, 5560 psi Stage 4: 25 bbls gelled diesel w/1 ppg 100 mesh sand @ 20 BPM, 5630 psi Stage 5: 220 bbls gelled diesel @ 20 BPM, 5300 psi Stage 6: 35 bbls gelled diesel w/ 2 ppg 20/40 mesh.@ 20 BPM, 5300 psi Stage 7: 38 bbls gelled diesel w/ 4 ppg 20/40 mesh @ 20 BPM, 5380 psi Stage 8: 41 bbls gelled diesel w/6 ppg 20/40 mesh @ 20 BPM, 5400 psi Stage 9: 34 bbls gelled diesel w/8 ppg 20/40 mesh @ 20 BPM, 6163 psi Stage 10:46 bbls gelled diesel flush @ 20 BPM, 5550 psi Fluid to Recover: Sand in Zone: Sand in Csg: Ave pressure: 568 bbls 1000# 100 mesh & 22,371# 20/40 mesh 741 lbs 5700 psi Drilling Supervisor Date ,/ SUB.SURFACE DIRECTIONAL SURVEY I~UIDANCE I'~ONTINUOUS [-~'] OOL Company Well Name Field/Location 3K-8 (1259'FSL~317'FWL~ SE,C.35?T13N~R9E~UM) KUPARUK? NORTH sL~,PE; ALAKSA., '~' Job Reference N.,O. 72105 P~P~ Date 11/15/86 Computed By: GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKAt INC. 3K-8 KUPARUK NORTH SLOPEsALASKA SURVEY DATE: [5 NOV 86 ENGINEER: PEPPEL METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORIZo DISTo PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 88 DEG 16 MIN WEST ARCO ALASKA, INC. 3K-8 KUPARUK NORTH SLOPE,ALASKA COMPUTATION DATE: 9-DEC-86 TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZINUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN PAGE i DATE OF SURVEY: 15 NOV 86 KELLY BUSHING ELEVATION: 69.00 F.T ENGINEER: PEPPEL INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE. SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 -69.00 0 0 N 0 0 E 100.00 100.00 31.00 0 2 N 8 46 E 200.00 200.00 131.00 0 il N 59 50 W 300.00 300.00 231.00 0 17 S 77 47 W 400.00 400.00 331.00 0 19 N 89 55 W 500.00 500.00 431.00 0 27 N 73 45 W 600.00 599.99 530.99 0 29 N 29 41 W 700.00 699.98 630.98 0 48 N 4 20 N 800.00 799.97 730.97 0 40 N 14 8 W 900.00 899.97 830.97 0 31 N 0 49 W 1000.00 999.96 930.96 1100.00 1099.96 1030.96 1200.00 1199.96 1130.96 1300.00 1299.95 1230.95 1400.00 1399.95 1330.95 1500.00 1499.95 1430.95 1600.00 1599.86 1530.86 1700.00 1699.36 1630.36 0 33 N 10 11 E 0 30 N 15 39 E 0 32 N 16 46 E 022 N. 3 6 E 0 26 N 12 50 E 0 18 N 37 42 W 4 11 N 73 24 ~t T 34 N 66 59 W N 71 43 W N 82 2 W 1800.00 1797.97 1728.97 11 19 1900.00 1895.57 1826.57 13 16 N 87 45 W S 85 56 W S 84 26 W S 85 31W S 86 25 W S 86 56 W S 87 32 W S 88 18 W S 88 49 ~I S 89 8 W 2000.00 1992.39 1923.39 16 5 2100.00 2087.69 2018.69 19 16 2200.00 2180.88 2111.88 23 13 2300.00 2271.41 2202.41 26 55 2400.00 2359.17 2290.17 30 19 2500.00 2443.97 2374.97 33 30 2600.00 2525.83 2456.83 36 51 2700.00 2603.64 2534.64 41 0 2800.00 2677.30 2608.30 43 13 2900.00 2750.11 2681.11 43 4 3000.00 2823.41 2754.41 42 46 S 89 23 W 3100.00 2897.03 2828.03 42 21 . S 89 56 W 3200.00 2971.17 2902.17 41 57 N 89 49 W 3300.00 3045.79 2976.79 41 30 N 89 27 W 3400.00 3120.74 3051.74 41 29 N 89 7'W 3500.00 3195.89 3126.89 40 53 N 88 4 N 3600.00 3271.91 3202.91 40 23 3700.00 3347.23 3278.23 41 58 3800.00 3421.28 3352.28 42 3 3900.00 3495.87 3426.87 41 27 0.00 0.00 0.00 N 0.00 E 0.05 0.45 0.03 N 0.05 W 0.14 0.16 0.18 N 0.15 W 0.52 0.18 0.13 N 0.52 W 1.00 0.18 0.08 N 1.01 W 1.67 0.35 0.17 N 1,68 W 2.32 0.58 0.64 N 2.34 W 2.43 0.29 1.86 N 2.49 W 2.56 0.58 3.20 N 2.66 W 2.74 0.23 4.21 N 2.86 W 2.64 0.19 5.10 N 2.80 W 2.40 0.12 6.00 N 2.58 W 2.10 0.30 6.82 N 2.31 H 2.03 0.51 7.69 N 2.27 W 1.71 0.64 8.33 N 1.96 W 1.75 1.57 8.81 N 2.01 W 5.08 3.26 9.77 N 5.38 W 14.21 4.38 13.26 N 14.61 W 29.34 4.19 19.23 N 29.94 W 50.29 3.15 24.30 N 51.05 W 75.11 3.23 105.33 3.96 141.45 4.05 183.80 3.47 231.67 3.50 284.62 2.90 342.01 3.97 404.79 4.33 472.40 0.71 540.94 1.04 608.96 576.61 743.69 810.22 876.35 942.23 N 87 14 W 1007.01 N 89 48 W 1072.66 S 89 21 W 1139.86 N 89 59 W 1206.43 0.46 0.58 0.41 0.75 0.59 1.13 0.67 2.42 0.70 0.66 0.00 N 0 0 E 0.06 N 57 12 W 0.23 N 40 18 W 0.54 N 76 13 W 1.01 N 85 36 1.69 N 84 3 2.42 N 74 43 W 3.10 N 53 14 W 4.16 N 39 43 id 5.09 N 34 12 W 5.82 N 28 44 W 6.53 N 23 15 W 7.20 N 18 41 ~ 8.01 N 16 25 W 8.56 N 13 14 W 9.04 N 12 52 W 11,15 N 28 49 W 19.73 N 47 46 W 35.58 N 57 17 W 56.54 N 64 32 W 26.15 N 75.94 W 80.31 N 71 0 W 25.48 N 106.15 W 109.16 N 76 30 W 22.09 N 142.18 W 143.89 N 81 10 W 18.40 N 184.44 W 185.35 N 84 18 W 15.11 N 232.23 W 232.72 N 86 16 12.05 N 285.12 W 285.37 N 87 34 9.25 N 342.44 W 342.57 N 88 27 k 7.00 N 405.18 W 405.24 N 89 0 W 5.36 N 472.78 W 472.81 N 89 20 W 4.20 N 541.32 W 541.34 N 89 33 W 3.26 N 609.33 W 609.34 N 89 41 W 2.87 N 677.01 W 677.01 N 89 45 id 2.99 N 744.12 W 744.12 N 89 46 W 3.38 N 810.69 W 810.70 N 89 45 W 4.16 N 876.88 W 876.89 N 89 43 W 5.69 N 942.84 id 942.85 N 89 39 W 8.54 N 1007.73 W 1007.77 N 89 30 W 10.46 N 1073.46 W 1073.52 N 89 26 W 9.68 N 1140.68 W 1140.72 N 89 30 W 9.30 N 1207.27 W 1207.30 N 89 33 W ARCO ALASKAt INC. 3K-8 KUPARUK NORTH SLOPEsALASKA CONPUTATION DATE= 9-DEC-86 TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN PAGE 2 DATE DF SURVEY: 15 NOV' 86 KELLY BUSHING ELEVATION: ENGINEER: PEPPEL INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET BEG/lO0 FEET FEET FEET DEG MIN 4000,00 3571,05 3502,05 40 57 N 89 10 W 1272,32 4100,00 3646,86 3577,86 40 28 N 88 38 W 1337,45 4200.00 3723.19 3654.19 40 0 N 88 3 W 1401.94 4300.00 3800,04 3731,04 39 48 :N 87 55 W 1465,80 4400.00 3876.87 3807.87 39 36 N 88 12 W 1529.66 4500.00 3954.19 3885.19 39 10 4600.00 4031.29 3962.29 41 4 4700.00 4104.12 4035.12 44 47 4800.00 4174.74 4105.74 45 7 4900.00 4245,25 4176,25 45 5000.00 4315.66 4246.66 45 19 5100.00 4385.97 4316.97 45 5200.00 4456.58 4387.58 45 6 5300.00 4527.06 4458.06 45 9 5400.00 4597.74 4528.74 44 55 5500.00 4669.06 4600.06 43 37 5600.00 4742.07 4673.07 42 58 5700,00 4815.22 4746.22 43 3 5800°00 4888.27 4819.27 43 9 5900.00 4960.96 4891.96 43 26 6000.00 5033.73 4964.73 43 8 6100.00 5106.81 5037.81 42 58 6200.00 5180.16 5111.16 42 43 6300.00 5253.61 5184.61 42 45 6400.00 5327.12 5258,12 42 30 6500.00 5401.09 5332.09 42 6 6600.00 5475.44 5406.44 41 42 6700.00 5550,43 5481,43 41 16 6800.00 5625.82 5556.82 40 47 6900,00 5701.67 5632.67 40 37 N 88 25 W 1592,98 N 89 22 N 1656,55 S 89 22 N 1725.00 S 89 24 W 1795,80 S 89 25 N 1866.69 $ 89 24 ~ 1937.68 S 88 54 W 2008.79 S 88 13 W 2079.59 S 87 54 W 2150.54 S 87 42 W 2221,27 S 85 33 W 2291,33 S 84 4 W 2359,51 S 83 53 W 2427.51 S 84 6 W' 2495.61 S 84 22 W 2564.1L S 83 42 w 2632,52 s 82 55 w 2700.53 s 82 23 w 2768.17 S 81 47 W 2835.64 S 81 9 W ' 2902.95 S 80 36 W 2969°69 S 80 7 W 3035.92 S 79 38 W 3101.37 S 79 10 W 316-6.28 S 78 34 W 3230,57 S.78 17 W 3294,76 S 78 8 W 3359,03 S 78 7 W 3423,47 S 77 54 W 3487,69 S 77 45 W 3551.90 S 77 24 W 3615.84 S 77 18 W 3679.75 S 77 39 ~ 3743.55 S 77 37 W 3807,28 S 77 25 W 3870,86 0.93 0.63 0.71 0.43 0.48 0.31 4.74 1.17 0.14 0.22 0.47 0.60 0.34 0.49 0.35 2.81 0.28 0.17 0.45 0.58 0.77 0.68 0.47 0.68 0.60 0.61 0.96 0.45 0.53 0.24 0.29 0.34 0.48 0.14 0.36 0.23 0.03 0.24 0.15 0.49 69.00 FT .. 18.40 N 1939.12 W 1939.21 N 89 27 W 17,33 N 2010,23 W 2010.31 N 89 30 W 15.52 N 2081.01 W 2081.07 N 89 34 W 13.11 N 2151.92 W 2151.96 N 89 39 ~. 10.40 N 2222.61 W 2222,63 N 89 43 W 6.66 N 2292.58 W 2292.59 N 89 50 W 0.14 N 2360.60 W.2360.60 N 89.5~ W 7 07 S 24~8.41 W 2428.42 S 89 49 ~ 14~23 S 24~6.32 W 2496.36 S 89 40 W 21.06 S 2564.64 W 2564.73 S 89 31 W 28.06 S 2632.88 W 2633.03 S 89 23 W 36.03 S 2700.68 44.72 S 2768°09 W 2768.45 S 89 4 W 54,01 S 2835,31 W 2835,82 S 88 54 W 64.13 S 2902.34 W 2903.05 S 88 44 W 74.78 S 2968.79 86,01 S 3034.71 W 3035,93 S 88 22 97.63 S 3099.84 W 3101.38 S 88 11 W 109.72 S 3164.41 W 3166.31 S 88 0 W 122.30 S 3228,34 N 3230.66 S 87 49 W 135.41 .S 3292.17 W 3294.96 S 87 38 W 148.72 S 3356.07 W 3359.36 S 87 27 W 162.14 S 3420.13 W 3423.97 S 87 17 W 175,70 S 3483.97 W 3488.39 S 87 6 W 189.41 S 3547.79 W 3552.85 S 86 56 W 203.42 S 3611.34 W 3617.06 S 86 46 W 217.69 S 3674.85 W 3681.29 S 86 36 W 231.78 S 3738,25 W 3745.43 S 86 27 W 245.63 S 3801.59 W 3809.52 S 86 18 W 259,55 S 3864,77 W 3873,48 S 86 9 W 7000,00 5777,53 5708,53 40 43 7100.00 5853,30 5784,30 40 50 7200.00 5928.90 5859.90 40 46 7300.00 6004.67 5935.67 40 47 7400.00 6080.42 6011.42 40 40 7500.00 6156.35 6087.35 40 36 7600.00 6232.26 6163.26 40 34 7700.00 6308.30 6239.30 40 26 7800.00 6384.44 6315.44 40 19 7900.00 6460.68 6391,68 40 19 9.73 N 1273.20 W 1273.24 N 89 33 W 11.04 N 1338.40 W 1338.44 N 89 31 W 12.90 N 1402.97 W 1403.03 N 89 28 W 15.26 N 1466.93 W 1467.01 N 89 24 W 17.43 N 1530.89 W 1530.99 N 89 20 ~ 19.30 N 1594.29 W 1594.41 N 89 18 20.70 N 1657.93 W 1658.06 N 89 17 ~ 20.57 N 1726.41 W 1726.53 N 89 19 W 19.76 N 1797.22 W 1797.32 N 89 22 W 19.06 N 1868.12 W 1868.21 N 89 24 W COMPUTATION DATE= 9-DEC-86 PAG6 3 ARCO ALASKA, INC. DATE OF SURVEY= 15 NOV 86 3K-8 KUPARUK NORTH SLOPE,ALASKA KELLY BUSHING ELEVATIDN: ENGINEER: PEPPEL 69. O0 I:::.T INTERPOLATED VALUES FOR EVEN 100 FEET DF MEASURED DEPTH TRUE SO'B-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATIDN AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 8000.00 6537.10 6468.10 40 3 8100.00 6613.65 6544.65 40 4 8200.00 6690.10 6621.10 40 6 8300.00 6766.85 6697.85 39 25 8400.00 6844.27 6775.27 39 15 8500.00 6921.70 6852.70 39 15 S 77 11 w 3934.18 S 76 52 W 3997.28 S 76 56 W 4060.48 S 77 29 W 4123.38 S 77 59 W 4185.62 S 77 59 W 4247.90 0.23 0.04 0.31 1.50 0.00 0.00 273.73 S 3927.70 W 3937.22 S 86 0 W 2.88.20 S 3990.39 W 4000.78 S 85 52 W 302.82 S 4053.17 W 4064.47 S 85 43 W 317.13 S 4115.67 W 4127.87 S 85 35 W 330.42 S 4177.54 W 4190.59 S 85 28 ~. 343.59 S 4239.44 W 4253.34 S 85 21 COMPUTATION DATE: g-DEC-86 PAGE 4 ARCO ALASKA, INC. DATE OF SURVEY: 15 NOV 86 3K-8 KUPARUK NORTH SLOPE~ALASKA KELLY BUSHING ELEVATION: ENGINEER: PEPPEL 69.oo Fy INTERPOLATED VALUE'S FOR EVEN 1000 FEET DF MEASURED DEPT TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DE-G MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOOTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 -69.00 0 0 N 0 0 E 0.00 1000.00 999.96 930.96 0 33 N 10 11 E 2.64 2000.00 1992.39 1923.39 16 5 N 87 45 W 75.11 3000.00 2823.41 2754.41 42 46 S 89 23 W 608.96 4000.00 3571.05 3502.05 40 57 N 89 10 W 1272.32 5000.00 4315.66 4246.66 45 19 S 89 24 W 1937.68 6000.00 5033.73 4964.73 43 8 S 83 42 W 2632.52 7000.00 5777.53 5708.53 40 43 S 78 17 W 3294.76 8000.00 6537.10 6468.10 40 3 S 77 11 W 3934.18 8500.00 6921.70 6852.70 39 15 S 77 59 W 4247.90 0.00 0.19 3.23 0.46 0.93 0.47 0.77 0.29 0.23 0.00 0.00 N 0.00 E 0.00 N 0 0 E 5.10 N 2.80 W 5.82 N 28 44 26.15 N 75.94 W 80.31 N 71 0 W 3.26 N 609.33 W 609.34 N 89 41 W 9.73 N 1273.20 W 1273.24 N 89 33 18.40 N 1939.12 W 1939.21 N 89 27 28.06 S 2632.88 W 2633.03 S 89 23 W 135.41 S 3292.17 W 3294.96 S 87 38 W 273.73 S 3927.70 W 3937.22 S 86 0 W 343.59 S 4239.44 W 4253.34 S 85 21 ARCO ALASKAt INC. 3K-8 KUPARUK NORTH SLOPE,ALASKA COMPUTATION DATE: 9-DEC-86 TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN PAGE 5 DATE OF SURVEY: 15 NOV 86 KELLY BUSHING ELEVATION: 69.00 FI ENGINEER: PEPPEL INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH 0.00 0.00 69.00 69.00 169.00 169.00 269.00 269.00 369.00 369.00 469.00 469.00 569.01 569.00 669.01 669.00 769.02 769.00 869.03 869.00 -69.00 0 0 N 0 0 E 0.00 0 4 N 62 29 W 100.00 0 10 N 44 32 W 200.00 0 14 S 67 36 W 300,00 0 16 S 86 51 W 400.00 0 24 N 79 44 W 500.00 0 27. N 46 51 W 600.00 0 47 N 2 7 W 700.00 0 44 N 10 43 W BO0.O0 0 33 N 10 19 W 0 30 'N 7 51 E FEET DEG/IO0 FEET FEET FEET DEG MIN 969.03 969.00 900.00 1069.04 1069.00 1000.00 0 31 1169.04 1169.00 1100.00 0 28 1269.05 1269.00 1200.00 0 27 1369o05 1369.00 1300.00 0 27 1469.05 1469.00 1400.00 0 11 1569.07 1569o00 1500.00 2 49 1669.42 1669.00 1600.00 6 16 1770.51 1769.00 1700.00 10 12 1872.72 1869.00 1BO0.O0 12 55 0.00 0.00 0.00 N 0.00 E 0.03 0.33 0.02 N 0.03 W 0.06. 0.22 0.11 N 0.07 W 0.38 0.27 0.17 N 0.38 W 0.85 o.15 o.o8 N 0.85 w 1.45 0.11 0.13 N 1.45 W 2.17 0.51 0.44 N 2.18 W 2.42 0.13 1.42 N 2.46 W 2.48 0.39 2.82 N 2.57 W 2.72 0.49 3.92 N 2.84 W 1975.71 1969.00 1900.00 15 17 2080.23 2069.00 2000.00 lB 32 2187.05 2169.00 2100.00 22 42 2297.28 2269.00 2200.00 26 50 2411.38 2369.00 2300.00 30 42 2530.17 2469.00 2400.00 34 24 2654.79 2569.00 2500.00 39 4 2788.58 2669.00 2600.00 43 10 2925.77 2769.00 2700.00 42 54 3062.02 2869.00 2800.00 42 32 N 14 38 E N 20 16 E N 4 12 W N 31 7 E N 12 50 1~ N 75 25 W N 68 5 W N 69 35 W N 78 45 W 3197.08 2969.00 2900.00 41 57 3330.93 3069.00 3000.00 41 25 3464.36 3169.00 3100.00. 41 10 3596.18 3269.00 3200.00 40 23 3729.41 3369.00 3300.00 42 14 3864.14 3469.00 3400.00 41 39 3997.28 3569.00 3500.00 40 58 4129.08 3669.00 3600.00 40 19 4259.65 3769°00 3700.00 39 44 4389,78 3869.00 3800.00 39 39 2.69 0.14 4.82 N 2.84 W 2.48 0.08 5.73 N 2.65 W 2.20 0.18 6.56 N 2.40 W 2.03 0.34 7.46 N 2.25 W l. B2 0.42 B.lO N 2.06 W 1.71 0.25 8.72 N 1.98 W 3.23 4.72 9.26 N 3.52 W 10.84 4.17 11.83 N ll. ZO W 24.22 3.98 17.42 N 24.75. W 44.26 3.13 23.30 N 44.98 W N 86 55 W 68.62 3.55 S 86 50 W 98.91 4.10 S 84 18 W 136.33 4.04 S 85 29 W 182.54 3.48 S 86 28 W 237.41 3.48 S 87 4 W 301.46 2.91 S 87 58 W 375.74 4.24 S 88 47 W 464.56 0.94 S 89 9 W 558.47 0.40 S 89 45 W: 651.00 0.60 N 89 49 W 741.73 N 89 21 W 830.63 N 88 30 W 918.89 N 87 15 W 1004.55 S 89 28 W 1092.43 S 89 45 W 1182.69 N 89 11 W 1270.54 N 88 29 W 1356.28 N 87 51 W 1440.07 N 88 10 W 1523.15 0.41 0.32 1.12 0.71 1.09 0.89 0.95 0.61 0.08 0.44 0.00 N 0 0 E 0.03 N 60 44 W 0.13 N 30 33 W 0.42 N 65 39 W 0.85 N 84 37 W~, 1.46 N 85 3 ~ 2.23 N 78 33 W 2.84 N 59 58 N 3.82 N 42 19 W 4.84 N 35 58 W 5.59 N 30 32 W 6.32 N 24 50 W 6.98 N 20 5 W 7.79 N 16 47 W 8.36 N 14 16 W 8.94 N 12 47 W 9.90 N 20 48 W 16.29 N 43 26 W 30.27 N 54 52 W 50.66 N 62 37 ~ 25.80 N 69.43 W 74.07 N 69 37 W 25.92 N 99.74 W 103.05 N 75 25 W 22.59 N 137.07 W 138.92 N 80 38 W 18.50 N 183.19 W 184.12 N 84 14 W 14.75 N 237.97 W 238.42 N 86 27 W~.~ 11.18 N 301.94 W 302.14 N 87 52 W 7.94 N 376.16 W 376.24 N 88 47 W 5.52 N 464.94 W 464.98 N 89 19 W 3.92 N 558.84 W 558.86 N 89 35 W 2.93 N 651.38 W 651.39 N 89 44 W 2.98 N 742.16 W 742.16 N 89 46 W 3.60 N 831.12 W 831.13 N 89 45 W 4.98 N 919.46 W 919.47 N 89 41 W 8.42 N 1005.27 W 1005.30 N 89 31 W 10.36 N 1093.24 W 1093.29 N 89 27 W 9.35 N 1183.51 W 1183.55 N 89 32 W 9.70 N 1271.42 W 1271.46 N 89 33 W 11.50 N 1357.25 W 1357.30 N 89 30 W 14.29 N 1441.16 W 1441.23 N 89 25 ~ 17.23 N 1524.37 W 1524.47 N 89 21 W COMPUTATION DATE= g-DEC-86 PAGE 6 ARCO ALASKAt INC. DATE OF SURVEY: 15 NOV 86 3K-8 KELLY BUSHING ELEVATION: KUPARUK NORTH SLOPE,ALASKA ENGINEER= PEPPEL INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HDRIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SDDTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 4519.10 3969.00 3900.00 39 8 4650.89 4069.00 4000.00 43 23 4791.87 4169.00 4100.00 45 6 4933.70 4269.00 4200.00 45 13 5075.90 4369.00 4300.00 45 16 5217.60 4469.00 4400.00 45 8 5359.38 4569.00 4500.00 45 0 5499.91 4669.00 4600.00 43 37 5636.79 4769.00 4700.00 42 58 5773.60 4869.00 4800.00 43 4 5911.09 4969.00 4900.00 43 26 6048.26 5069.00 5000.00 43 3 6184.80 5169.00 5100.00 42 44 6320.96 5269.00 5200.00 42 44 6456.69 5369.00 5300.00 42 15 6591.37 5469.00 5400.00 41 45 6724.71 5569°00 5500.00 41 11 6856~95 5669.00 5600.00 40 38 6988.74 5769.00 5700.00 40 42 7120o78 5869.00 5800.00 40 53 N 88 29 W 1605.02 S 89 51 W 1690.69 S 89 23 W 1790.04 S 89 26 W 1890.59 S 89 I W 1991.67 S 88 8 W 2092.07 S 87 47 W 2192.57 S 85 33 W 2291.27 S 83 57 W 2384.51 S 84 i ~ 2477.62 S 84 22 W 2571.73 S 83 19 W 2665.35 S 82 29 W 2757.91 S 81 37 W 2849°77 S 80 51 W 2940.85 S 80 9 W 3030.23 S 79 30 W 3117.48 S 78 49 W 3202.93 S 78 17 W 3287.53 S 78 9 W 3372.43 S 78 0 W 3457.44 S 77 48 W 3542.25 S 77 21 W 3626.49 S 77 27 W 3710.64 S 77 37 W 3794.40 S 77 23 W 3877.80 S 77 1 W 3960.47 S 76 54 W 4043.03 S 77 32 W 4125.10 S 77 59 ~ 4205.51 0.10 4.36 0.10 0.21 0.47 0.23 0.18 2.81 0.28 0.35 0.59 0.49 0.42 0.55 0.46 0.94. 0.50 0.51 0.33 0.20 0.22 0.35 0.15 0.48 0.28 0.59 0.32 0.23 1.51 0.00 69.00 FT 19.62 N 1506.34 W 1606.46 N 89 18 W 20.85 N 1692.09 W 1692.22 N 89 17 W 19.82 N 1791.46 W 1791.57 N 89 21 W 18.81 N 1892.02 W 1892.12 N 89 25 W 17.64 N 1993.11W 1993.19 N 89 29 15.13 N 2093.49 N 2093.54 N 89 35 11.52 N 2193.92 W 2193.95 N 89 41 6.67 N 2292.52 W 2292.53 N 89 50 W 2.48 S 2385.53 W 2385.53 S 89 56 12.37 S 2478.38 W 2478.41 S 89 42 21.80 S 2572.25 W 2572.34 S 89 30 W 31.80 S 2665.61 W 2665.80 S 89 18 W 43.36 S 2757.86 W 2758.20 S 89 5 W 56.08 S 2849.38 N 2849.93 S 88 52 W 70.11 S 2940.08 W 2940.91 S 88 38 W 85.02 S 3029.05 W 3030.24 S 88 23 W 100.56 S 3115.86 W 3117.49 S 88 9 W 116.79 S 3200.86 W 3202.99 S 87 54 W 133.91 S 3284.98 W 3287.71 S 87 39 W 151.51 S 3369.39 W 3372.79 S 87 25 W 7252.92 5969.00 5900.00 40 44 7384.94 6069.00 6000.00 40 41 7516.67 6169.00 6100.00 40 38 7648.37 6269.00 6200.00 40 30 7779.76 6369.00 6300.00 40 22 7910.92 6469.00 6400.00 40 17 8041.66 6569.00 6500.00 40 2 8172o40 6669.00 6600,00 40 9 8302.78 6769.00 6700.00 39 23 8431.94 6869.00 6800.00 39 t5 169.27 S 3453.90 W 3458.04 S 87 11 W 187.33 S 3538.20 N 3543.16 S 86 58 W 205.78 S 3621.93 ~ 3627.77 S 86 44 N 224.59 S 3705.55 W 3712.34 S 86 31 W 242.82 S 3788.79 W 3796.57 S 86 19 W 261.10 S 3871.67 W 3880.47 S 86 8 '~--~ 279.70 S 3953.82 W 3963.70 S 85 57 ,. 298.80 S 4035.84 W 4046.88 S 85 45 W 317.51 S 4117.38 W 4129.61 S 85 35 W 334.63 S 4197.31 W 4210.63 S 85 26 W 8500.00 6921.70 6852.70 39 15 S 77 59 W 4247.90 0.00 343.59 S 4239.44 W 4253.34 S 85 21 W ARCO ALASKAs INC. 3K-8 KUPARUK NORTH SLOPE~ALASKA MARKER TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A PBTD TD COMPUTATION DATE: 9-DEC-86 PAGE DATE OF SURVEY: 15 NOV 86 KELLY BUSHING ELEVATION: ENGINEER: PEPPEL 69. O0 F.T INTERPOLATED VALUES FOR CHOSEN HORIZONS MEASURED DEPTH BELOW KB 7856.00 7924.00 8073.00 8242.00 8386.00 8500.00 SURFACE LOCATION AT ORIGIN= 1259' FSL~ 317' FWLt SEC 35t T13N, RgE, UM TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 6427.14 6358.14 253.40 S 3836.97 W .6478.97 6409.97 262.96 S 3879.94 W 6592.99 6523.99 284.25 $ 3973.46 W ~-~. 6722.25 6653.25 308.92 S 4079.50 W 6833.43 6764.43 328.58 S 6168.88 W 6921.70 6852.70 343.59 S 4239.44 W ARCO ALASKAs INC. 3K-8 KUPARUK NORTH SLOPEtALASKA MARKER TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARU'K A PBTD TD COMPUTATION DATE: 9-DEC-86 PAGE DATE OF SURVEY: 15 NOV 86 KELLY BUSHING ELEVATION: ENGINEER: PEPPEL 69.o0 F,T ***~***~*** STRATIGRAPHIC MEASURED DEPTH BELOW KB 7856.00 7924°00 8073.00 8242.00 8386.00 8500.00 SUMMARY SURFACE LOCATION AT ORIGIN= 1259' FSL~ 317' FWLt SEC 35~ T13N~ RgE~ UM TVD RECTANGULAR COORDINATES FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 6427.14 6358.14 253.40 S 3836.97 W 6478.97 6409.97 262.96 S 3879.94 W 6592.99 6523.99 284.25 S 3973.46 W ~---_ 6722.25 6653.25 308.92 S 4079.50 W 6833.43 6764.43 328.58 S 4168.88 W 6921.70 685Z.70 343.59 S 4239.44 W FINAL WELL LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 8500.00 6921.70 6852.70 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 4Z53.34 S 85 21 W SCHLUMBERGER O I RECT I ONAL SURVEY COMPANY ARCO ALASKA INC. WELL 3K-8 F I ELD KUPARUK COUNTRY NORTH SLOPE RUN 1 BATE LOOOED 1S - NOV - 86 REFERENCE ?210S NORTH 4000 R'P.F '721 OS SCALE. = 1/1000 IN/FT 3000 2000 IO00 -IOOO -~000 -BO00 SOUTH-4000 -5000 NEST -5000 -4000 -~000 -2000 -1000 0 1000 2000 ~RST -zuuu -1000 0 0 1000 2000 9000 4000 SO00. 6000 88, 268, PROJECTION ON VERTICAL PLANE 268, - 88. SCALED IN VERTICAL DEPTHS HORIZ SCALE = 1/1000 IN/FT Form to be inserted J.n each "Active" well folder to check for timely .compliance with our regulations. RATOR, WELL NAME AND NUMBER Reports and Materials to be received by: Date , , Required Date Received 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 Log Run Digitized Data ARCO Alaska. Inc. Post Office BOX 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk · ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE January 2, 1987 TRANSMITTAL # 5869 Transmitted herewith are the following items. Pl.ease acknowledge receipt and return one signed copy of this transmittal. 3K-11 · '~ 3K-12 · . ~ 3K-8 3K-10 CBL 11-16-86 5547-7730 CBL 11-17-86 5115-7674 Pulse Echo Log 11-16-86 7002-8381 CBL 11-16-86 5502-7173 Receipt Acknowledged: DISTRIBUTION: ' NSK Chevron (+ sep) & G35~%~: Commission Drilling ~'?~'State'"'of 'Aias'~"-($"'~*~p)'!!i.~ BP~ .. ~.~-'~-' ..... :.. - ....... _ ,.~.~¥.., ~_~ .... ~ ..... ; ..... . Mobil (+ sep) s~c (+ sep) Unocal (+ se9) Vault (film) L. Johnston ARCO Allltkl. Inc. i- · Sul~.,diary of AtlanticRtchf,eldComl~an¥ ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE December 31', 1986 TRANSMITTAL # 5866 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. OH Final Prints: (1 blueline copy unless otherwise specified) 3K-8 ~ ,, FDC Raw 9-29-86 4245-8467 ~.~2 FDC Porosity 9-29-86 4245-8467 2" FDC Raw 9-29-86 4245-8467 Cyberlook 7750-8400' 9-29-86 ~2" DIL 9-29-86 4245-8493 x'~5" FDC Porosity 9-29-86 4245-8467 ~" DIL 9-29-86 4245-8493 3K-6 'x~5" FDC Porosity 9-15-86 6650-8066 ~.~-2" FDC Raw 9-15-86 6650-8066 ._x~x~',.FDC Porosity 9-15-86 6650-8066 DIL 9-16-86 4012-8092 ~5" FDC Raw 9-15-86 6650-8066 ~5" DIL 9-16-86 4012-8092 x. dCyberlook 9-15-86 7350-8050 Receipt Acknowledged: ?//~---'~/Alask~ l~l~.e~~ DISTRIBUTION: NSK - Drilling /~/~D&M RaF/~mell A~c:~o~ State..of~.Alaska,...(+.'sept~.~.~,'~ Vault (fi~j~. Johnston (vendor package) ,. ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldComl3an¥ STATE OF ALASKA ALASK,~i' AND GAS CONSERVATION COMMI REPORT OF SUNDRY WELL OPEi ATIONS 1. Operations performed: Operation shutdown - Stimulate - Plugging '- Alter Casing ~...Other ~ ..... CCNPLETE 99510 2. Name of Operator ARCO Alaska~ Inc. 3. Address P.O. Box 100360 Anchorage, AK 4. Location of well at surface 1259' FSL, 317' FWI_, Sec.35, T13N, RgE, LlVl At top of productive interval 1006' FSL, 1760'FWL,Sec.34, T13N, R9E,LlVl At effective depth 930' FSL, 1428' FWL,Sec.34, T13N, R9E,LN At total depth 915' FSL, 1358' FWL,Sec.34, T13N, RgE,· Perforate ~ Pull tuOing _-_ 5. Datum elevation (DF or KB) RKB 69' 6. Unit or Property name Kuparuk River Unit 7. Well number 8. Approval number 479 9. APl number 50-- 029-21621 10. Pool Kuparuk River Oil Pool Feet 11. Present well condition summary Total depth: measured , true vertical Effective depth: measured true vertical Casing Conductor Surface 8500'~ 6922'TVD 8386'~ 6833'TVD Production Length Size 80' 16" 4207' 9-5/8" 8443' 7" feet feet feet feet Plugs (measured) None Junk (measured) None Cemented Measured depth 1,54~ Poleset 110'1¢) 1200 sx AS TV & 4244 300 sx Class G 335 sx Class G & 8475'~ 175 sx AS I True Vertical depth llO'TVD 3757 'TVD 6903'TVD · Perforation depth: measured See Attached true vertical See Attached Tubing (size, grade and measured depth) 2-7/8", J-55, tbg w/tail @ 8031' Packers and SSSV (type and measured depth) HRP-1-SP pkr @ 7826', DB pkr @ 8003, & TRDP-1A-SSA SSSV @ 1786' 12. Stimulation or cement squeeze summary In' N/A mrvals treated (measured) Treatment descril~tion including volumes used and final pressiJre 13. Representative Daily Average Production or Injection Data N/A OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 14. Attachments (Completion Well History w/.Addendun, dat.~! 11/19/86) Daily Report of Well Operations ~.~ Copies of Logs and Surveys 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed &~X./ Z~I,~,2~ Title AS~;OCi~ Enqilleer Date Form 10-404 Rev. 12-1-85 (~ (D/~) ~0/141 Submit in Duplicate ARCO Oil and Gas Company Daily W~,, ,distory-Final Report Instructions: c-etA "Final Report' ~"~'; ~ 'ec~ '~: .~ :3~;'?: Alaska ~ North Slope Borough [ Alaska Field uea~e o, _~ ', We,' ~o Kuparuk River ~L 25520 3K-8 Aulh. or W.C, no, Ti:le A~g ~140~ Completion Nordic 1 Operator ARCO Alaska, Inc. Spudded or W.O. begun Complete API 50-029-21621 AR.Co. WI ITotal number of wells (active or inactive) on th,s Icost center priOr to plugging an0 56.24% labandonrnent of this well Date IHour I Prior status if a W.O, 12/1/86 ~ 0330 hrs. I Date and depth as of 8:00 a.m. Old TD Complete record for each day reported Released rig 12/01/86 12/02/86 12/03/86 Classifications (o11, gas,,etc.) Oil 7" @ 8475' 8386' PBTD, Tst BOPE 9.8 ppg NaCl/NaBr Accept ri~ @ 0330 hfs, 12/1/86. NU & cst BOPE. 7" @ 8475' 8386' PBTD, Tst tree 9.8 ppg NaCl/NaBr RU & perf w/4" gun, 0° phasing, 1 spf @ 8102', 8106', 8110', 8114', 8140', 8144', 8152', 8156', 8160', 8165', 8169', 8175' & 8179'-8184'. Perf w/5" gun, 12 SPF f/7916'-7934'. Make GR/JB rn to 8010'. RIB, set DB pkr @ 8003', RD Gearhart. RU & rn 246 Jts, 2-7/8", 6.5#, J-55 EUE 8RD AB-Mod tbg w/SSSV @ 1786', HRP-1-SP pkr @ 7826' DB pkr @ 8003', TT @ 8031'. Tst tbg & ann to 2500 psi. Tst SSSV; OK. ND BOPE. NU & tst tree. 7" @ 8475' 8386' PBTD, RR Diesel Displ well to diesel. RR @ 0930 hfs, 12/2/86. New TO PB Depth Date I K nd of rig 0930 hrs. 12/2/86 I Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data 8386' PBTD Rotary Well no. Date Reservoir Producing Interval Oil or gas Test time .Production ]Oil on test Gas per day .... Pump size, SPM X length Choke size T.P. C.P. Water % CdR Gravity Allowable Effective date corrected The above is correct Date/. ~r -- ITttle Drilling Supervisor For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. REPORT OF SUNDRY WELL OPERATIONS 3K~ (Cont' d) It~n #11 Perforation Depths: 7916' - 7934' 8102' 8106' 8110' 8114' 8140' 8144' 8152' 8156' 8160' 8165' 8169' 8175' 8179' - 8184' TVD 6473' - 6487' 6616' 6619' 6622' 6625' 6644' 6647' 6654' 6657I 6660I 6663' 6671' 6674' - 6678' SWO/141(p.2) 12-15-86 ADDENDUM WELL: 3K-8 10/30/86 Arctic Pak w/175 sx AS I, following by 56 bbls Arctic Pak. 11/15/86 Rn CET/GR/CCL f/8376' - 7148'. Rn GCT gyro f/surf - 8328'. Make GR/JB rn to 8381' WLM PBTD. RD Schl. Drzlling Supervisor z Da4:e- ' STATE OF ALASKA I" ALASKa' .,- AND GAS CONSERVATION COMMI'~. ,,.~N APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~. Suspend _~ Operation Shutdown ~ Re-enter suspended well ~ Alter casing Time extension ~ Change approved program ,~. Plugging ~ Stimulate ~ Pull tubing ~ Amend order = Perforate -- Other 2. Name of Operator 5. Datum elevation (DF or KB) ARCO A]aska, Inc. 69'RKB feet 3. Address 6. Unit or Property name P. O. Box 100360 Anchorage, AK 99510-0360 Kuparuk River Unit of well at surface ' FSL, 317' FWL, Sec.35, T13N, RgE, UM productive interval 4. Location 1259 At top of 1139' FSL, 1619' FWL, Sec.34, T13N, R9E, UM (approx.) At effective depth 1018' FSL, 1389' FWL, Sec.34, T13N, RgE, UM (approx.) At total depth 1003' FSL, 1317' FWL, 5ec.34, T13N, R9E, UM (approx.) 7. Well number 3K-FI 8. Permit number 86-126 9. APl number 50-- 029-21 621 10. Pool Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Surface Length 80' 4207' 8443' Production 8500 'MD feet Plugs (measured) None feet 6893 ' TVD 8386 'MD feet Junk (measured) None 6805 ' TVD feet Size Cemented Measured depth 16" 1540# Poleset 110'MD 9-5/8" 1200 sx AS IV & 4244 'MD 300 sx Class G 7" 335 sx Class G 8475 'MD ~ue Verticaldepth 110'TVD 3759'TVD 6874'TVD Perforation depth: measured None'. true vertical None Tubing (size, grade and measured depth) None Packers and SSSV (type and measured depth) None OCI ,,. t !986 ~,!aska 0il & Gas Cons. At, chorale: 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch Well Hi story 13. Estimated date for commencing operation November, 1986 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~/ Commission Use Only ( DAM ) SA/129 Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearancel Date Approved by~~ Form 10-403 Rev 72-i-85' // // / '~gturn~d by order of Commissioner the commission Date, S,.b~it' irf~ipl icate ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Alaska Field Kuparuk River Auth. or W.O. no. AFE AKI40I Doyon 9 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded 9/24/86 9/25/86 9/26/86 9/27/86 thru 9/29/86 9/30/86 Date and depth as of 8:00 a.m. ICounty, parish or borough North Slope Borough Il, ease or Unit ADL 25520 JTitlO Drill State Alaska Well no. 3K-8 API 50-029-21621 Date 9/23/86 ARCO W.I. IHour lPr orstatusifa W,O. 2000 hrs I e 56.24% Complete record for each day reported 16" @ 110' 1500', (1390'), TIH Wt. 9.1, PV 21, YP 19, PH 9.0, WL 11.6, Sol 6 Accept ri~ @ 1800 hfs, 9/23/86. NU diverter sys. Spud well @ 2000 hfs, 9/23/86. Spud @ 110' & drl to 1500', POOH. PU DD, TIH. ,;7 16" @ 110' 3458', (1958'), RIH Wt. 9.3, PV 18, YP 16, PH 8.5, WL 12.4, Sol 7 Navi-Drl & surv 12¼" hole to 3458'. 1952', 14.5°, N86.9W, 1945.99 TVD, 64.54 VS, 17. 2467', 32.1°, S87.SW' 2417.73 TVD, 266.04 VS, 9.61N, 266.45W 3057', 42.6°, N88.0W, 2869.26 TVD, 644.24 VS, 6.18N, 644.72W ' 9-5/8" @ 4244' 4260', (802'), ND diverter Wt. 9.4, PV 22, YP 16, PH 8.5, WL 7.8, Sol 8 Drl & surv 12¼" hole to 4260', C&C, POOH. RU & rn 102 jts, 9-5/8", 36#, J-55 BTC csg w/FS @ 4244', FC @ 4160'. Cmt w/1200 sx AS IV & 300 sx C1 "G" w/S-1 & D-46. Displ using rig pmps, bump plug. ND diverter. 3529', 40.8°, N85.9W, 3221.66 TVD, 957.10 VS, 22.89N, 958.23W 4093', 40.4°, N86.8W, 3644.78 TVD, 1329.07 VS, 37.21N, 1330.80W 4205', 40.3°, N86.2W, 3730.14 TVD, 1401.28 VS, 41.64N, 1403.18W 9-5/8" @ 4244' 8500', (4240'), Pmp diesel pill Wt. 9.9+, PV 16, YP 10, PH 9.5, WL 4.4, Sol 11 ND diverter, NU & tst BOPE. RIH w/8½" BHA to 4160', tst csg to 2000 psi. DO cmt & flt equip + new hole to 4270'. Conduct formation tst to 12.5 ppg EMW. Drl & surv 8½" hole to 8500'. 4687', 45.3°, N89.6W, 4083.68TVD, 1727.89 VS, 53.63S, 1730.30W 5346', 45.6°, S89.0W, 4544.99TVD, 2198.21VS, 53.75S, 2200.90W 5817', 43.5°, S84.9W, 4880.62TVD, 2528.51VS, 36.18N, 2530.76W 6606', 42.0°, S82.1W, 5459.53TVD, 3062.74 VS, 23.46S, 3063.42W 7545', 40.7°, S78.1W, 6164.70TVD, 3676.35 VS, 130.00S, 3674.10W 9-5/8" @ 4244' 8500', (0'), Rn'g 7" Wt. 9.9+, PV 13, YP 9, PH 9.5, WL 4.2, Sol 10 Circ & spot pill, POH. RU Schl, rn DIL/SFL/SP/CAL/GR/FDC/CNL f/8501'-7150', RD Schl. Make cond'g rn, spot pill, POH. Chg rams to 7". RU & rn 7" csg. Theabove is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date Title ] Drilling Supervisor ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged. Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, reporl completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting District 1County or Parish I State Alaska North Slope Borough Field /Lease or Unit Kuparuk River [ ADL 25520 Auth. or W.O. no. /Title AFE AK1401 ~ Drill COSt center code Alaska Well no. 3K-8 Doyen 9 Operator [A.R.Co. W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun JDate Spudded J 9/23/86 Date and depth Complete record for each day reported as of 8:00 a.m. 10/01/86 API 50-029-21621 I otal number of wells (active or inactive) on this cst center prior to plugging and I bandonment of this well I our I Prior status if a W.O. I 2000 hrs. 7" @ 8475' 8500' TD, 8386' PBTD, RR 9.8+ NaCl Rn 201 jts, 7", 26#, J-55 HF/ERW R-3 BTC csg w/FC @ 8387', FS @ 8475'. Cmt w/100 sx lead & 235 sx tail cmt. Displ w/322 bbls 9.8+ ppg brine. CIP @ 1400 hrs, 9/30/86 after bump'g plug. ND BOPE, NU pack-off, tbg head & lower tree, tst to 3000 psi. RR @ 1830 hrs, 9/30/86. Alaska 0il & Gas Cons. ~,~, ...... Old TD New TD PB Depth 8500' T9 8386' ?BTD Released rig Date Kind of rig 1830 hrs. Classifications (o11, gas, etc.) O±l Producing method Flowing Potential test data 9/30/86 Type completion (single, dual, etc,) Single Official reservoir name(s) Kuparuk Sands Rotary Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct For form preparation and distribution, soo Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Supervisor 'ARCO Alaska, Inc. '~ Post Office B ~.~360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk AT0 1119 P. O. Box 100360 Anchorage AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ~ · . ~- ,~ . ,;"~ ~,, ~ ' - ' ,'." .2 c:~..~./~_ Receipt Acknowledged: .. Anchorage ARCO Alaska. Inc. is · Sub,idiary o! AtlanticRichfieldComoany June 24, 1986 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Telecopy: (907) 276-7542 Re: Kuparuk River Unit 3K-8 ARCO Alaska, Inc. Permit No. 86-126 Sur. Loc. 1259'FSL, 3!7'FWL, Sec. 35, T13N, RgE, UM. Btmhole Loc. ll3!'FSL, 1378'FWL, Sec. 34, T13N, R9E, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required b~ law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. C. V. Cha Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o enclo Mr. Doug L. Lowery STATE OF ALASKA ' ALASKA (._ AND GAS CONSERVATION Cr~,..lvllSSlON PERMIT TO DRILL 2O AAC 25.005 i la. Type of work Drill [] Redrill [~1 lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil ~' Re-Entry [] Deepen[]1 Service [] Developement Gas [] Single Zone ~ Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 69', PAD 35' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Poo P.O. Box 100360 Anchorage, AK 99510 ADL 25520 ALK 2556 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20AAC 25.025) 1259'FSL, 317'FWL, Sec.35, T13N, R9E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well nurpber Number 1139'FSL, 1619'FWL, Sec.34, T13N, R9E, UM 3K-8 #8088-26-27 At total depth 9. Approximate spud date Amount 1131'FSL, 1378'FWL, Sec.34, T13N, R9E, UM 08/05/86 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 8452 'MD 317' (~ surface feet 3K-7 25' ~ surfacefeet 2560 (6890'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035 (e)(2)) Kickoff depthlS00 feet Maximum hole angle 42 0 Maximum surface 2234 psig At total depth (TVD) 3439 psig 18. Casing program Setting Depth size Specifications Top Bottom Ouantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 80' 35' 35' 115' 115' +200 cf 12-1/4"9-5/8" 36.0# J-55 BTC 4210' 35' 35' 4245' 3774' 1187 sx AS Ill & HF-EFW 301 sx Class G blend U-'I/Z" :/" Zb.U~ J-.b.b I¢1C U4~IU' 3~.' 3~.' 8452' 6890' 200 sx Class G(.minimum HF-EF~/ T0C 50, : above t:op OT ~,uparuK 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor ?":? i,' ,'"' ',/:' !, ?, ',, .... Surface Intermediate Production Perforation depth: measured true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch j~ Diverter Sketch J~ Drilling program [] Drilling fluid program ~ Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements 21.1hereby~hat//theforegoi_og/,,,~ is true and correcttothebestofmy knowledge Signed ..- c ~..,.~x..Y,~,~J Title Regional Drill ing Engineer t,,./"'"'-¢/,"¢,' / Z' ........ ' - Commission Use Only (HRE} PD/PD283 " I Ir6 > I Permit Number APl number App See cover letter ~',~-,'"/'% 6 50-- 6'L,~- -L.,~ G t,f 86 for other requirements Conditions of approval Samples required [] Yes ,g~No Mud log required E'] Yes .[;~No Hydrogen sulfide measures [] Yes [] No Directibnal survey required [~ Yes [] No Required work~u¢~~~,~; [] 5M; [] 10M; [] 15M Other: by order of Approvedby k,.....~..~/', ~k.~"j~;C:~'~,~L,/ Commissioner the commission Date Form 10-401 Rev. 1211-85 Subn~i triplicate / HORIZONT^L PROJECTION SCALE I IN. = 1000 FEET ARCO ALASKA, INC. ' PAD 3K, WELL NO, 8 PROPOSED KUPARUK FIELD. NORTH SLOPE. ALASKA EASTMAN WHIPSTOCK, INC. 6000 1 O00 ,,, z 0 _ ~: lO00 _ 2000 _ TARGET LOCATION, 1137' FSL, 154~$' FWL SEC. 34. TI3N. RGE TD LO~AT !!3!' FSL. !378' FWt, SEC. 5000 I 4000 ! WEST-EAST ;~ooo 2oo0 i , 1 000 I TARGET CENTER TND=81?4 DEP-4034 SOUTH t22 WEST 41)32 S 88 DEG 16 MI N W 4034' (TO TARGET) 0 1000 '~ ~L~FACE ! SUflFA~ LOCAT t[~)N' 125g' FSL. 317' FWL SEC. 35. T13N. RGE PAD 3K. WELL NO, 8 Pku~OSED KUPARUK FIELD, NORTH SLOPE. ALASKA EASTMAN WHIPSTOCK, INC. 1 000 _ 2000 3000 4000_ 50OO KOP TVD-1500 TMD=I500 DEP=O BASE PERMAFROST TVD-I?2! TMD=1722 DEP=13 BUILD 3 DL~ 21 PER I oo FT TOP UGNU SNDS TVD=2684 TMD=2777 DEP=411 39 EOC TVD=2783 TMD=2g07 DEP=495 TOP W SAK SNDS TVD=3324 TMD=3637 DEP=g86 K, 12 TVD=3574 TMD=3975 DEP=1213 9 5/8' CSO PT TVD=3774 TMD=4245 DEP=1394 AVERAGE ANGLE 42 DEG 15 MI N 6OOO 7000 i 1 000 K'S TvD=s674 TMD=6elO DEP'-'3! lS ! ! 2000 3000 VERTt CAL SECTION -" T/ ZONE~D TVD=6284 TMD=7634 DEP=3671 T/ ZONE C TVD=6362 TMD=7739 BEP=3742 T/ ZONE A TVD=6625 TMD=8094 DEP=3g80 TARG1[T CNTR TVD=6684 TMD=8174 DEP=4034 · , B/ KUP SNDS TVD=6742 TMD=8252 DEP=4086 TD (LOG PT) TVD=6890 TMD=8452 DEP=4221 4000 5000 ' po ) .... l'iOO._ 1300 _ ] O0 ::>:00 ~'00 ~00 ~oo ~oo 990 ' / : / , i ,/ ' 1 '1 O0 _ 1000._ I I 0 100 I 400 too 200 300 ,. 5oo ; 6oo 900 i I i ± i 800 , _ too~ KUP~RUK R I VER UN I T 20" D I VERTER SCHEMRT ! C ,',! DE SC R I P T I ON 1. 1G" CONDUCTOR. 2. TANKO STARTER HEAD. 3. TANKO SFVER SUB. 4. TANKO LONER QUICK-CONNECT ASSY. S. TANKO UPPER QUICK-CONNECT ASSY. G. 20" 2000 PSI DRILLING SPOOL N/lO" OUTLETS. ?. tO" HCR BALL VALVES W/lO" OIVERTER LINES, A SINQLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION. 8. 20" 2000 PSI ANNULAR PREVENTER. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20 AAC2S, 03S (b) %%% 4 . [' 2 ,,1 MAINTENANCE & OPERATION 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. 2. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. 3. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF NELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DONNHIND DIVERSION. DO NOT SI-RJT IN NELL UNOER ANY C I RCUMSTANCES . RI0 7 6 > > A(~CLMJLATOR CAPACITY TF.~T I. C~ AhD FILL AC~TC~ F2F. S~OIR TO P~ LEVEl. WITH HYORALLIC ~UID. 3. ~ TI~, ~ ~ ~ ~ITS SI~T~~ 4. ~ ~ ~ ~, ~ A~~E L~ LIMI" IS 45 ~~ ~I~ T~ ~ 12~ ~I ~INI~ I · 5 4 3 2 I Ii 1~3-5/8" BOP STACK, TEST I. FILL ~ STAO( AI~ O-ICKE MANIFOLD WITH A~CTIC DIF. S~o 2. Q-ECl( THAT ALL LOCI( D(3~ ~ IN V~.~ A~E FULLY RETRACTED. SF_AT TEST I:~UG IN WITH RtJN41N~ JT AD~ RUN IN L~ LIh~ VALVES ~ TO BOP ~9'AC~. ALL ~. ~ UP TO P-90 ~! ~'- ,L~,~ FDR mO ~N. ~N- ~ P~~ TO'~"P~,I,,'Ah~ HO.O FC~ lO ~IN. BL~ZO M4E~ TO 0~ 5. ~ ~ PRL:'VENTER A/~) MANUAL K,ZLL AN3 Q-K~E Lib[ VALVES. CL0~E TOP PIP~ ~ ~ H(~ VALVES ON K, ZLL ~ O,K](E LI~:S ............ 6. TEST TO 250 PSI A, AD ~ PSi',,AS IN STEP 4. 7. CCt~I~ TESTING ALL VALVES. LIi~.So AJ'~) Q-,~KES WITH A 2.50 PSI LON ~ 3000 PSI HIGH. TEST AS STEP 4. [30 ~3T P~:~~ TEST ANY C:HO<E~TAATY;A NOT A FULL Q...OSING PCSITIYE SEAL ~. F'".,tqCT ]; ON Tg;5'T Q-K;KES THAT DO NOT FULLY Q..OSE. 8. (:PEN TOP PIPE RAMS AN3 CLOSE BOTTCM PIPE RAMS. TEST BOTTCM PIPE RA/v~ TO ;ZSO PSI ~ 3000 PSI. 10. CLOE~ BI,.IN3 RAMS ~ TEST TO 2.50 PSI AJ~D 3000 PSI. II. CPEN BLII~D RAMS A,I~3.RL:'T'~I~E-TEST PL.U~.. MAKE MANIFOLD AI~D. LI~,ES ARE FULL CF NON-FREEZING FLUID. ~ ALL VALVES iN DRILLING PC~ITICN. TEST STAI',[;PIPE VALVES. K~_LY. K_FI_Iy COCKS,, DRILL PIPE SAFETY VALVE. ~ INSICE ~ TO 2.50 PST 3OO0 PSI. J3. RE~ TEST I~FCI:~VATION ON BL~ Pt:~:'VENTF_~ TE.~ FCI~4,, SIGN. A~D SF. AD TO DRILLING SUPERVISCR, i4. PERFORM ~ETE BCF'E TEST AFTER NIPPLING UP Ar[ V~r_EKLY THEREAFTER F"UNCTI(3qALLY ~TE ~ DAI~ 510084001 ~E~ MAY 15,1c. DRILLING FLUID PROGRAM Density PV YP Viscosity Initial Gel Spud to 9-5/8" Surface Casing 9.6-9.8 15-30 20-40 50-100 5-15 10 Minute Gel 15-30 Filtrate AP1 20 pH 9-10 % Solids 10± Drill out to Weight Up 8.7-9.2 5-15 8-12 35-40 2-4 4-8 10-20 9.5-10.5 4-7 Weight Up to TD 10.3 9-13 8-12 35-45 3-5 5-12 9.5-10.5 9-12 Drilling Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW (Kuparuk average) and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this proposed well. LWK5/ih GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS 1. Move in rig. 2. Install Tankco diverter system. 3. Drill 12¼" hole to 9-5/8" surface casing point according to directional plan. 4. Run and cement 9-5/8" casing. 5. Install and test blow out preventer. Test casing to 2000 psig. 6. Drill out cement and 10' new hole. Perform leakoff test. 7. Drill 8½" hole to logging point according to directional plan. 8. Run open hole logs. 9. Continue drilling 8½" hole to provide 100' between plug back total depth and bottom of Kuparuk sands. 10. Run and cement 7" casing. Pressure test to 3500 psig. ~/ 11. Downsqueeze Arctic Pack and cement in 7" x 9-5/8" annulus. 12. Nipple down blow out preventer and install temporary Xmas tree. 13. Secure well and release rig. 14. Run cased hole logs. 15. Move in workover rig. Nipple up blow out preventer. 16. Pick up 7" casing scraper and tubing, trip in hole to plug back total depth. Circulate hole with clean brine and trip out of hole standing tubing back. 17. Perforate and run completion assembly, set and test packer. 18. Nipple down blow out preventer and install Xmas tree. 19. Change over to diesel. 20. Flow well to tanks. Shut in. 21. Secure well and release rig. 22. Fracture stimulate. SHALE _ SHAKERS DEaASSER ! I .~. STR STIR STIR HUD CENTRIFU6E CLEANER LWK4 / ih TYPICAL MUD SYSTEM SCHEMATIC ARCO Alaska, inc. ~_~ Post Office Box 10u.~60 : Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 7, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plat - 3K Pad {Wells I - 18) Dear l.lr. Chatterton' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU1/12 Encl osure If ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~ IIII ........ III __ I I~ .... . L,OCATEO Ill PRO ,~"TED 27 T. 12N. ' ~ ~-~- ~ : " LOCATED IN PROTRACTED LOCATED IN PROTRACTED SECTION 35, T. 13 N., R. 9 E.,U.M. SECTION 35~ T. 15 N., R. 9 E.,U.M. ' I - Y - 6,~,~.74 ~T. 70'~'02.7~" 10 - Y - 6,~,153.79 ~T. 70'~'~.076~ X · S~,~.11 L~G. ~49'4S'~.9~7' X - 5~,~S.69 L~G. 149'45'~.g7~" 14~' FSL, 31~' ~ ~- ~.2 P~' ~.S 11~' ~, 316' ~ ~- ~.8 P~- ~.S 2 - Y - 6,~.~3.~ ~T. 70'~'01.53~" 11 - Y - 6,~,1~.79 ~T. 7~'S9.8~3' X - 5~,~.19 L~G. 149'4S'~.93~ X · 5~,~S.73 ~. 149'4S'~.9774" 1~' ~, 318' ~ ~- ~.4 P~- ~.S 113S' ~, 316' ~ 3 - Y - ~,~.~8.~ ~T. 70'~'02.~79" 1~ - Y - 6,~,103.S3 ~T. 7~'S9.~" X - S~,~.14 L~G. 149'4S'~.9~" X · 5~,~S.7~ L~G. 149'45'~.~S' 1~' ~, 318' ~ ~' ~.S P~ - ~.S 11~' ~, 316' ~ ~- ~.O P~- ~.S 4 - Y · 6,~,353.~ ~T. 70'~'02.~14' 13 - Y - 6.~,078.~ ~T. 70'2S'S9.3~3' X - S~,~.11 LMG. 149'45'~.~3' X · 5~,~5.7~ L~. 149'45'~.~3S" 1359' FSL, 318' ~ ~- ~.7 P~ · ~.S 10~' ~, 316' ~. ~- ~.0 P~- ~.S S - Y - 6,~,3~.~ ~T. 70'~'01.79S~ 14 - Y - 6,~,053.76 ~T. X - S~,~.07 L~G. 149'45'~.~S" X - 5~,~.~ L~. 13~' ~L, 317' ~ ~" ~.8 P~ ~.S 1~' ~, 31S' ~ ~- ~.0 ~- ~.S S - Y - 6,~,~3.~ ~T. 70'~'01.5~1" 15 - Y - 6,~,0~.S3 ~T. 70'2S'~.8451' X · S~,G.OS L~G. 149'4S'~.~78" X - S~,~S.TS 1~' FSL, 317' ~ ~- ~.9 P~' ~.S 10~' ~, 316' ~ ~- ~.0 P~- ~.S 7 - Y - 6,~,~.~ ~T. 70'26'01.~' 16 - Y · 6,~,~3.~ ~T. 7~'~.S~' X - S~,~S.~ L~G. 149'4S'~.~ X - S~,~S.78 ' L~G. 14~4S'~.~S' 1~' ~L. 317' ~ ~ · ~.0 P~" ~.S I0~' FSL, 31S' ~ ~ - ~.0 P~ - 34.5 S - Y - 6,~,2S3.70 ~T. 70'26'01.~ 17 - Y - 6,~7,978.81 ~T. 70'~'~.35S1" X - 5~,~5.~ L~G. 149'4S'~.~" ' X - 5~.~S.77 L~G. ~49'4S'~.~" 1259' KL, 317' ~ ~- ~.0 p~- ~.S 98S' FSL, 315' ~ ~- ~.0 P~- ~.S ~ - Y · 6,~,2~.6S ~T. 70'26'~.8124" 18 - Y - 6,~7,953.69 ~T. 7~25'~.1~ X- S~,~S.9~ ~G. ~49'4S'~.~" X- S~,~5.73 ~G. 14g'45'~.~77" P~- ~.S 959' ~L. 315' ~ FSL, 317'~ ~-~.~ NOTES ..... , . ..... I. ALL COORDINATES ARE A.S.E~ZONE~. ~. ~ALL DISTANCES SHOWN ARE TRUE. ~K CONTROL MONUMENTS PER LHD POSITIONS BASED ON 4. VERTICAL POSITIONS BASED ON 3K TBM No. 4 ~ TBM No. 5 PER LHD ' 5.0.G. ELEVATIONS INTERPOLATED FROM S/C DRAWING CED- RIXX- 3070 rev.~ C[R~FICA~ OF SURV[YOR: I HER[BY C~I~ THAT I AM PROP[RLY~-: ~ .- REGISTERED AND LICENSED TO PRACTICE LAND $URV~YINO IN ~E STAT~ OF ALASKA ~D THAT ~ '- ........ L ~ .? ~ ~ THIS PLAT REPRESENTS ~ LOCATION SURVEY ~..-.. ,- :.. ~ MAD~ BY ME OR UN~E MY SUP[RVISION, AND ~ · '~ - ~ ~E CO~RE~. AS 0F S MAY 1986. / ';'~. T'-~ ,, ,~ . ~... ~ ..... ;.~ ]all ,, ,,co Inc. "'... ~~--~. DATE 2 MAY 1986 ~ KUPARUK PROJECT ':' ': ~ .-' ..... ".' D.~w-~ DRILL SITE 3K CONDUCTOR v _~. ~ ~,t~ ~.E..B..~o. AS-BUILT LOCATIONS '~X... · SCALE , ,, ii II I I I II II I CHECK LIST FOR NEW WELL ITEM. 'APPROVE, DATE (1) Fee >!,,--.-#-/i-J" J'^-- 6-lð-{(. ( thru' 8) (2) Loc ~~ . (3) Admin. . 6 ---Ilf-Ib . . .c;;/}¡ru ~)/. /76 (10 and ~ (4) Casg .{I(.~A:. ~ (14 thru 22) (5) BOPE IIIdø . t"lg~~/, , (23thru28) (6) OTHER Jl,fll. .. (29 thru 31) (6) Add: ~~-la-8L : Lc:n;:eä~~: .- MTM ~ HJH llJJl ~' rev: 04/03/86 6.011 PERMITS Company ~ Lease & Well No. YES NO 1. Is the permit fee attached .......................................... ~-== 2. Is well to be located in a defined pool............................. 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool............ 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party................................. 8. Can permit be approved before ten-day wait .......................... 9. Does operator have a bond in force .................................. 10. Is a conservation order needed ...................................... 11. Is administrative approval needed ................................... 12. Is the lease number appropriate ..................................... 13. Does the well have a unique name ~nd number ..........,'.............. ~- ~ /L-lL~' ~ 1<-- -<¡ REMARKS ~ ~= 14. Is conductor string provided ........................................ ~ 15. Will surface casing protect fresh water zones .........'.............. ~ 16. Is enough cement used to circulate on conductor and surface ......... ~ 17. Will cement tie in surface and intermediate or production strings ... '~ 18. Will cempnt cover all known productive horizons ..................... A- 19. Will all casing give adequate safety in collapse, tension and burst.. """"'- 20. Is this well to be kicked off from an existing wellbore ............. 21. Is old we 11 bore abandonment procedure included on 10-403 ............ 22. Is adequate wellbore separation proposed ............................ z¡¿ 23. Is a diverter system required ....................................... ~ 24. Is the drilling fluid program schematic and list of equipment adequate ~ 25. Are necessary diagrams and descriptions of diverter and BOPE attached. 4:!:L. 26. ÐoE!s'BOPE"'bave"stiffìicient""pres8ure' 'ratirtg"'- "Test't()~ððO"""".""'psiìg'" .'. '21/t.' 27. Does the choke manifold comply w/API RP-53 (May 84)..................' 28. Is the presence of H2S gas probable ................................. For explor~tory and Stratigraphic wells: 29. Are data presented on potential overpressure zones? ................. 30. Are seismic analysis data presented on shallow gas zones ............ 3!. If an offshore loc., are survey results of seabed conditions presented- L Addi,t',i,ona,l Remarks ::fJ,; ~fpn1~ .~, ~ ~,.~~~, ' of lj)(-1 @ r~J.4R~ ~, -(ia - 32. Additional requirements............................................. / INITIAL GEO. UNIT ON OFF POOL CLASS 'STATUS AREA NO. SHORE Lf~ O/J~ () -e,./ J 7J \'J (1 rj III' ÿ 0,,;) ÑL. - .JJ.A. ---- ~ J~ð'" ,~I:'~RI#:""'I4~~"t; =.Ð~v/;~£A. A~í'J\/ 1/~Ai~Al"H'- ;;'1Ub:.# - LV~-I: ~<'ubÞ1/f:l::~J A- I:~' '\" t:j .0 ~z HO cnt-i ~~ >H nt-i tIjtlj ~ \C, .J' Cll 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. ********************** , , * * ********************** *---- S C HL U,HB E RGE R'- *---"----"- ..... '"* TAPE VERIFICATION LIST'ING idBC ()FILMED ! - .VP OIO.HOZ VERIFICATION LISTING PAGE ~ REEL HEADER SERVICE NAME :EDIT 3ATE :85/10/ 8 3RIGIN : 2EEL NAME :149574 CONTINUATION ~ :OI PREVIOUS REEL COMMENTS :LIBRARY TAPE ¢~ TAPE HEADER ~ SERVICE NAME :EDIT DATE :B6/lO/ 8 ORIGIN :0000 TAPE NAME :173B CONTINUATION # :Ol PREVIOUS TAPE : COMMENTS :LIBRARY TAPE ~ FILE HEADER FILE NAME :EDIT .00! SERVICE NAME : VERSION DATE : MAXIMUM LENGTH : 102.4 FILE TYPE : PREVIOUS FILE : ~'~ INFORMATION RECORDS MNEM ~CONTENTS CN : ARCO ALASKA I!NC WN : 3K-8 FN : KUPARUK RANG: gE TOWN: SECT': 35 C'DUN: N. SLOPE STAT: ALASKA CTRY: USA MNEM 'CONTENTS PRES: E ~ COMMENTS UNIT TYPE CATE S'I ZE CODE 000 000 018 0,65 000 000 004 065 000 000 008 06,5 000 000 0'02 065 000 000 00~ 065 :000 000 002 065 000 000 012 065 000 000 006 065 000 000 003 065 UNIT TYPE :CATE SIZE' ~CODE 000 000 001 065 .VP OlO.M02 VERIFICATION LISTING PAGE 2 SCHLUMBERGER ALASKA COMPUTING CENTER SOMPANY = ARCO ALASKA INC WELL = 3K-8 FIELD = KUPARUK COUNTY = NORTH S'LOPE ~OROUGH STATE = ALASKA JOB NUMBER AT ACC: 7[738 RUN e[ DATE LOGGED,: 29-SEP-86 LOP: R~CK KRUWELL CASING = 9.625" @ 42.~' - BIT SIZE = 8.5" TO 8500' TYPE FLUID = WEIGHTED POLYMER DENSITY = 9.9 LB/G RM = 2.98 ~ 68 OF VISCOSITY = 41 S RMF = 2°03 @ 68 D'F PM = 9°5 RMC = 3.58 @ 68 DF FLUID LOSS = 4.4 C3 RM AT BHT = 1.46! @ 146 DF MATRIX SANDSTONE ~~ THIS DATA HAS NOT BEEN DEPTH SHIFTED' .- OVERLAYS FIELD PRINTS .VP 010,H02 VERIFICATION LISTING PAGE SCHLUMBERGER LOGS INCLUDED WITH THIS MAGNETIC TAPE: DUALINDUCTION SPHERICALLY FOCUSED LOG (OIL) DATA AVAILABLE: 8493' TO 4245' FORMATION DENSITY COMPENSATED LOG CFDN) COMPENSATED NEUTRON LOG (FDN) DATA AVAILABLE: 8467' TO ¢2~5° GAMMA RAY IN CASING (GR.CSG) DATA AVAILABLE: 4245' TO 1000' ~, DA'TA FORMAT RECORD ** ENTRY BLOCKS TYPE SIZE REPR CODE ENTRY 2 ! 66 0 4 1 66 1 8 4 73 60 9 4 65 .liN 16 I 66 1 0 1 66 0 .VP OlO.H02 VERIFICATION LISTING P,&GE 4 )EPT SFLU ILO [LM SP ~R ~R ;AL I ~HOB ]RHO qRAT RNRA qPHI ~CNL ~CNL 3PHI 3R )ATUM SPECIFICATION BLOCKS 4NEM SERVICE SERVICE UNIT ID ORDER # LOG TYPE FT O0 000 OIL griMM O0 220 Oil OHMM O0 120 OIL OHMM O0 120 OIL MV O0 010 OIL GAPI O0 310 FDN GAPI O0 310 FDN iN O0 280 FDN G/C3 O0 350 FDN G/C) O0 3:56 FON O0 420 FDN O0 000 FON PU O0 890 FDN CPS O0 330 FON CPS O0 330 FON PU O0 890 CSG GAPI O0 310 API API FILE CLASS MOD NO. O0 0 0 01 0 0 46 0 0 44 0 0 01 0 0 O1 0 0 01 0 0 O1 0 0 02 0 0 Ol 0 0 01 0 0 O0 0 0 O0 0 0 31 0 0 30 ~0 0 O0 0 0 O! 0 0 SI ZE 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 SPL 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 REPR P CODE ( 68 00000000 68 00000000 68 00000000 68 00000000 68 00000000 68 00000000 68 00000000 68 00000000 68 00000000 68 00000000 68 00000000 68 00000000 68 00000000 68 00000000 68 00000000 68 00000000 68 00000000 ROCESS OCTAL) 000000 000000 O000OO 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 .000000 000000 DATA DEPT 8533.500'0 SFLU SP -25.5313 GR RHOB 1.6201 DRHO NPHI 43.2617 NCNL GR -999.2.500 DEPT 8500.0000 SFLU SP -20.3125 GR RHOB 1.6133 OR'HO NPHI 43.2129 NCNL GR -9'99.2500 DEPT 8400.0000 SFLU SP -21.9531 GR RHOB 2.4512 ORHO NPHI 33.7891 NCNL GR -999.2.500 DEP'T 8300.0~0~00 SFLU SP -20.7.500 GR RHOB 2.410Z DRHO NPHI 4).1660 NCNL GR -999.2500 DEPT 8200.'0000 SFLU SP -5,5.2187 GR RHOB 2..5039 DRHO NPHI 39.4043 :NCNL GR -999.2500 2.8027 ILO 81.187.5 GR 0.0405 NRAT 2210.0000 FCNL 2.7948 ILO 81.1875 GR 0.0244 2210.0000 'FCNL 3.9717 87.3750 GR 0.0112 NRAT' 2398.0000 FCNL 2.7117 I L O 88.1250 GR 0 ,' 0913 N R A'T 8.5.0000 F C N L 3.6291 'ILO 91.8'125 GR 0.089,4 NRAT 1992.0000 FCNL 2.2754 81.1875 3.2754 624.5000 2.2770 81.1875 3-2754 624.5000 3.771.5 87'37.50 2.9805 746.0000 2.6146 88.1250 3.7930 445.2500 3.2319 91,8125 3. 4180 23.5000 ILM CALI RNRA DPHI ILM' CALI RNRA DPHI, I LM CALI RNRA DPHI ILM CALl RNRA OPMI ILM CALI R.NRA OPHI 2.363.5 4.9531 3.5371 62.4209 2- 3624 5.0078, 3' 5371 62,8352 3.9238 8.4141 3.212.9 12.0590 2.7022 101.9'766 3.7832 14.5445 3.3398 10.0313 3.8047 8.8633 .VP OlO.H02 VERIPICATICN LISTING PAGE 5 2EPT 8100.0000 SFLU SP -26.0000 GR ~HOB 2.2031 DRHG ~PHI 30.6641 NCNL ~R -999.2500 110.7151 ILD 40.5313 GR 0.0171 NEAT 2660.0000 FCNL }EPT 8000.0000 SFLU SP -42.5000 GR RHOB 2.4277 DRHO NPHI 31.7383 NCNL SE -999.2500 8.3600 ILO 79.1875 GR 0.0479 NEAT 2340. 0000 FCNL 3EPT 7900.0000 SFLU SP -35.2500 GR RHOB 2.4746 DRHO NPHI 31.7871 NCNL GR -999.2500 2.2723 ILD 102.7500 GR 0.0503 NEAT 2106.0000 FCNL DEPT 7800.0000 SFLU SP -41.5000 GR RHOB 2.4746 DRHO NPHI 35.0586 NCNL GR -999.2500 2.4548 ILD 120.875,0 GR 0.0503 flRAT 2118.0000 FCNL DEPT 7700.0000 SFLU SP -25.9687 GR RHOB 2o3145 DEMO NPHI 45. 9961 N'CNL GR -999. 2500 1.4527 ILD 12,4,.4375 GE 0.0'073 NRAT 1592.0000 FCNL DEPT 7600.0000 SFLU SP -16.2500 GR RHOB 2. 2266 DRHO NPHI 47' 8027 NCNL GR -999.25,00 1.4806 ILD 1'17.43'75 GR -0'0005 NEAT 1616.00'00 F:CNL DEPT 7500.0000 S:FLU SP -38'0000 GR EH'OB 2.3438 DEMO NPHI 51,5625 NCNL GR -999.2500 1,,8278 ILO 1.20 . 312, $ G R. 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ILM :CALI RNRA DPHI ILM CALI RNRA DPHI ILM C AL I RNRA D.PH I 3.0092 8.9766 3.9121 13.9527 2.0969 -999.2500 -999.2500 -999.2500 1.6311 -999.2500 -999.2500 -999.2500 2.6981 -999.2500 -999.2500 -999.2500 2.9990 -999.2500 -999.2500 -999.2500 3.1030 -999.2500 -999,2500 -999.25'00 2.6668 -9'99.2500 -999'2500 '-999.25'00 2.6226 -999.250'0 -999.2500 -9'99-2500 2.6291 -999.2500 -999.2500 -999.2500 LVP OlO.H02 VERIFICATION LISTING PAGE 7 3EPT SP RHOB NPHI GR DEPT SP RHOB NPHI GR DEPT SP RHOB NPHI GR DEPT SP RHOB NPHI GR DEPT SP RHO8 NPHI GR DEPT SP RHOB NPHI GR DEPT SP RHOB NPMI GR DEPT SP RHOB NPHI GR DEPT SP RHOB NPHI GR 6300.0000 SFLU -47.0000 GR -999.2500 DRHO -999.2500 NCNL -999.2500 6200,0000 SFLU -46.5000 GR -999,2500 DRHO -999,2500 NCNL -999,2500 6100.0000 SFLU -49.0000 GR -999.2500 DRHO -999.2500 NCNL -999.2500 6000.00100 SFLU -48°7500 GR -999.2500 DRHD -999.2500 N'CNL -999.2500 5900,0000 SFLU' -51.2500 GR -999.250:0 DRHO -999.2500 NCNL -'999.2500 5800.0000 SFLU -52.7500 GR -999.2500 DRHO -999.2500 NCNL -999.2500 5700.000:0 SFLU' -51,00'00 GR -999,2500 DRHO -999.2500 NCNL -999.2500 5600.0000 SFLU -57-0000 GR -999.2500 DRHO -999.2500 NCNL -999.2500 5500.0000 SFLU -58.1250 GR -999.2500 DRHO -999.2500 NCNL -999,2500 1,9996 ILD 94,7500 GR -999,2500 NRAT -999.2500 FCNL 2.7482 ILD 90.5000 GR -999.2500 NRAT -999.2500 FCNL 2.8677 ILD 93.3750 GR -999.2500 NRAT -999.2500 FCNL 2,7571 ILO 100,5000 GR -999,2500 NRAT -999.2500 FCNL 3.0334 ILO 106.0000 GR -999.2500 NRAT -999.2500 FCNL 2. 8389 ILO 97.8125 GR -999-2500 NRAT - g g 9.2500 F C N L 2.3905 101.93'75 GR -999.2500 NRAT -999. 2500 FCNL 2.9446 I:LD 122.9375 GR -999.2500 NRAT -999,2500 FCNL 2,5421 ILO 99.3125 GR -999.2500 NRAT -999.2500 FiCNL 2.3597 -999.2500 -999.2500 -999,2500 3.2960 -999.2500 -999.2500 -999.2500 3.1035 -999. 2500 -999.2500 -999.2500 3.0198 -999.2500 -999.2500 -999.2500 3.3118 -999.2500 -999.2500 -999.2500 3.3617 ,-999.2500 -999.2500 -99'9.2500 2'7382 -999,,. 25 00 -999.2500 -99'9.2500 3.[842 -999.250'0 -999.2500 -999.2500 2.8241 -999.2500 -999,,2500 -999,2500 ILM CALI RNRA DPHI ILM CALi RNRA D.PH I ILM CALI RNRA DPHI ILM CALI RNRA DPHI ILM CALI RNRA DPHI ILM CALI RNRA DPHI ILM C A'LI RNRA DPHI I~LM CALI RNR A DPHI I,LM. CALI R N R A DPHI 2.3828 -999.2500 -999.2500 -999.2500 3,1590 -999.2500 -999,2500 -999,2500 3.1166 -999.250.0 -999.2500 -999.2500 3.0075 -999.2500 -999,.2500 -999.2500 3.3232 -999.2500 -999.2500 -999,250'0 3.2623 -999.2500 -999.2500 -99'9-2500 2.7057 -999.2500 -999.2500 -999.2500 3.0957 -999-2500 -999.2.500. -999.2500 2,.778:0 -999.2500 -99'9.250~0 -999.2:5'00 .VP OlO.H02 VERIFICATION LISTING PAGE 8 )EPT 5400.0000 SFLU ;P -61.5313 GR ~HOB -999,2500 DRHO ~PHI -999.2500 NCNL ;R -999.2500 )EPT 5300.0000 SFLU ~P -54.5000 GR ~HOB -999.2500 DRHO ~PHI -999,2500 NCNL JR -999,2500 )EPT 5200,0000 SFLU 5P -56,5000 GR ~HOB -999,2500 DRHD NPHI 37.9883 NCNL ~R -999.2500 DEPT 5100.0000 SFLU SP -51.9687 GR RHDB 2.3535 DRHO NPHI 40.7715 NCNL GR -999.2500 DEPT 5000.0000 SFLU SP -58.3750 GR RHDB -999.2500 ORHO NPHI -999.2500 NCNL GR -999.2500 DEPT 4900,0000 SFLU SP -60.5000 GR RHOB -999,2500 DRHO NPHI -999.2500 NCNL GR -999.2500 DEPT 4800,0000 SFLU SP -60.5000 GR RMOB -999-2500 D:RHO NPHI -999,2500 NCNL GR -999°2500 DEPT 4700,0000 SFLU SP -62.0000 GR RHOB -999.2:500 DRHO NPHI -999.2500 NCNL GR -999,2500 DEPT 4600,0000 SFLU SP -66,2500 GR RHOB 2,2363 DRMO NPHI 39.6973 NCNL GR -999,2500 2.8498 ILD 96.2500 GR -999.2500 NRAT -999.2500 FCNL 2.0876 ILD 86,3125 GR -999.2500 NRAT -999.2500 FCNL 2.7167 ILD 84,8750 GR -999,2500 NRAT 1925,0000 FCNL 3.2004 ILO 97'0000 GR 0.0415 NRAT 2032.0000 FCNL 3.2004 ILD 105.8125 GR -999.2500 NR'AT -999.2500 FCNL 1.9542 ILO 89'5000 .GR -999.250:0 NRAT -999,2500 FCNL 2.6.011 ILO 88, 1250 GR. -999.25'00 N'RAT -999. 250.0 FCNL 2,7791 ILD 98.7500 G.R -999.2500 NRAT -999.2500 FCNL 3.8707 'ILO 86,1875 GR 0,0200 NRAT' .18~1,0000 FCNL 3.0960 -999.2500 -999.2500 -999.2500 3.8225 -999.2500 -999.2500 -999.2500 3,0241 84.8750 -999.2500 568.0000 3.8008 97.0000 3.4629 562.0000 3.4010 105,8125 -999.2500 -999.2500 2.1332 -999.2500 -999.2500 -999.2'500 2.8550 -999.2500 -999.2500 -999.2.500 2.7835 -9'99.2500 -999.2500 -999.2500 4.2763 86.1875 3.4824 515.0000 ILM CALl RNRA DPHI ILM CALl RNRA DPHI ILM CALI RNRA DPHI ILM CALI R NRA DPHI ILM CALI RNRA DPHI lC AL i RNRA OPHI I L M CALI RNRA DPH I ILM CALI RNRA DPHI ILM CALI R N R A DPHI 3.0445 -999.2500 -999.2500 -999.2500 3.4675 -999.2500 -999.2500 -999.2500 2.9459 9.8516 -99'9.2500 16.9117 3.5632 9.6719 3,6152 17.9770 3.4463 10.0938 -999.2500 -999.2500 2.1062 -999.2500 -99'9.2:500 -999.2500 2.8081 -9'99.2500 -99'9.2500 -999.2500 .2.7216 -999.2500 -999.2500 -999.2500 4,12.21 10.6250 3.5742 25.0785 .VP OlO.H02 VERIFICATION LISTING PAGE 9 )EPT ~P ~HOB ~PHI )EPT SP ~HOB qPHI .~R 3E PT ~HOB NPHI DEPT SP RHOB NPHI GR DEPT SP RHOB NPHI GR DE PT SP RHO B NPHI GR D E PT SP RHDB NPHI GR OEPT S'P RHOB NPHI GR DEPT SP RHDB NPHI GR 4500.0000 SFLU -64.2500 GR 2.2559 DRHO 46.8262 NCNL -999.2500 4400.0000 SFLU -65.5625 GR 2.2637 DRHO 45.65¢3 NCNL -999.2500 4300.0000 SFLU -63.2500 GR 2.1680 DRHO 42.0410 NCNL 95.3125 4200.0000 SFLU -999.2500 GR -999.2500 DRHO -999.2500 NCNL 53.0000 4100.0:000 SFLU -9'99.2500 GR -999.2500 D, RHO -999°2500 NCNL 45.5625 4000'0000 SFLU -999.2500 GR -999.2500 DRHO '-999.2500 NCNL 52.5938 3900'0000 SFLU -999.2500 GR -999.2500 DRHO -999.2500 NCNL 46.0000 3800.0000 SFLU -999.250'0 GR -999.250:0 ORHO -999.2500 NCNL 52.9062 3700.0000 SFLU -999.2500 GR 1-999.2500 ORHO -9'99.2500 NCNL 63,8750 2.5864 ILD 83.2500 GR 0.0361 NRAT 1713.0000 FCNL 2.6654 ILD 86.4375 GR 0.0298 NRAT 1746.0000 FCNL 3.5069 ILO 74.7500 GR 0.0254 NRAT 1720.0000 FCNL -999.2500 ILD -999.2500 GR -999.2500 NRAT -999.2500 FCNL -999.2500 ILO -999.2500 GR -99'9.2500 NRAT -999.2500 FC:NL -999.2500 ILD -999.2500 GR -999.2500 NRAT -999.25'00 :FCNL -999.2500 ILO ,-999.2500 GR -999.250.0 NRAT -999.2500 FCNL -999.2500 ILD -99'9'2500 GR -999.2500 :NRAT -999.2500 F:CN:L -999.2500 ILD -999.2500 GR -999.2500 ,NR'AT, -999.2500 FCNL 2.8567 83.2500 3.9023 402.7500 3.1774 86.4375 3.8301 420.5000 4.0422 74.7500 3.5156 469.0000 -999.2500 -999.2500 -999.2500 -999.2500 -99'9.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -9'99.2500 -999.2500 -999.2500 -'999.250~0 -999.2500 -999.2500 -999.25:00 -999.2500 -'99'9.2500 -9'99.2'500 -99'9.2500 -999.250'0 -999.£500 ILM CALl RNRA DPHI ILM CALI RNRA D PM I ILM CALI RNRA DPHI ILM CALI RNRA OPHI ILM CAL! RNRA DP'HI ILM CALI RNRA DPHI ILM CALI R'NRA DPHI ILM CALI R NRA DPHI ILM' CALI RNRA OPHI 2.8096 11.6328 4.2500 23.8949 2.9797 11.3828 4.1484 23.4215 3.7963 9.4688 3.6660 29.2211 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -9:99.2500 -'999.2'500 -999.2500 -999,2500 -999.2500 -999.2500 -999.25,00 -999.Z500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 .VP 010.H02 VERIFICATION LISTING PAGE 10 3EPT RHOB qPHI ~R 3EPT SP RHOB NPHI GR DEPT SP RHOB NPHI GR DEPT SP RHOB NPHI GR DEPT SP RHOB NPHI GR DEPT, SP RHOB NPHI GR DEPT SP RHDB NPHI GR DEPT SP RHOB NP H I G'R DEPT SP RHDB NPHI GR 3600.0000 SFLU -999.2500 GR -999.2500 DRHO -999.2500 NCNL ~2.1875 -999.2500 ILD -999.2500 GR -999.25'00 NRAT -999.2500 FCNL 3500.0000 SFLU -999.2500 GR -999.2500 DRHO -999.2500 NCNL 48.0000 -999.2500 -999.2500 GR -999.2500 NRAT -999.2500 FCNL 3400.0000 SFLU -999.2500 GR -999.2500 DRHO -999.2500 NCNL 47.7813 -999.2500 ILO -999.2500 GR -999.2500 NRAT -999.2500 FCNL 3300.0000 SFLU -999.2500 GR -ggg.2$O0 ORHO -999.2500 NCNL 14o0859 -999. 2500 ILO -9gg. 2500 GR -999. 2500 NRAT -999. 2500 FCNL 3200.0000 SFLU -999.2500 GR -999.2500 DRHO -999.2500 NCNL 46.5938 -999.2500 ILO -999.2500 GR -999.2500 NRAT -999.2500 FCNL 3100.0000 SFL~U -999.2500 GR -999.2500 DRHO -999.2500 NCN'L -'999.2500 ILD -999.2500 GR -999.2500 NRAT -999.2500 FCNL' 3000.0000 SFLU -999-259'0 GR -999.2500 DRHD -999.2500 NCNL 32.'0313 -999. 2500 ILO -999.250'0 GR' -999° 25;00 NRA'T -9'99. 2500 FCNL 2900.0000 SFLU -999.25,00 'GR -999o2500 DRHO -'9'99.2500 NCN'L 35.6250 '99:9.2500 ILO, -999.250'0 GR -999.2500 NRAT "-99'9.250'0 FCNL 2800.0000 SFLU -999.2500 GR -999.2500 D:RHO -999°2500 NCN'L 36.3750 -999.2500 ILD -999,.250!0 GR -999.2500 NRAT -999°2500 FCNL -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999-2500 -9'99.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999o25'00 -999°2500 -999°2500 -999.250'0 -999°2500 -999-2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 ILM CALI RNRA DPHI ILM CALI RNRA DPHI ILM CALI RNRA DPH! I LM .CALI RNRA DPHI ILM CALI RNRA DPHI ILM CALI R N R A D'PH I CALI RNRA DPHI ILM CALI RNRA DPHI ILM R iN R :A DPHI -999.2500 -999,o2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -99'9.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -99.9.2500 ,.999.2500 -99,9.2500 -999-2500 -999*2500 -999.2500 -999..2500 -999.2500 -99'9.2'500 -999°2500 -99'9.2500 -999.2500 -9'99.2500 -99'9.2500 -9:99.2:500 .VP OlO.H02 VERIFICATION LISTING PAGE )EPT ~P ~HOB qPHI ~R ]EPT SP ~HOB ~ PHI ~R 3EPT SP ~HOB 4PHI SR OEPT SP R'H 0 B NPHI GR DEP'T SP RHOB NPHI GR DEPT SP RHOB N,PHI GR DEPT SP RHOB NPHI GR DEPT SP RHOB NPHI GR DEPT SP RHOB NPHI GR 2700.0000 SFLU -999.2500 GR -999.2500 DRHO -999.2500 NCNL ~3.5313 2600.0000 SFLU -999.2500 GR -999.2500 DRHO -999.2500 NCNL 36.7813 2500.0000 SFLU -999.2500 GR -999.2500 DRHO -999.2500 NCNL 27.265,6 2400.0000 SFLU -999.2500 GR -999.2500 DRHO -999.2500 NCNL 32.9062 2300.0000 SFLU -999.2500 GR -999,.2500 DRHO -999.2500 NCNL 36.5938 2200.0000 SFLU -999.2500 GR -999.2500 DRHO -999.2500 NCNL ,45.7500 21:00.0'000 SFLU -999.2500 GR' -999.2500 DRHO -999.2500 NCNL 31'8125 2000.0000 S'FLU -999.2500 GR -9'99.2500 DR:HO -999.25,00 NCNL 27,8281 1900.0000 SFLU -999.2500 GR -999,.2500 DRHO -999.2500 NCNL 46'1.875 -999.2500 ILD -999.2500 GR -999.2500 NRAT -999.2500 FCNL -999.2500 ILD -999.2500 GR -999.2500 NRAT -999.2500 FCNL -999.2500 ILD -999.2500 GR -999.2500 NRAT -999.2500 F,CNL -999.2500 ILD -999.2500 GR -999.2500 NRAT -999.2500 FCNL -999.25~00 ILD -999.25:00 GR -999.2500 NRAT -999.2500 FCNL -999.2500 ILO -999.2500 GR -999.2500 NRAT -999.2500 FCNL -999.2500 ILO -999.250.0 GR -999.2500 NRAT -999.2500 FCNL -999.2500 ILO -999.2500 GR -999.25'0'0 NRAT -999-250'0 FCNL -999.2500 ILD -999°2500 GR -999.2500 NRAT -999,2500 FCNL -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 ,-999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999. 250.0 - 9'99.25,00 -999. 2500 -999.2500 -999.2500 -999.2500 -999,.25:00 -999.2500 ILM CALI RNRA DPHI ILM CAL2 RNRA DPHI ILM CALI RNRA DPHI ILM CALl RNRA DPHI I :L M CALI RNRA DPHI ILM CA'LI. R,NRA DPHI CALI R,NRA DPHI ILM CALI RNRA O P H I ILM CALI RNRA D PHI -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.Z500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.25 O0 -999.250'0 -'999 . 2500 - 999 . 2 S 0'0 -999. 2500 -999 · 2500 -999,. 2500 -999.25:00 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999.2500 -999.2500 -999.2500 .VP OlO.H02 VERIFICATION LISTING PAGE )EPT 1800.0000 SFLU SP -999.2500 GR ~HOB -999.2500 DRHO qPHI -999.2500 NCNL ~R 22.9375 2EPT 1700.0000 SFLU SP -999.2500 GR RHDB -999.2500 DRHO NPHI -999.2500 NCNL ER 45.5938 DEPT 1600.0000 SFLU SP -999.2500 GR RHOB -999.2500 DRHO NPHI -999.2500 NCNL GR 22.2344 DEPT 1500.0000 SFLU SP -999.2500 GR RHDB -999.2500 DRHO NPHI -999,2500 NCNL GR 31.1406 DEPT 1400.0000 SFLU SP -999.2500 GR RHOB -999.2500 DR'HO NPHI -999.2500 NCNL GR lg.593B DEPT 1300-0000 SFLU SP -999.2500 GR RHOB -999.2500 DRHO NPHI -999.2500 NCNL GR 36.,0938 DEPT 12.00,0000 SFLU SP '999.2500 GR RHOB -999,2500 DRHO NPHI -999.2500 NCN'L GR 24.3594 DEPT 1100.0000 SFLU SP -999,250'0 GR RHOB -999.2500 DRHO NPHI -999.2500 NCNL GR 35.5938 · DEPT 1000.0000 SFLU SP -999-2500 'GR RHOB -999.2500 DRHO NPHI -999.2500 N'CNL GR 51.31.25 -999.2500 ILO -999.2500 GR -999.2500 NRAT -999.2500 FCNL -999.2500 ILD -999.2500 GR -999.2500 NRAT -999.2500 FCNL -999.2500 IiLD -999.2500 GR -999.2,500 NRAT -999.2500 FCNL -999.2500 ILD -999,2500 GR -999.2500 NRAT -999,2500 FCNL -999.25.00 ILD -999.2500 GR -999.2500 NRAT -999.250'0 F~CNL -999.2500 IgD -999.2500 GR -999.250'0 NRAT -999.2500 FCNL -999,2500 ILD -999-2500 GR -999.2500 NRAT -999,25,00 :FCNL -999.2500 ILD -999.2500 GR -999.250D NRAT -999.2500 FCNL -999.2500 -999.2500 GR -'999.2500 'NRAT -999.2500 FCNL -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999,2500 -999.250,0 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 .-999.2~00 -999.2500 -999.250'0 .-999.250D -999,2500 -9'99,250'0 -999.2500 -999,2500 -999.2500 -999.2500 -999.'2500 -999.2500 -999.2500 -999,2500 -999.2500 -999.2500 -999,2500 ILM CALl RNRA DPHI ILM CALI RNRA OPMI ILM CALI RNRA DPHI ILM CALI RNRA DPMI ILM CALI RNRA DPMI ILM CALI RNRA' DP'MI ILM CALI RNR,A OPHI ILM CALI R;NRA DPHI ILM CALl RNRA DPHI -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999.2500 -999.2500 -999.2500 -999,2500 -999.2500 -999.2500 -999,2500 -999.2500 -999.2500 -999.250:0 -999.2500 -999.2500 -999.2500 -99'9.2500 -999.250'0 ,-999.2500 -999.2500 -9'99,2500 -999,2500 '-999o2~00 -999,2500 -999.2500 -999.2500 -999.2500 -99'9.2500 -999.25001 '-999.2500 -999.2500 -999.2500 -999.25'00 -999.2500 .VP OlO.H02 VERIFICATION LISTING PAGE 13 ]EPT 5P 2H OB qPHI 994.0000 SFLU -999.2500 GR -999.2500 DRHg -999.2500 NCNL 50.4063 -999.2500 ILO -999.2500 GR -999.2500 NRAT -999.2500 FCNL ,-"",- FILE TRAILER =ILE NAME :EDIT .001 SERVICE NAME : VERSION # : 3ATE : ~AXIMUM LENGTH : 1024 mILE TYPE : ~EXT FILE NAME : ~* TAPE TRAILER SERVICE NAME :EDIT DATE :86/10/ ORIGIN :0000 TAPE NAME : CONTINUATION t~ :01 NEXT TAPE NAME : COMMENTS :LIBRARY TAPE ** REEL TRAILER ** SERVICE NAME :EDIT DATE :85/10/ 8 ORIGIN : RE EL NAME :149574 CONTINUATION ~ :01 NEXT REEL NAME : COMMENTS :tIBR/~RY TAPE -999.2500 ILM -999.2500 CALI -999.2500 RNR~ -999.2500 DPHi -999.2500 -999.2500 -999.2500 -999.2500
