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186-077
WELL HISTORY FILE COVER PAGE XHVZS This page identifies oversize material and digital infonnation 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. Itll - () '1 '1 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 # Other # Yes No Yes No Yes No Mud Logs # - General Notes or Comments about this file. ~"'r" \ I to} \\, IZo. + 1-' t;~p:,} J - -+.. a..r\:;'. N-.,p r7 cSøs I,. .(C1(of If any of the infonnation 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 Fli L., V C LI • STATE OF ALASKA • 4 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT ANA la. Well Status: Oil ❑ Gas ❑ SPLUG 111 Other ❑ Abandoned FA • Suspended ❑ 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Service 0 Stratigraphic Test Ell 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. or Aband.: January 14, 2012 186 - 077 / 311 - 372 . 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 April 5, 1986 50 - 029 - 21580 - 00 • 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 1561' FSL, 155' FEL, Sec. 29, T13N, R9E, UM , April 11, 1986 3N - 11 Top of Productive Horizon: 8. KB (ft above MSL): 68' RKB ' 15. Field /Pool(s): 1256' FSL, 938' FEL, Sec. 20, T13N, R9E, UM GL (ft above MSL): 36' AMSL• Kuparuk River Field • Total Depth: 9. Plug Back Depth (MD + TVD): 1508' FSL, 1006' FEL, Sec. 20, T13N, R9E, UM 8682' MD / 6560' 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 518246 y - 6013799 Zone 4 8790' MD / 6637' TVD • ADL 25521, 25512 TPI: x - 517436 y - 6018772 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 517367 y - 6019024 Zone 4 SSSV @ 1797' MD / 1731' TVD 2557, 2553 18. Directional Survey: Yes ❑ No 1g 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 / 1650' TVD • 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re drill /Lateral Top Window MD/TVD none not applicable 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 36' 115' 36' 115' 24" 250 sx CS II 9.625" 36# J -55 35' 4558' 35' 3632' 12.25" 1300 sx AS III, 350 sx Class G 7" 26# J -55 30' 8777' 30' 6627' 8.5" 300 sx Class G, 175 sx AS I 4.5" 11.6# L -80 8130' 8625' 6168' 6519' na 15 bbls 16ppg Class G w /GASBLOK 24. Open to production or injection? Yes ❑ No El If Yes, list each 25. TUBING RECORD Interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 3.5" 8173' 8130' MD / 6169' TVD perfs cemented off: 1 8420' - 8589' MD 6374' - 6493' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. j DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 1 sCANNE'� 9 2013 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) not applicable abandoned 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 Q Sidewall Cores Acquired? Yes ❑ No Q If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. NONE MOMS MAR 15 Mid wn Form 10-407 Revised 10/2012 CONTINUED ON REVERSE Submit original only C/IIj i//2 /i3 - M LI i/4 )``31 /(;,1 28. GEOLOGIC MARKERS (List all formations and rrs encountered): 29. • FORMATION TESTS • • NAME MD TVD Well tested? El Yes 0 No If yes, list intervals and formations tested, Permafrost - Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Bottom 1700' 1650' needed, and submit detailed test information per 20 AAC 25.071. not applicable N/A Formation at total depth: na 30. LIST OF ATTACHMENTS Summary of Daily Operatio•s, schematic 31. I hereby rtify that the fore.. sng is true and correct to the best of my knowledge. Contact: J. Gary Eller @ 263 - 4172 Email: J.Gary.Eller @conocophillips.com Printed Nam J. Ga\\ Title: Staff CTD Engineer \ Signature Phone 263 4172 Date 3 i _/ 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 10/2012 STATE OF ALASKA ALA. OIL AND GAS CONSERVATION COMM ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair well r Plug Perforations r Stimulate r Other w Converting WINJ P Tubing to Producer Alter Casing r g � Perforate New Fbol r Waiver r Time Extension Change Approved Program r Operat. Shutdow n r Perforate r Re -enter Suspended Well r7 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r i 186 -077 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic r Service 50 - 029 - 21580 - -e)a 7. Property Designation (Lease Number): 8. Well Name and Number: ADL- 25521,25512 w 3N -11 9. Field /Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 8790 feet Plugs (measured) None true vertical 6637 feet Junk (measured) None Effective Depth measured 0 feet Packer (measured) 8158, 8287 true vertical 0 feet (true vertucal) 6188, 6279 Casing Length Size MD TVD --- -Burst— Collapse CONDUCTOR 79 16 115 115 I RECEIVED SURFACE 4523 9.625 4558 3632 PRODUCTION 8746 7 8777 6627 i c &NNED � R 6 9 � { i . al % C ; ,�cr s. Commission Perforation depth: Measured depth: 8420- 8435, 8475 - 8490, 8498 - 8518, 8523 - 8524, 8540 - 8560,8561? 8562,856 -B58fl- - -.- True Vertical Depth: 6374 - 6384, 6412 - 6423, 6374 - 6384, 6447 - 6447,6459- 6473,6474- 6474,6476 -6493 Tubing (size, grade, MD, and TVD) 3.5 x 2.875, J -55, 8357 MD, 6329 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER FHL PACKER (PINNED 60M# SHEAR) @ 8158 MD and 6188 TVD PACKER - BROWN 'HB' PACKER @ 8287 MD and 6279 TVD SSSV - NIPPLE @ 531 MD and 531 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 1268 250 2813 Subsequent to operation 4 0 2993 760 800 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development pi Service r Stratigraphic r 15. Well Status after work: Oil 17 Gas r WDSPL r Daily Report of Well Operations X GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt 311 -344 Contact Darrell Humphrey / Bob Christensen Printed Name Robert n■ Christen ,-n Title Production Engineering Specialist Signature Phone: 659-7535 Date --) / q - 6 /z- fl �� Form 10-404 Revised 10/2 DMS APR 0 2 20 Submit Oinginal Only • 3N -11 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 11/16/11 TAG BTM @ 8531' SLM, EST. 35' OF FILL, MEASURE SBHP @ 8504' RKB= 4359 psi. JOB COMPETE 11/19/11 Turned well to production I I I � I I I I I I I I I I I I I I I � I • a KUP 3N -11 e ConocoPhillips ° Well Attributes Max Angle & MD TD _ Welibore APIIUWI Field Name Well Status Incl (°) MD (re(B) Act Btm (RKB) cAn000PNak 500292158000 KUPARUK RIVER UNIT PROD 49.88 2,400.00 8,790.0 "` Comment H25 (ppm) Date Annotation End Date KBGrd (ft) Rig Release Dab ." _ SSSV: NIPPLE Last WO: 11/16/2007 39.49 4/13/1986 Well Confi9 S 3N 11. 1 11'.06'.13 AM Schematic - - Actu al Annotation Depth End Date Annotation Last Mod ... End Dab Actual p th ( RKB 1 Last Tag: RKB 8,554.0 11/16/2011 Rev Reason: TAG ninam 12/2/2011 HANGER, 0 =--r Casing Strings Casing Description String O... String ID... Top (M68) Set Depth (f... Set Depth (TVD) ... String Wt... String... String Top Thrd CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H - 40 WELDED Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.765 35.0 4,558.0 3,631.6 36.00 J BTC Casing Description String 0... String ID ... Top (MB) Set Depth (f... Set Depth (TVD) ... String Wt_. String ... String Top Thrd pi . i=i I 1 PRODUCTION 7 6.276 30.4 8,776.6 6,627.2 26.00 J -55 BTC y bng t Tub i Descr rings String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 3 1/2 2.992 0.0 8,245.2 6,249.4 9.30 L -80 EUE 8RD CONDUCTOR. Completion Details 36-115 Top Depth (TVD) Top Inc! Nomi... NIPPLE, 531 Top (RKB (RKB) 1 Item Description Comment ID (in) 0.0 0.0 0.38 HANGER FMC Tubing HANGER w /pupjt 2.992 531.2 531.2 0.68 NIPPLE 2.812" 'DS' Nipple(2.856" lock) 2.812 8,144.6 6,178.5 45.32 PBR Baker PBR seal assembly (pinned 40M #)w /1' Space Out 2.992 8,158.2 6,188.1 45.28 PACKER Baker FHL Packer (pinned 60M# shear) 3.030 SURFACE, 35 55 8 8,200.2 6,217.7 45.08 NIPPLE 2.75" 'D' Nipple 2.750 L 8,238.8 6,244.9 45.01 XO Redudng 2 -7/8" pin x 3-1/2" box L-80 EUE 8RD crossover 2.480 DAs LIFT, 8,240.3 6,246.0 45.01 OVERSHOT Tubing Stub Overshot + 1' space out 3.000 8,090 Tubing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING Original 2 7/8 2.441 8,234.5 8,358.3 6,329.6 6.50 J -55 EUE8rdABMOD al Completion Details MI Top Depth (TVD) Top Incl Nomi... P8R. 8,145 Top (R(B) (RKB) (°) Item Description Comment ID (in) PACKER, 6158 8,270.0 6,267.0 44.95 PBR BROWN PBR 2.460 Inr 8,286.7 6,278.8 44.92 PACKER BROWN 'HB' PACKER 3.000 a 8,324.7 6,305.7 44.86 NIPPLE CAMCO 'D' NO GO NIPPLE 2.250 8,357.4 6,328.9 44.80 SOS SHEAROUTSUB 2.441 NIPPLE. 8,200 ilk i Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (TVD) Top Incl Top {ItKB) (RKB) ( "1 Description Comment Run Date ID (in) xo Reducing, e; 6,480.6 44.61 FISH 1" BK Latch Ring Lost in Hole; May be laying in one of 10/25/1987 8,239 Lower GL OVERSHOT, 8.240 Perforations & Slot Shot - Top (TVD) Btm (TVD) Dens Top (1568) Ben (RKB) (RKB) OMB) Zone Dab )eh.- Type Comment P6R, 8,270 8,420 8,435 6,373.6 6,384.2 UNIT D, C-4, 8/23/1999 4.0 APERF 0 deg phase/90 deg CW from PACKER, 8,287 UNIT B, 3N-11 lowside; 2 1/8" EJ 8,475 8,490 6,412.4 6,423.0 A -3, 3N-11 9/26/1987 8.0 APERF 60 deg. ph; 2 1/8" Silver Jet NIPPLE, 8.325 8,498 8,518 6,428.7 6,442.9 A -2, 3N-11 9/26/1987 8.0 APERF 60 deg. ph; 2 1/8" Silver Jet 8,502 8,503 6,431.5 6,432.3 A -2, 3N-11 7/16/1986 1.0 IPERF 120 deg. ph; 4" Jumbo Jet II 8,508 8,509 6,435.8 6,436.5 A -2, 3N-11 7/16/1986 1.0 IPERF 120 deg. ph; 4" Jumbo Jet II 505, 8,35] - 91. - 8,510 8,511 6,437.2 6,437.9 A -2, 3N-11 7/16/1986 1.0 IPERF 120 deg. ph; 4" Jumbo Jet 1) 8,523 8,524 6,446.5 6,447.2 A-2, 3N-11 7/16/1986 1.0 IPERF 120 deg. ph; 4" Jumbo Jet II APERF, 8,540 8,560 6,458.6 6,472.8 A -2, 3N-11 6/27/1996 4.0 RPERF 180 deg. ph; Odent( + / -) 90 deg F/ 8,4204,435 Lowside; 2 1/8" EJ 8,551 8,552 6,466.4 6,467.1 A -1, 3N-11 7/16/1986 1.0 IPERF 120 deg. ph; 4" Jumbo Jet II 8,557 8,558 6,470.6 6,471.4 A -1, 3N-11 7/16/1986 1.0 IPERF 120 deg. ph; 4" Jumbo Jet II APERF, 8,475 - 8,490 8,561 8,562 6,473.5 6,474.2 A -1, 3N-11 7/16/1986 1.0 IPERF 120 deg. ph; 4" Jumbo Jet II 8,565 8,589 6,476.3 6,493.4 A -1, 3N-11 7/16/1986 1.0 IPERF 120 deg. ph; 4" Jumbo Jet II Notes; General & Safety IPERF, - End Date Annotation 6502 -6503 APERF, - 11/28/2007 NOTE 1500 psi CSG to TUBING 8,498x,518 _ 1/15/2008 NOTE WAIVERED WELL- OA ATMOSPHERE COMMUNICATION IPERF, -_ 8,508x,509 IPERF, 8,510x,511 IPERF, 8,5238.524 RPERF, 8.5408.580 IPERF. 8,551-5552 IPERF, Mandrel Details 8,55743558 Top Depth Top Port (TVD) Intl OD Valve Latch Size TRO Run Stn Top (RKB) )RK8) ( ") Make Model (!n) Sery Type Type (!n) (psi) Run Date Corn... 1 8,089.9 6,139.9 45.17 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/28/2007 IPERF, 8,561-8,562 FISH, 8,571 IPERF, I 8,565-8,589 I • PRODUCTION, 30 -8.777 00, 8,780 0 0 CG--0-17 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. February 17, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 SCANNED APR ��� Anchorage, Alaska 99501 RE: Radial Cement Bond Log: 3N -11 Run Date: 2/16/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3N -11 1 CD Rom Data in LAS format, Digital Log Image files 50- 029 - 21580 -0 1 Color Log Cement Bond Log 50- 029 - 21580 -0 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 -352 Fax: 907 - 273 -353 klinton.wood @halliburton. Date: 1 Signed: ,> • LtG- 017 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. March 1, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Radial Cement Bond Log - Depth Shifted Redistribution: 3N -11 Run Date: 2/16/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3N -11 a Data in LAS format, Digital Log Image files 1 CD Rom 50-029-21580-00 Cement Bond Log 1 Color Log 50- 029 - 21580 -00 SCANNED PR 2 32 013 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com Date: q2—VN Si ned: 2. g ) 11 / 1 4 4:7 &A°4 1 • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION • WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended 0 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Service 0 Stratigraphic Test El 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: p _ c TIC ConocoPhillips Alaska, Inc. orAband.: January 14, 2012 186 - 077 / 311 - 372 ie rr -x Xe 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 April 5, 1986 50 029 - 21580 - 00 4a. Location of Well (Govemmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 1561' FSL, 155' FEL, Sec. 29, T13N, R9E, UM April 11, 1986 3N - 11 Top of Productive Horizon: 8. KB (ft above MSL): 68' RKB 15. Field /Pool(s): 1256' FSL, 938' FEL, Sec. 20, T13N, R9E, UM GL (ft above MSL): 36' AMSL Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): 1508' FSL, 1006' FEL, Sec. 20, T13N, R9E, UM 8682' MD / 6560' 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 518246 y 6013799 Zone 4 8790' MD / 6637' TVD ADL 25521, 25512 1 TPI: x - 517436 y - 6018772 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 517367 y - 6019024 Zone 4 SSSV @ 1797' MD / 1731' TVD 2553 18. Directional Survey: Yes ❑ No Q 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1700' MD / 1650' 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 pp licable 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 36' 115' 36' 115' 24" 250 sx CS II 9.625" 36# J -55 35' 4558' 35' 3632' 12.25" 1300 sx AS III, 350 sx Class G 7" 26# J -55 30' 8777' 30' 6627' 8.5" 300 sx Class G, 175 sx AS I 4.5" 11.6# L -80 8130' 8625' 6168' 6519' na 15 bbls 16ppg Class G w /GASBLOK 24. Open to production or injection? Yes ❑ No Ei 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" 8173' 8130' MD / 6169' TVD perfs cemented off: 8420' - 8589' MD 6374' - 649 YD RECEIVED 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED FEB 14 2012 C nmrn +ss •n 27. , . , Oil & Gds CofC. PRODUCTION ST Date First Production Method] 1 t rIFlowin• • - .) not applicable well suspended Date of Test Hours Tested Production for OIL -BBL GAS -MCF WATER -BBL CHOKE SIZE GAS -OIL RATIO Test Period - -> Flow Tubing Casing Pressure Calculated OIL -BBL GAS -MCF WATER -BBL OIL GRAVITY - API (corr) Press. psi 24 -Hour Rate -> 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No 0 Sidewall Cores Acquired? Yes ❑ No 0 If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. F E NONE ' M • FID .B 5,; g ' - RBDMS FEB 14 2012 e Form 10 -407 Revised 12/2009 CONTINUED ON REVERSE Submit original only 7 6_, z.„2,1_,L___ , e,,„, C 28. GEOLOGIC MARKERS (List all formations and markers ntered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes is 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' 1650' needed, and submit detailed test information per 20 AAC 25.071. not applicable N/A Formation at total depth: na 30. LIST OF ATTACHMENTS Summary of Daily Operations, schematic 31. I hereby best of my knowledge. Contact: J. Brett Packer 265 - 6845 certify that the foregoing is tru and correct to the bes © Y N 9 9 Y 9 Printed Name H. Gober Title: Wells Engineering Supervisor ---� / / Signature Phone 263 - 4220 Date l 13/ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10 -404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service wells: Gas injection, water injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level 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 , t KUP 3N -11 C onocoPhillips 0 $ We ell Attributes ax Angle & MD TD AI+AS#tfi. Inc . llbore API /UWI Field Name Well Status Inc! C) MD (ftKB) Act Btm (ftKB) 500292158000 KUPARUK RIVER UNIT PROD 49.88 2,400.00 8,790.0 `°" Comment fin (ppm) Date 'Annotation End Date KB - Ord (ft) Rig Release Date ... `°" SSSV: NIPPLE Last WO: 1/11/2012 39.49 4/13/1986 Well Conti, : - 3N-11, 1/312012 9:37:52 AM Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: RKB 8,5540 11/16/2011 Rev Reason: WORKOVER ninam 1/31/2012 HANGER, 24 -:3 Casing Strings Casing Description String 0... String ID ... Top ((KB) Set Depth (f... Set Depth (TVD)... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H WELDED Casing Description String 0... String ID ... Top (MB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd MIF SURFACE 95/8 8.765 35.0 4,558.0 3,631.6 36.00 J - 55 BTC Casing Description String 0... String ID ... Top (OKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.276 30.4 8,776.6 6,627.2 26.00 J - 55 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR, LINER 41/2 4.000 8,130.2 8,625.2 6,519.2 11.60 L -80 BTC 3&115 Liner Details Top Depth SAFETY VLV, 1 "" 1 (TVD) Top Inc! Noml,.. 1.797 Top (ftKB) (ftKB) (°) Item Description Comment ID (93) 8,130.2 6,168.5 45.36 PACKER BAKER C2 ZXP LINER TOP PACKER 4.960 MN 8,150.5 6,182.7 45.30 HANGER BAKER HYDRAULIC FLEXLOCK HANGER 4.900 GAS LIFT, 8,160.3 6,189.6 45.28 SBR BAKER 80-40 SEAL BORE EXTENSION 4.000 2.908 ;. Illi Tubing Strings Tubing Description String 0... String ID ... Top (ft(B) Set Depth (f... Set Depth (TVD) . String Wt... String ... String Top Thrd Tubing I 31/2 2.992 24.0 l 8,173.4 I 6,198.8 9.30 1 L -80 EUE8rdABMOD t Completion Details J L Top Depth SURFACE, (TVD) Top Inc! Noml... 351,558 Top (ftKB) (RKB) (1 Item Description Comment ID (in) 24.0 24.0 0.37 HANGER TUBING HANGER & PUP 3.500 GAS LIFT. 5,099 1,796.7 1,731.1 34.86 SAFETY VLV CAMCO TRMAXX -CMT SAFETY VALVE 2.812 M I 8,081.5 6,134.0 45.17 NIPPLE CAMCO X NIPPLE 2.812 8,128.5 6,167.3 45.36 LOCATOR LOCATOR SEALS 7 OUT 3.000 GAS LIFT, 8,136.81 6,173.1 45.34ISEAL ASSY (BAKER 80-40 SEAL ASSEMBLY FOR SBE HALF MULE SHOE 3,730 6,571 y Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) IMF Top Depth (ND) Top Inc! GAS LIFT, l Top (ftKB) (RKB) ( Description Comment Run Date ID (In) 7.524 - 8' 674 - 6;486 44.61 ISH 1" BK Latch Ring Lost in Hole, May be laying in one of 10/25/1987 .11 �}°?qQ f G J _37� Lower GLM Perforations &Slots GAS LIFT, Shot 8052 .s Top(ND) Blm(TVD) Dens Top (ftKB) Mai (ftKB) (M EI) (RKB) Zone Date (eh... Type Comment NIPPLE, 8,081 ilk, 8,435 6,373.6 6,384.2 UNIT D, C -4, 8/23/1999 4.0 APERF 0 deg phase/90 deg CW from UNIT B, 3N -11 lowside; 2 1/8" EJ NM 8,475 8,490 6,412.4 6,423.0 A -3, 3N -11 9/26/1987 8.0 APERF 60 deg. ph; 2 1/8" Silver Jet 8,498 8,518 6,428.7 6,442.9 A -2, 3N -11 9/26/1987 8.0 APERF 60 deg. ph; 2 1/8" Silver Jet 8, OR. LOCATOR, ' 8,502 8,503 6,431.5 6,432.3 A - 2, 3N - 11 7/16/1986 1.0 IPERF 120 deg. ph; 4" Jumbo Jet II r --. 8,508 8,509 6,435.8 6,436.5 A -2, 3N -11 7/16/1986 1.0 IPERF 120 deg. ph; 4" Jumbo Jet II SEAL ASSY, t 8,137 TS, ; � 8,510 8,511 6,437.2 6,437.9 A -2, 3N -11 7/16/1986 1.0 IPERF 120 deg. ph; 4" Jumbo Jet II 8,523 8,524 6,446.5 6,447.2 A -2, 3N -11 7/16/1986 1.0 IPERF 120 deg. ph; 4" Jumbo Jet II 44 8,540 8,560 6,458.6 6,472.8 A -2, 3N -11 6/27/1996 4.0 RPERF 180 d e . p h; Onent( + / -) 90 deg F/ ' ',J' 8,551 8,552 6,466.4 6,467.1 A -1, 3N -11 7/16/1986 1.0 IPERF 120 deg. ph; 4" Jumbo Jet II % 8,557 8,558 6,470.6 6,471.4 A -1, 3N -11 7/16/1986 1.0 IPERF 120 deg. ph; 4" Jumbo Jet II 8,4me au 8,561 8,562 6,473.5 6,474.2 A -1, 3N -11 7/16/1986 1.0 IPERF 120 deg. ph; 4" Jumbo Jet II % 8,565 8,589 6,476.3 6,493,4 A -1, 3N -11 7/16/1986 1.0 IPERF 120 deg. ph; 4" Jumbo Jet II APERF, Notes: General & Safety 8,475 -8,490 End Date Annotation 11/28/2007 NOTE: 1500 psi CSG to TUBING 1/15/2008 NOTE: WAIVERED WELL - OA x ATMOSPHERE COMMUNICATION IPERF, 8,502 -8,503 APERF. 8,498-8,518 _ IPERF, 8,5088,509 - - IPERF, 8,5108,511 IPERF, 8,523-8,524 ;:; 1 RPERF, 8,540 -8,560 -_ IPERF, 8,551 -8,552 IPERF, 8,557 -8,558 Mandrel Details Top Depth Top Port % J (ND) Inc! OD Valve Latch Size TRO Run IPERF. P (ftKB) 8,561$562 ', # Stn To (RKB) C) Make Model (in) Sew Type Type (in) (psi) Run Date Corn... 1 1 9 9 1 2,908.3 2,492.1 47.16 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 1/12/2012 !, 2 5,099.4 4,001.9 46.28 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 1/12/2012 FISH,�'it 3 6,571.1 5,056.2 42.97 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 1/12/2012 PERF, • 7/ ..- 8,585 4 7,524.1 5,741.5 45.23 CAMCO MMG 1 1/2 'GAS LIFT DMY RK 0.000' 0.0 1/12/2012 r - j 5 8,052.5 6,113.5 45.17 CAMCO MMG 11/2 GAS LIFT SOV DCK 0.000 0.0 1/12/2012 , LINER. M • • 8,130 -8,825 1 I PRODUCTION, 3aa,m TD, 8.790 I Foil ,t 3N -11 Pre -Rig Well Work DATE SUMMARY 12/25/11 MEASURED BHP @ 8504' RKB (01 psi max) , PULLED 1" DMY VLV @ 80 RKB, (( ASSIST SETTING BPV )). COMPLETE. 12/26/11 T -POT (PASSED), T -PPPOT (PASSED), IC -POT (PASSED), IC -PPPOT (PASSED), FUNCTIONED ALL LDS. • • Conoc cPhiIIips Time Log & Summary WeMew Web Reporting Report Well Name: 3N - 11 Rig Name: DOYON 141 Job Type: RECOMPLETION Rig Accept: 1/2/2012 3:00:00 AM Rig Release: 1/14/2012 12:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12/31/2011 24 hr Summary Rig released from 1 E -24B at 1400 HRS. Prep rig for move. Wait on Peak trucks. Trucks arrived at 2200 HRS. Break aprat rig modules. Load onto trucks. 14:00 22:00 8.00 MIRU MOVE MOB P Rig on standby, waiting on Peak trucks to move rig from 1 E pad to 3N pad. Prep rig for move. 22:00 00:00 2.00 MIRU MOVE MOB P Peak Trucks arrived. Break apart rig modules and load on to trucks. Begin move to 3N pad. 01/01/2012 Continue Move rig to #N Pad. Spot modules on the pad. Road back to 1E pad. Load sub base, and remaining modules. MOve over to 3N pad. Spot sub baase, and all modules, including the pipe sheds. Hook up power and all interconnects. Work on rif acceptance checklist. 00:00 12:00 12.00 MIRU MOVE MOB P Conitnue move rig modules form 1E pad to 3N pad. Spot Modules on the pad. Road trucks backl to 1E. Load subbase, rockwasher, and pipe sheds. Move same to 3N pad. Crew Change 12:00 00:00 12.00 MIRU MOVE MOB P Continue move subbase to 3N pad. Spot sub, power pack, and pipe sheds over well 3N -11. Set rockwasher. Hook up interconnects, steam, water, air etc. Trucks sent back to move rig camp. Get steam up and running through rig. Rebuild bad steam line valves. Work on rig acceptance checklist. Crew Change 01/02/2012 Continue work on rig acceptance checklist. Rig up slop tank and hardline. Rig accepted at 0300 HRS. Rig up lines in cellar to kill well. Wait on scaffold crew & rig up scaffold in cellar. Rig up lubricator, pull BPV. Pressure test lines to 2000 PSI. Displace well with 10.7 PPG LSND mud, taking returns to slop tank. Monitor well. Observed 175 PSI on Tbg & IA. Continue circulate building mud wt to 10. 9 PPG at 3 BPM - 600 PSI. Fluid loss46 BBLS for the day. 00:00 03:00 3.00 MIRU MOVE MOB P Continue rig up and work on rig acceptance checklist. Rig up hardlines, and slop tank to kill well. Set stairs, handrails and landings. Rig accepted at 0300 HRS as per CPAI checklist. Spot & set Rig camp, sewer plant & truck shop. 03:00 07:45 4.75 MIRU WELCTL RURD P Wait on scaffold crew to set scafold in cellar, 4.75 HRS. Set scaffold. Rig up lines in cellar to kill well. Take on 580 BBLS of 10.7 PPG LSND mud to pits. Pull FMC lubricator to rig floor. Page 1 of 17 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:45 09:00 1.25 MIRU WELCTL RURD P Rig up scaffolding in cellar around tree. Test mud pump & lines to 3000 PSI. 09:00 11:00 2.00 MIRU WHDBO PULD P Rig up lubricator. Test same to 1500 PSI. Attempt to pull BPV. First attempt failed. Second attempt successful. Rig down lubricator. 11:00 12:00 1.00 MIRU WHDBO RURD P Remove blank flange on tree. Install 1502 firring and flange on wing valve for circulation. Crew Change 12:00 13:15 1.25 MIRU WELCTL RURD P Held PJSM. Continue rig up for displacement. 13:15 17:00 3.75 MIRU WELCTL KLWL P Pressure test surface lines to 2000 PSI. Open up well. Pump down annulus as planned with 1000 PSI on the tbg, bleeding off through choke. Take returns to slop tank. Pump 10.7 PPG LSND mud around until observed mud back to surface. Pumps at 2 BPM - 800 PSI. Increase rate at 160 BBLS pumped to 3 BPM - 1000 PSI. Pumped a total of 400 BBLS. Mud returns weighed 10.4 PPG. 17:00 20:15 3.25 MIRU WELCTL KLWL P Pumps down. Shut in well - monitor pressures. IA & Tbg = 175 PSI. Blow down all lines to slop tank. Continue pumping taking returns to pits. Pumps at 3 BPM - 600 PSI with no losses. Stage pumps to 4 BPM - 825 PSI, observing losses of 10 BPH. SLow opumps to 3 BPM, until returns at 10.6 PPG. 20:15 20:45 0.50 MIRU WELCTL OWFF P Monitor well. Observed flow from annulus at 8 BPH steady. Shut and monitor pressures. TBG = 60 PSI, Annulus = 75 PSI. 20:45 00:00 3.25 MIRU WELCTLCIRC P Weight up mud pits to 10.9 PPG. Open well, pumping down tbg at 3 BPM - 600 PSI with 10.9 PPG mud. Crew Change Total fluid losses for the tour = 46 BBLS. X1/03/2012 Continue pump 10.9 PPG LSND mud around. Monitor well - one hour at the wellhead. Slight flow on tbg and annulus approximately 2 -3 BPH, and steady. Weight up mud pits to 11.1 PPG. Pump 11.1 PPG at 3 BPM 650 PSI. Monitor well. Well Dead. Set BPV. ND Tree. NU BOPE. Test BOPE. Witness of test by AOGCC rep - Matt Herrera BOP test 250 / 4000 PSI on chart. Perform Koomey test. Initial 200 PSI achieved in 25 Secs, full 3000 PSI in - 170 Secs. 5 Nitrogen bottles with an avg PSI of 2025. 00:00 00:15 0.25 MIRU WELCTLCIRC P Continue pump 10.9 PPG LSND mud around until 10.9 out. 00:15 01:15 1.00 MIRU WELCTL OWFF P Monitor well for one hour at the wellhead. Observed slight flow from the annulus and tbg. little or no pressure, but flow not stopping. Page 2 of 17 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:15 04:00 2.75 MIRU WELCTL CIRC P Weight up mud pits to 11.1 PPG. Pump 11.1 PPG LSND mud around until good 11.1 PPG back to surface at 3 BPM - 650 PSI. Shut down pumps. 04:00 06:30 2.50 MIRU WELCTL OWFF P Monitor well at the wellhead for flow. Observed annulus dead - no flow. Tbg with pencil sized flow, slowing to less than 1 BPH. Suspect wellbore fluid slightly out of balance. Allow tbg to flow, minimal flow, didn't stop. 06:30 07:15 0.75 MIRU WELCTL CIRC P Reverse down IA up tubing 3 BPM @ 575 PSI. Pump 72 BBL total. 07:15 10:00 2.75 MIRU WELCTL OWFF P Monitor well at the wellhead for flow. Observed IA with slight flow. Flowed slowed then stopped. Gained 2 BBLS back. Well dead and in balance. 10:00 10:30 0.50 MIRU WHDBO MPSP P Install BPV w/ Dry rod 10:30 10:45 0.25 MIRU WELCTL RURD P RD circulating lines. 10:45 11:00 0.25 MIRU WHDBO SFTY P Held PJSM with crew and FMC rep. Discuss safety & hazard recognition issues. Discuss procedure to nipple down the tree. 11:00 12:00 1.00 MIRU WHDBO NUND P Install tree lift cap. Nipple down tree as per FMC rep. Obtain correct orientation. CRew Change 12:00 13:00 1.00 MIRU WHDBO NUND P Continue nipple down tree. Inspect threads on hanger. Install blanking plug. 13:00 13:15 0.25 MIRU WHDBO SFTY P Held PJSM with crew. Discuss safety & hazard recognition issues. Discuss procedure to nipple up BOP's. 13:15 15:00 1.75 MIRU WHDBO NUND P Nipple up BOP stack and adapter flange. Make up choke & kill lines. 15:00 17:00 2.00 MIRU WHDBO BOPE P Rig up BOP test equipment. Make up floor safety valves for testing. 17:00 22:45 5.75 MIRU WHDBO BOPE P Test BOP's. Test choke manifold and all valves. Test manual & HCR choke and kill line valves. Test all rams. 1,P Test to 250 / 4000 PSI, record on f chart. Test annular to to 250 / 3500 PSI. TEst with 3.5" and 4" test jnts. <tt Witness of test by AOGCC rep Matt Herrera. Perform Koomey test. Observed first 200 PSI gained in 25 secs. Full 3000 PSI gained in 170 secs. 5 Nitrogen bottles with an avg PSI of 2025. 22:45 00:00 1.25 MIRU WHDBO RURD P Rig down test equipment. Blow down lines. Blow down choke and line up same. Rig up to pull blanking plug with 3 1/2" test joint. Crew Change Page 3 of 17 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01/04/2012 24 hr Summary Pull blanking plug. Verify no pressure. Pull BPV. RU power tongs and equipment. Make up landing joint with 3 1/2" EUE pups. RIH screw into hanger. BOLDS. Pull hanger to rig floor and circ. two BU. Balance well and begin POH. Well swabbing due to heavy mud. Thin mud w/ DESCO and continue to POH. Will swap to CaCI brine on next trip in with DP. 00:00 01:30 1.50 MIRU WHDBO PULD P Continue pull blanking plug. Suck out BOP stack. RU and verify no pressure under BPV. Pull BPV. Blow down all lines. Change out elevators. 01:30 03:00 1.50 COMPZ RPCOM RURD P Pull power tongs to floor. Rig up tongs, and prep to pull tbg. Make up 3 1/2" EUE landing joint consisting of pups. RIH screw into hanger. Make up floor valve assembly. Screw into top drive. 03:00 04:45 1.75 COMPZ RPCOM PULD P BOLDS as per FMC rep. observed trouble backing out LDS. 04:45 05:00 0.25 COMPZ RPCOM PULD P Pull tbq hanger to rig floor. Observed UP WT = 85K. Fill hole. Monitor well - static. 05:00 06:00 1.00 COMPZ RPCOM PULD P Breakout & lay down floor valve assembly, landing joint, and hanger with pup. RU to circulate. 06:00 08:00 2.00 COMPZ RPCOM CIRC P Reverse circulate two tubing volumes @3 BPM at 575 PSI. 08:00 08:30 0.50 COMPZ RPCOM CIRC P Monitor well. Well out of balance. RU and circulate long way @ 3 BPM at 500 PSI. Increase to 4 BPM at 750 PSI. 08:30 09:00 0.50 COMPZ RPCOM CIRC P Pump slug, monitor well. Well static. 09:00 10:30 1.50 COMPZ RPCOM TRIP P POOH with 10 Jts of 3 -1/2" tubing with no displacement. 10:30 12:00 1.50 COMPZ RPCOM TRIP P Monitor well. Well is static. Pull up 20' and verify swabbing. Discuss with town engineer. Plan is to displace well to 11.2 CaCI brine. 12:00 13:00 1.00 COMPZ RPCOM CIRC P Thin mud with DESCO to enable trip out of hole with tubing. Mud properties still ok to suspend barite. 13:00 14:00 1.00 COMPZ RPCOM CIRC P Reverse circulate to Condition mud. t� 14:00 00:00 10.00 COMPZ RPCOM TRIP P Begin to POOH with 3 -1/2" completion. Monitor hole fill closely on trip tank. Hole taking proper fill. X1/05/2012 Continue POOH lay down tbg. RU & test annular and upper rams with 2 7/8" test joint. Test to 250 / 4000 PSI. Make up Fishing BHA #1, TIH with 4" DP in single from shed. Tag & engage upper packer assembly at 8135' DPM. Pull packer free. Circulate bottoms up with 11.1 PPG Mud. Displace well with 11.0 PPG Brine. Observed mud packing off at packer. Drop dart - open Pump out sub. Work string to free up packer and allow elements to relax. Monitor well. Continue circulate at full rates. 00:00 02:30 2.50 COMPZ RPCOM PULD P Continue POOH, lay down 3 1/2" tbg. Laid down a total of 257 jnts, 3 pups, one GLM, and seal assembly. 02:30 03:00 0.50 COMPZ RPCOM RURD P Clean & clear rig floor area. Send tools out. Prep for next run. Check strap on DP in shed. 03:00 04:00 1.00 COMPZ RPCOM SVRG P Service rig, Top drive. Page 4 of 17 • Time Logs Date From To Dur S, Depth E. Depth Phase Code Subcode T Comment 04:00 05:00 1.00 COMPZ RPCOM BOPE P Install test plug with 2 7/8" test joint. test upper rams, and anunlar. test to 250 / 4000 PSI, and 3500 on the annular. record on chart. 05:00 05:15 0.25 COMPZ RPCOM SFTY P Held PJSM with crew & BOT rep. Discuss safety & hazard recognition issues. Discuss procedure to make up fishing BHA #1. 05:15 09:30 4.25 0 586 COMPZ RPCOM PULD P Make up Fishing BHA #1. Total length = 586.3' 09:30 16:30 7.00 586 8,140 COMPZ RPCOM TRIP P RIH with Spear assembly on 4" drillpipe, single in hole. 16:30 17:30 1.00 8,140 8,140 COMPZ RPCOM FISH P Wash down last two stands to top of fish. Engage and PU @ 8140' DPM. Release FHL packer with 40K straight pull. Jars not required. 17:30 20:00 2.50 8,140 8,050 COMPZ RPCOM CIRC P Pull one stand and prep to circulate. Observed slight flow. Shut upper pipe rams and open choke for precautionary operational circulation. Circulate bottom's up with mud. Check for flow. Well slightly out of balance. Open pipe rams. 20:00 20:30 0.50 8,050 8,050 COMPZ RPCOM CIRC P Pump down drillpipe with 5 BBL H2O followed by 11.+ PPG CaCI brine. 20:30 21:00 0.50 8,050 8,050 COMPZ RPCOM CIRC P At 110 BBL pumped, started loosing returns. Lost a total of 60 BBLS. SD pumps and discuss plan with town. Dropped ball to open pump -out sub. 21:00 22:30 1.50 8,050 8,050 COMPZ RPCOM CIRC P Started pumping down tubing to move ball down hole and immediately regained full rate & returns. Packer elements had relaxed allowing circulation. Continue circulating mud out with 11.0+ brine. Shut down pumps after 1900 Strokes. Observed free movement in string up, down. 22:30 22:45 0.25 8,050 8,050 COMPZ RPCOM OWFF P Monitor well - Slight flow. Mud wt in / out 11.0 PPG. 22:45 00:00 1.25 8,050 8,050 COMPZ RPCOM CIRC P Continue circulate bottoms up monitoring well for losses. Pumps at 3 BPM - 475 PSI, then to 5 BPM - 800 PSI. Crew Change 01/06/2012 Monitor well - Observed flow on annulus and DP. Circulate bottoms up at 5 BPM - 800 PSI. Monitor well. Slight flow. 11.0 PPG in /out. Circulate to increase brine weight to 11.2 PPG in the system. 00:00 00:30 0.50 8,050 8,050 COMPZ RPCOM OWFF P Monitor well. Slight flow on annulus. 0 PSI on DP. 00:30 01:00 0.50 8,050 8,050 COMPZ RPCOM CIRC P Circulate bottoms up at 5 BPM - 800 PSI. Fluid loss with pumps on 4 -5 BBLS. 01:00 01:30 0.50 8,050 8,050 COMPZ RPCOM OWFF P Monitor well. Mud weight In /Out = 11.0 PPG. Observed slight flow on annulus and drill pipe. Closed in no pressure, just slight and steady flow. Page 6 of 17 0 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:30 03:15 1.75 8,050 8,050 COMPZ RPCOM CIRC P Circulate while bringing brine system up to 11.2 PPG. Pumps at 4 BPM - 550 PSI. 03:15 04:00 0.75 8,050 7,915 COMPZ RPCOM OWFF P Monitor well. Slowly pull one stand and rack back same. UP WT = 145K. Observed well flowing from DP. Static on annulus. Suspect out of balance or breathing ? 04:00 04:30 0.50 7,915 7,915 COMPZ RPCOM CIRC P Circulate one DP volume @ 5 BPM - 800 PSI. 04:30 05:00 0.50 7,915 7,915 COMPZ RPCOM OWFF P Monitor well. Observed flow from DP. Annulus slight flow, and then static. Steady flow on DP, not slowing. Decision to increase brine weight by two tenths. Consider issues of pulling packer, brine weight, swabbing etc.. 05:00 06:45 1.75 7,915 7,915 COMPZ RPCOM CIRC P Circulate at 4 BPM - 550 PSI increasing brine weight to 11.3 PPG. 06:45 07:30 0.75 7,915 7,915 COMPZ RPCOM OWFF P Monitor well - static. Blow down Top drive & lines. Held PJSM. 07:30 11:30 4.00 7,915 586 COMPZ RPCOM TRIP P POOH from 7915'. Observed proper displacement. 11:30 13:30 2.00 586 0 COMPZ RPCOM PULD P LD Fishing BHA and FHL packer. Total length of fish recovered = 103.64' 13:30 14:15 0.75 0 0 COMPZ RPCOM SVRG P Rig service. 14:15 15:45 1.50 0 586 COMPZ RPCOM PULD P PJSM. PU BHA #2, Baker overshot for retrieving 2 -7/8" completion. Total length of BHA #2 = 586'. 15:45 21:45 6.00 586 8,235 COMPZ RPCOM TRIP P TIH with BHA #2 on 4" drillpipe to top of fish at 8235'. Observed proper displacement. 21:45 22:30 0.75 8,235 8,235 COMPZ RPCOM FISH P Obtain parameters. Pumps at 3 BPM -300 PSI. UP WT= 145K,SOWT= 100K. Tag & engage fish. First catch unsucessful, repeat procedure to observed catch, and overpull to 160K. Pulled free. Retag fish top observing seals reenter the HB packer. Pull out observed seals pulling free.Pull above HB packer top. 22:30 23:30 1.00 8,235 8,235 COMPZ RPCOM CIRC P Circulate bottoms up at 5 BPM - 825 PSI. No gas. 23:30 23:45 0.25 8,235 8,195 COMPZ RPCOM OWFF P Rack back one stand while monitor well. Observed fluid slightly falling in stack. 23:45 00:00 0.25 8,195 7,723 COMPZ RPCOM TRIP P Trip out of hole with 4" DP and BHA #2. Observed proper displacement. Crew Change 31/07/2012 Continue POOH with 4" DP & BHA #2 from 7723' - 586'. Breakout & lay down Fish. Service rig and Top Drive. Make up Fishing BHA #3, Spear assembly. TIH on 4" DP to 8260' and engage fish. Jar on fish with no success. Released spear, circ BU and POOH. Page 6 of 17 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 02:45 2.75 7,723 586 COMPZ RPCOM TRIP P Continue trip out of hole with 4" DP and BHA #2. Observed proper displacement. Monitor well at the BHA. 02:45 03:00 0.25 586 586 COMPZ RPCOM OWFF P Monitor well at the BHA. Static. 03:00 04:00 1.00 586 0 COMPZ RPCOM PULD P POOH, rack back HWDP & DC's. Breakout & lay down overshot assembly & fish. Fish recovered = 2 7/8" - 1/2 jnt, pup, and seal assembly. Total length = 40.98' Observed OD of seals assembly = 3 9/16" 04:00 04:30 0.50 0 0 COMPZ RPCOM PULD P Clean & clear rig floor. Pull tools to floor. Held PJSM with crew. Making up BHA #3. 04:30 05:00 0.50 0 COMPZ RPCOM SVRG P Service rig, Blocks and Top drive. 05:00 06:45 1.75 COMPZ RPCOM PULD P Make up BHA #3 spear per Baker Rep. 06:45 10:45 4.00 COMPZ RPCOM TRIP P RIH with BHA #3 on 4" drillpipe to 8195'. 10:45 12:15 1.50 COMPZ RPCOM FISH P MU topdrive and establish parameters at 4 BPM @ 900 PSI and full returns. PU = 145K, S0= 96K. Wash down to 8260' MD and set down with 10K. Observed 200 PSI incr. PU and rotate 3 turns to left then set down 20K. Depth with 20K down wt is 8262' MD. Lost 10 BBL fluid. 12:15 14:30 2.25 COMPZ RPCOM FISH P Shut down pump and engage fish. PU w/ 80K over and confirm. Jar on fish up to 155K over. Jarred 65 times. Made 4' total. 14:30 15:15 0.75 COMPZ RPCOM JAR P Break circulation at 3 BPM @ 750 PSI and jar 20 times. No movement. 15:15 16:15 1.00 COMPZ RPCOM SVRG P Perform derrick inspection as required. 16:15 17:15 1.00 COMPZ RPCOM JAR P Continued to jar 100 to 155K over. No success. Jars fired 115 times total. 17:15 18:15 1.00 COMPZ RPCOM FISH P Released spear and PU 10'. Observed oil at surface. Circ BU at 4 BPM @ 900 PSI. Brine wt. 11.2+ in and out. 18:15 18:30 0.25 COMPZ RPCOM OWFF P SD pump and monitor well. Static. 18:30 23:00 4.50 COMPZ RPCOM TRIP P POOH with spear assembly from 8192'. 23:00 00:00 1.00 COMPZ RPCOM PULD P LD BHA #3 01/08/2012 Slip & Cut Drilling Line. Make up BHA #4, Rattler tool assembly with Spear, and TIH with 4" DP to top of fish @ 8256' DPM. Fill every 10 stands. Engage Fish. Pumps at 2 BPM, moving fish up hole until free. Open circ sub. POOH. Breakouy & lay down BHA & Fish. Recovered HB Packer assembly and tail pipe. Total length = 87.41'. Prepare for Clean out run assembly. Page 7 of 17 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:00 1.00 COMPZ RPCOM SLPC P Held PJSM. Rig up and slip and cut drilling line. Inspect Top Drive & draw works. 01:00 03:30 2.50 0 614 COMPZ RPCOM PULD P Clean & clear rig floor. Make up Fishing BHA #4, rattler tool with spear assembly. Total length of BHA = 614.56 ". 03:30 07:30 4.00 614 8,252 COMPZ RPCOM TRIP P Trip in hole with BHA #4. Fill every 10 stands. 07:30 09:15 1.75 8,252 8,091 COMPZ RPCOM FISH P Obtain parameters. UP WT - 145K, SO WT - 100K. Tag & engage top of fish at 8252' DPM. Verify catch with overpull to 225K. Stage pumps form 1 BPM - 2 BPM to engage Rattler tool, observing fish moving up hole until free. Observed 2 -4 K Down drag, and 5K drag pulling. Packer free. 09:15 10:45 1.50 8,091 8,091 COMPZ RPCOM CIRC P Drop ball & rod to open circulation sub. Opened at 2100 PSI. Continue CBU at 4 BPM - 1375 PSI. 10:45 11:15 0.50 8,091 8,091 COMPZ RPCOM OWFF P Monitor well, while rack back stand, blow down top drive & lines. Static. 11:15 12:00 0.75 8,091 7,940 COMPZ RPCOM TRIP P Trip out of holw with fish from 8129' - 7940' DPM. Observed proper displacement. Crew Change 12:00 15:45 3.75 7,940 4,800 COMPZ RPCOM TRIP P Continue trip out of hole from 7940' - 4800' DPM. Observed displacement 2 BBLS behind. 15:45 16:15 0.50 4,800 4,800 COMPZ RPCOM OWFF P Monitor well - Observed pencil sized flow on annulus. Brine weight = 11.3 PPG. 16:15 18:15 2.00 4,800 4,800 COMPZ RPCOM CIRC P Continue monitor well, and circulate surface to surface to balance well. Monitor well - static. 18:15 21:15 3.00 4,800 614 COMPZ RPCOM TRIP P Continue POOH with BHA #4 and fish. Observed proper displacement. 21:15 22:45 1.50 614 0 COMPZ RPCOM PULD P Rack back DC's and HWDP. Breakout & lay down fish. Fish recovered = 87.41' 22:45 23:15 0.50 0 0 COMPZ RPCOM PULD P Clean & clear rig floor. Send tools out. 23:15 00:00 0.75 0 572 COMPZ WELLPF PULD P Make up BHA #5, Clean out assembly with 6 1/8" bit. Total length = 572.22'. Crew Change 01/09/2012 Held PJSM. TIH with BHA #5- Clean out run assembly. Tag @ 8504' DPM. Clean out washing down to 8682' DPM. Circulate hole clean, and balance brine weight while reciprocate & rotate drill string. Observed sand across shakers. POH and PU BHA #6 - Clean out run assembly w/ scrapers. TIH and tag 1' high. Clean out to 8682' DPM. Circulate hole clean and balance brine wt. POH with BHA #6. 00:00 02:00 2.00 572 8,504 COMPZ WELLPF TRIP P Held PJSM. Trip in hole with 4" DP, and BHA #5- cleanout assembly. Observed proper displacement. 02:00 03:30 1.50 8,504 8,682 COMPZ WELLPF WASH P Tag up at 8504'. Wash down with pumps at 6 BPM - 1200 PSI, cleane out to 8682' DPM. RPM's- 60, with 5K TQ. Page 8 of 17 • . Time Logs Date From To Dur S. Deoth E. Depth Phase Code Subcode T Comment 03:30 06:00 2.50 8,682 8,682 COMPZ WELLPFCIRC P Circulate hole clean with pumps at 6.5 BPM - 1300 PSI. reciprocate & rotate drill string. Observed increased amounts of sand across shakers. Continue circulate until hole cleaned up, and brine weight balanced at 11.3 PPG. 06:00 06:30 0.50 8,682 8,682 COMPZ WELLPF OWFF P Monitor Well. Static. 06:30 10:00 3.50 8,682 572 COMPZ WELLPF TRIP P POH from 8652 to 572' MD. 10:00 11:00 1.00 572 0 COMPZ WELLPF OWFF P Monitor well at HWDP. Static. Rack back HWDP and collars. LD BHA #5. 11:00 12:00 1.00 0 0 COMPZ WELLPF PULD P Clean and clear rig floor. PJSM for BHA #6, 2nd clean -out run 12:00 13:00 1.00 0 572 COMPZ WELLPF PULD P PU BHA #6. 13:00 15:30 2.50 572 8,682 COMPZ WELLPF TRIP P RIH to 8681' and tag fill. Clean out 1' fill to 8682'. 15:30 16:30 1.00 8,682 8,686 COMPZ WELLPFCIRC P Circulate BU and clean up hole. 16:30 16:45 0.25 8,686 8,686 COMPZ WELLPF OWFF P Monitior well. Still slight flow. Well out of balance 16:45 18:15 1.50 8,686 8,686 COMPZ WELLPFCIRC P Circulate to condition mud, and balance system. 18:15 19:00 0.75 8,686 8,686 COMPZ WELLPF OWFF P Monitor well. 19:00 19:30 0.50 8,686 8,150 COMPZ WELLPF TRIP P Pump five stands out of hole. Observed proper displacement. 19:30 19:45 0.25 8,150 8,150 COMPZ WELLPF OWFF P Monitor well - static. 19:45 22:15 2.50 8,150 556 COMPZ WELLPF TRIP P Continue POOH on eleavtors from 8150' to BHA. Observed proper displacement. 22:15 00:00 1.75 556 0 COMPZ WELLPF PULD P Breakout & lay down BHA. Lay down DC's and HWDP. Inspect bit. Crew Change 01/10/2012 Finish laying down BHA #6. Clean & clear rig floor. Rig up and test BOP's w/ 4" test joint. Witness of test waived by AOGCC rep Matt Herrera. MU mule shoe, RIH tp 8420', CBU, pump 80 bbl pill of 11.7 ppg brine, spot at the bottom of hole, POOH to 8368', let well balance out, POOH 2 stands to 8175', monitor well- static, POOH 5 stands to 7705', monitor well- static, POOH, pull wear bushing, RU, test w/ 4.5" test joint to 250 psi low and 4000 psi high f/ top and bottom pipe rams, test annular to 250 psi low and 3500 psi high, charted tests, held each test 5 minutes. 00:00 00:30 0.50 0 0 COMPZ WELLPF PULD P Finish laying down BHA #6. 00:30 01:15 0.75 0 0 COMPZ WELLPF PULD P Clean & clear rig floor area. Send all fishing tools out. Prep for BOP test. 01:15 01:30 0.25 0 0 COMPZ WELLPFSFTY P Held PJSM with crew. Discuss safety & hazard recognition issues. Discuss procedure to rig up and test BOPE. 01:30 03:00 1.50 0 0 COMPZ WHDBO RURD P Drain stack. Pull wear bushing. Install test plug with 4" test joint. Rig up test equipment. Page 9 of 11 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:00 05:00 2.00 0 0 COMPZ WHDBO BOPE P Observed fluid coming out of annulus, pulled test plug to inspect test plug seals. C/O seals on test plug. Set test plug and filled stack. Observed fluid coming out of the wellbore. Monitor wellbore. 20 mins, filled a 5 gallon bucket. Continued to monitor the well during the BOPE test. 05:00 09:30 4.50 0 0 COMPZ WHDBO BOPE P Test BOPE. AOGCC waived witness. (Matt Herrera). Test all equipment to 250 PSI low, 4000 PSI high, 5 mins, charted. Test#1= Top pipe rams, C.M. valves, 1,12,13,14 and HCR / Kill. Test#2= Manual Kill, C.M. valves { 5,8,10. Test#3= Upper IBOP, C.M. ( 25 valves 5,8,10, Test#4= Lower IBOP, C.M. valves 4,6,7, Test#5= Floor valve, C.M. valve 2, Test#6= HCR choke, 4" kill line Demco valve, Test#7= Manual choke valve & HCR kill, Test#8= Annular preventer to 250 PSI low, 3500 PSI high for 5 mins. Test #9= Lower variable pipe rams. Test#10= Blind rams, C.M.valve 3. Accumulator test / System pressure 3000 PSI, pressure after closed = 1700 PSI. 200 PSI attained =44 secs. Full pressure attained =192 secs. 5 bottle average= 1900 PSI. 09:30 10:00 0.50 0 0 COMPZ WHDBO BOPE P Rig down test equipment. Blow down choke and kill line, pull test plug and set wear ring. SIMOPS: Monitoring wellbore. Final strap and time to fill a 5 gallon bucket, 17 mins 39 secs. 10:00 12:00 2.00 0 3,000 COMPZ WELLPF TRIP T Make up mule shoe to stand of 4" DP. RIH to 3000' MD. Calculated fill =16.2 BBLS. Actual fill= 16.3 BBLS. 12:00 13:30 1.50 3,000 8,368 COMPZ WELLPFTRIP T Continue to trip in the hole with the mule shoe to place 11.7 PPG 70 barrel pill on bottom. 13:30 15:00 1.50 8,368 8,420 COMPZ WELLPF CIRC T Make up stand #90 to top drive. P/U Wt= 140k. S/O Wt= 95k. Run in hole to 8420' MD. Top of perfs. Break circulation @ 5 BPM. 750 PSI, 38% flow. CBU with 11.3 PPG brine. Pump 80 BBL pill of 11.7 PPG brine and spot on bottom with 70 BBLS of 11.3 PPG brine. 15:00 15:45 0.75 8,420 8,368 COMPZ WELLPF CIRC T Shut down pump, rack back one stand ( #90). Observe well to be out of balance. Rig up with floor valve to allow wellbore to U -tube. Monitor well. slight flow from DP. 15:45 16:00 0.25 8,368 8,175 COMPZ WELLPF OWFF T Pull 2 stands from 8368' to 8175'. Observe well. Fluid level dropped in well. PagelO • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:00 16:15 0.25 8,175 8,175 COMPZ WELLPFOWFF T Observe well. Static. 16:15 16:30 0.25 8,175 7,705 COMPZ WELLPF TRIP T Pull 5 stands from 8175' to 7705'. Good hole fill. Calculated = 2.7 BBLS. Actual = 3.0 BBLS 16:30 16:45 0.25 7,705 7,705 COMPZ WELLPF OWFF T Observe well for flow. Static. 16:45 20:00 3.25 7,705 0 COMPZ WELLPFTRIP T Finish trip out of the hole f/ 7705'. Trip calculated fill 48.6 bbls, actual 50.2 bbls. 20:00 20:15 0.25 0 0 COMPZ WELLPF OTHR P Pull FMC 6.5" ID wear bushing. 20:15 21:45 1.50 0 0 COMPZ WHDBO RURD P Rig up testing equipment and 4.5" test joint. Fix test joint so hole in joint was not above lower pipe rams. Sim Ops: Rigging up 4.5" handling tools f/ liner run. 21:45 22:15 0.50 0 0 COMPZ WHDBO RURD P MU 4.5" test joint and FMC test plug. Seat test plug, fill hole w/ water. 22:15 00:00 1.75 0 0 COMPZ WHDBO BOPE P Test lower pipe rams (2 -7/8" x 5" VBR's) and upper pipe rams (3 -1/2" x 6" VBR's) to 250 psi low and 4000 psi high. Test annular to 250 psi low and 3500 psi high. Hold each test f/ 5 minutes. Chart tests. 01/11/2012 Run 4 Liner. Rig up Halliburton E -Line for correlation. Adjust DP depth to WL depth for Coil sidetrack. +4.89'. Place liner on depth, shoe depth 8625.18', circulate and condition mud, PJSM, cement liner. 00:00 01:00 1.00 0 0 COMPZ WHDBO BOPE P PJSM. Rig down test equipment. Install wear ring, mobilize XO's, and tools to rig floor. Pick up cement head and make up XO and sub. Lay back down. 01:00 01:30 0.50 0 0 PROD1 RPCOM SFTY P PJSM on running 4 %" 11.6 ppf, L -80 Liner. 01:30 03:00 1.50 0 183 PROD1 RPCOM PUTB P Pick up shoe and float track. Baker locked to pin of jt # 4 on tally. Installed bow spring centralizers floating on joints # 1,2 and #3. No centralizers on x -o BTC to IBT liner joint and jt #4. 03:00 03:15 0.25 183 183 PROD1 RPCOM PUTB P Test float equipment @ 183'. Pumping 37 spm w/ 148 psi. Good. 03:15 04:00 0.75 183 464 PROD1 RPCOM PUTB P Continue to pick up 41/2" L -80 11.6# BTC Liner as per Baker Rep f/ jt # 4 to jt #10, then MU SBE to 464'. 04:00 04:30 0.50 464 464 PROD1 RPCOM RURD P Change elevators f/ 4 -1/2" to 3 -1/2 ", slips to 5 ", rig up 5 -1/2" tongs. 04:30 05:00 0.50 183 507 PROD1 RPCOM PUTB P Make up 2 -3/8" pups and liner wiper plug, make up Baker Flex lock hanger and "C2" ZXP liner top packer. 05:00 05:30 0.50 507 600 PROD1 RPCOM RUNL P Rig down casing tongs, make up XO to hanger(4" XT39 b x 3 -1/2" IF pin), change elevators and run a stand of 4" drill pipe to 600'. Page 11of17 1 r Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:30 05:45 0.25 600 600 PROD1 RPCOM CIRC P Circulate liner volume @ 5 BPM w/ 220 PSI @ 600'. Circ 25 bbls. P/U Wt =38k, S/O Wt =40k. 05:45 06:00 0.25 600 600 PROD1 RPCOM OTHR P Blow down top drive. 06:00 12:00 6.00 600 6,702 PROD1 RPCOM RUNL P Trip in the hole with 4" XT39 Drill Pipe from 600' to 6702' MD. Filling pipe every 5 stands. Obtaining up and down weights every 10 stands. Drop 2.375" rabbit starting from stand #67. Actual displacement =38.35 BBLS, Calculated displacement =37.02 BBLS. 12:00 14:00 2.00 6,702 8,652 PROD1 RPCOM RUNL P Continue to trip in the hole with the 4W Liner on 4" DP. From 6702' to 8647' MD. Fill every 5 stands. Trip to 8652' and pick up 5 feet to 8647' to put the string in tension, set slips. L/D single from stand #87. Actual displacement= 48.5 BBLS, Calculated displacement = 48.4 BBLS 14:00 14:30 0.50 8,652 8,647 PROD1 RPCOM SFTY P PJSM with Halliburton E -Line crew and rig crew. Electric line operations, and rig up. Hazard analysis. 14:30 16:30 2.00 8,647 8,647 PROD1 RPCOM ELOG P Pick up and rig up Halliburton E -Line equipment. Make up floor valve and XO's to stump, make up Hal. BOP stack, riser, grease head and CCL & GR tools. 16:30 16:45 0.25 8,647 8,647 PROD1 RPCOM ELOG P Pressure test E -Line BOPE and grease head against floor valve to 1000 PSI for 5 mins with test pump. Check for leaks. Good. 16:45 17:30 0.75 8,647 8,647 PROD1 RPCOM ELOG P Conduct wireline logging operations. CCL /GR @ 200 FPM. Correlate to original SLB CET log 4/22/86. 17:30 17:45 0.25 8,647 8,647 PROD1 RPCOM ELOG P On bottom with CCL /GR tools. Log up @ 50 FPM. Correlate to original gamma ray log. 17:45 19:15 1.50 8,647 8,647 PROD1 RPCOM ELOG P POOH w/ Halliburton e-line. 19:15 20:45 1.50 8,647 8,647 PROD1 RPCOM RURD P Rig down Halliburton equipment. 20:45 21:30 0.75 8,647 8,625 PROD1 CEMEN PULD P After corrolation (need to move pipe up hole 27.53' to put collar of x -o joint top @ 8485' WLM, shoe @ 8625.18' WLM, Shoe is @ 8620.29' dpm: a correction of 4.89'). Pick up, lay down a single, make up 5' pup joint and then the Baker cement head. Sim ops: Move Halliburton a -line unit, spot Dowell cementing equipment. Page 12 of 17 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code. Subcode T Comment 21:30 23:15 1.75 8,625 8,625 PROD1 CEMEN" CIRC P Break circulation pumping 4.5 bpm w/ 900 psi. Circulate out the 11.7 ppg 80bbI pill in the hole. Sim Ops: Pre job safety meeting on cementing. 23:15 00:00 0.75 8,625 8,625 PROD1 CEMEN' CMNT P Dowell pump 5 bbls of 13 ppg mudPush @ 2.9 to 4.3 bpm w/ 380 psi. Shut down. Pressure test lines to 4000 psi -good. Dowell pump an t " additional 10 bbls of mud push @ 5 bpm w/ 800 psi (Total of 15 bbls of 13 ppg mudPush. Follow w/ 15 bbls of 16 ppg class "G" cement w/ (1t, GASBLOK, pumping 5bpm w/ 860 to 713 psi. Note: pumped 16 bbls w/ 15 bbls to the rig floor. Shut down, close TIW valve, flush lines to the mud pits until clean (5 bbls pumped). Line up valves to pump. Drop wiper plug, Dowell kick out plug pumping 11.3 ppg CACL. Cowell pumping 5 bpm, caught pressure after pumping 8 bbls. Pumping 5 bpm w/ 680 psi initial, slowed down to 3 bpm w/ 500 psi after displacing 82 bbls. Continue pumping 3 bpm. Saw latch up of liner wiper plug after pumping 86.7 bbls (increase of pressure to 1061 psi). Continued displacement, bumped plug after pumping another 6 bbls. Increased pressure to 3500 psi when plug bumped. Full returns for job. Bumped plug @ 0004 hrs 1/12/2012. Did not reciprocate pipe. 01/12/2012 Pump 15 barrels of cement. Displace. Latch plug @ 87.7 BBLS. Bump plug @ 93.6 BBLS. Set liner top packer. WOC 5%2 hrs. Test liner top. Displace 11.3 PPG out with 8.6 PPG seawater. POOH UD DP. Slip and cut 280 feet of drill line. Test 31/2" Test joint. Page 13of17 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 00:30 0.50 8,625 8,625 PROD1 CEMEN" PACK P Baker slacked off to 32k to confirm liner hanger was set, Dowell bled off the 3500 psi pressure and checked floats- good. Pick up to 170k (30k over pull), slack off to 85k, rotate 20 rounds to the right w/ 4k ft lbs of torque to release running tool from liner hanger. Rig pressure string up to 1000 psi, pick up and observe pressure fall off, once that occured, increased pumps and moved 25 bbls of fluid up hole pumping 67 spm w/ 1350 psi. PU wt 132k. Slow pumps to .5 bpm, slack off and observe shear @ 75k, continued to slack off to 55k. shut down pumps. Blow down and remove cement hose. Pick up, then rotate 15 rpm while coming down, set dog sub on liner top- set down to 75k to insure liner top packer was set. Increase pump rate to 8 bpm w/ 1650 psi, slowly pull out of hanger assembly w/ 2 -3/8" EUE stinger. 00:30 01:30 1.00 8,625 8,127 PROD1 CEMEN" CIRC P While 3' above liner top, circulate two bottoms up pumping 8 bpm w/ 1650 psi. Observed mud push at the shakers confirmed, circulated 15 bbls of 13 ppg mudPush out of the hole, followed by 4.3 bbls of 15.8 ppg cement. 01:30 07:00 5.50 8,127 8,117 PROD1 CEMEN - WOC P Waiting on cement to achieve 500 psi compresive strength (Will wait till 0700 hrs 1/12/2012). SIM Ops: Break and lay down cement head w/ 2 joints of 4" drill pipe from hole. Lay down 3 joints of 4" drill pipe from the hole. Lay down 5 stands of 4" drill pipe from the derrick, leaving 1 stand to run back in the hole with. Break pup joints and crossover's from cement head. Clean up under shakers and trough. Pick up 1 stand f/ derrick and run back in the hole to 8117'. Rig up to test 7" and 4 -1/2" liner. 07:00 07:45 0.75 8,117 8,117 PROD1 CEMEN" PRTS P Test 7" and 4 -1/2" liner to 250 psi low, then test to 3000 psi high f/ 30 minutes- chart test. 07:45 08:15 0.50 8,117 8,117 COMPZ WELLPF RURD P Rig down testing equipment. Rig up to circulate and displace f/ 11.3 ppg CACL to 8.6 ppg seawater. 08:15 09:15 1.00 8,117 8,117 COMPZ WELLPFCIRC P PJSM. Circulate 8.6 ppg seawater to displace 11.3 ppg brine @ 7 BPM. ICP =1800 PSI. 36% flow. FCP =1000 PSI. Total volume pumped 331 barrels. Total barrels returned 331 barrels. Page 14of17 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:15 09:45 0.50 8,117 8,117 COMPZ WELLPF DHEQ P Perform negative pressure test on well for 30 mins. Charted. Good. 09:45 10:00 0.25 8,117 8,117 COMPZ WELLPF RURD P Rig down test equipment. Blow down lines. 10:00 10:15 0.25 8,117 8,117 COMPZ WELLPFSFTY P PJSM. Laying down drill pipe coming out of the hole. 4" XT39. 10:15 12:00 1.75 8,117 6,416 COMPZ WELLPF TRIP P Trip out of the hole. Laying down singles. 54 jts. 12:00 17:45 5.75 6,416 0 COMPZ WELLPF TRIP P Continue to trip out of the hole laying down singles. UD liner running tools. 17:45 18:45 1.00 0 0 COMPZ WELLPF RURD P Drain stack. Make up stack washer and single joint of drill pipe to top drive, run in hole to casing head and circulate @ 10 BPM. while rotating. Pick up and wash stack slowly. Blow down top drive. 18:45 19:00 0.25 0 0 COMPZ WELLPF SFTY P PJSM. Slip and cut drill line. 19:00 20:30 1.50 0 0 COMPZ WELLPF SLPC P Slip and cut drill line. 280 feet due to bad spot in line. 20:30 21:30 1.00 0 0 COMPZ WHDBO MPSP P Check crown - 0 - matic, drain stack, pull wear bushing, set test plug with 3'/" test joint. 21:30 22:15 0.75 0 0 COMPZ WHDBO OTHR P Open lower and upper pipe ram doors. Inspect for cement debris. The rams and cavities were clean. SIMOPS: clean pits. 22:15 23:00 0.75 0 0 COMPZ WHDBO RURD P Rig up test equipment. Clear rig floor of un- needed tools and equipment. Pick up 3%2' handling equipment and spooling unit for CAMCO control line. 23:00 00:00 1.00 0 0 COMPZ WHDBO BOPE P Test Lower VBR's. 2 7/8" x 5 ". 250 PSI low. 4000 PSI high. 5 mins each, charted. Test Upper VBR's. 3 x 6" . 250 PSI low. 4000 PSI high. 5 mins each, charted. With 3%" test joint. 01/13/2012 Test with 3 test joint. BOPE test. Rig up and run 3'/" 9.3# L -80 EUE Mod production string with GLM's. . Land out, space out. Displace well with corrosion inhibited brine. Shear out GLM @ 8052' MD. PT SSSV. ND BOP. 00:00 00:15 0.25 0 0 COMPZ WHDBO BOPE P PJSM. Test annular preventer to 250 PSI /3500 PSI. 5 mins. charted. 00:15 00:30 0.25 0 0 COMPZ WHDBO RURD P Rig down test equipment. Drain stack. 00:30 01:00 0.50 0 0 COMPZ RPCOM SVRG P Service top drive and Drawworks. 01:00 01:30 0.50 0 0 COMPZ RPCOM RURD P Make up safety valve, rig up tubing equipment. 01:30 01:45 0.25 0 0 COMPZ RPCOM SFTY P PJSM on running 3 completion string. 01:45 07:30 5.75 0 6,355 COMPZ RPCOM RCST P Run 3 9.3# L -80 tubing. Seal assembly, X nipple & 5 GLM's to 6355' MD. 07:30 08:15 0.75 6,355 6,355 COMPZ RPCOM RCST P Rig up and pick up Camco TRMAXX, CMT,SSSV. Test control line. Page 15of17 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:15 10:45 2.50 6,355 8,126 COMPZ RPCOM RCST P Continue to trip in the hole with tubing from 6355' MD to 8126' MD. Tag liner top @ 8126' MD. Actual fill =26.5 BBLs, Calculated fill =26.63 BBLs. 10:45 12:00 1.25 8,126 8,155 COMPZ RPCOM RCST P Make up cement line. Break circulation @ 2 BPM. 100 PSI. P/U Wt =95k. S/O Wt =72k. Tag up on liner top. Could not go down. P/U turn 3/4 turn to the right. Work string. Went into liner top. RIH to 8155' MD. 12:00 12:30 0.50 8,155 8,174 COMPZ RPCOM RCST P Sting into seal assembly while pumping 20 SPM, 100 PSI. Saw pressure increase @ 8156' MD. Locate seals. shut down pumps, bled off pressure. RIH to 8174' MD. Fully located. Set down 15k. P/U to neutral weight. Pressure test seals to 500 PSI. Good. L/D 3 joints in preparation for space out. 12:30 13:00 0.50 8,174 8,152 COMPZ RPCOM RCST P Pick up three pup joints. 8.14', 8.16', 4.09'. Total 20.39'. P/U joint #256. Make up hanger and landing joint. Rig up to pump. 13:00 13:30 0.50 8,152 8,152 COMPZ RPCOM RCST P Bleed off control line, cut control line, feed through hanger and secure with swage fittings, pressure up control line and open SSSV. 61 stainless steel bands used on the run. 13:30 13:45 0.25 8,152 8,152 COMPZ RPCOM SFTY P PJSM on displacement. 13:45 15:00 1.25 8,152 8,152 COMPZ RPCOM CIRC P Displace out 8.6 PPG brine with 8.6 PPG corrosion inhibited brine. 210 BBLS, chase with 75 barrels of clean seawater. @ 4BPM. 375 PSI 15:00 16:30 1.50 8,152 8,173 COMPZ RPCOM PRTS P Blow down choke, kill lines, and hole fill. Pressure test tubing to 3000 PSI for 15 mins.Charted. Good. 16:30 17:45 1.25 8,173 8,173 COMPZ RPCOM PRTS P Bleed down tubing pressure to 1500 PSI. Pressure up annulus to 3000 PSI for 30 mins. Charted. Good. Bleed ann. to zero.Pressure back up annulus to 3000 PSI to shear out DCR /SOV @ 8052' MD. Did not shear. Shut in annulus with 3000 PSI. Bleed off tubing to zero. Valve sheared @ 2500 PSI differential. Positive bleed down to zero on both sides. Bleed off control line to close SSSV. Test SSSV to 1000 PSI for 5 mins. Charted. Good. 17:45 18:45 1.00 8,173 8,173 COMPZ WHDBO RURD P Rig down lines, lay down landing joint. Set BPV on dry rod. Clear rig floor, control line reel, tool box for CAMCO. 18:45 19:00 0.25 8,173 8,173 COMPZ WHDBO SFTY P PJSM changing out rams. 19:00 20:30 1.50 8,173 8,173 COMPZ WHDBO EQRP P Change out lower rams from 2 7/8" x 5" to the 5" solid body rams. Page 16of17 • • Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 20:30 22:15 1.75 8,173 8,173 COMPZ WHDBO RURD P Nipple down BOPE, rack back stack. 22:15 22:45 0.50 8,173 8,173 COMPZ WHDBO RURD P Lay down spacer spool. Prepare production tree. 22:45 00:00 1.25 8,173 8,173 COMPZ WHDBOOTHR P Clean and prepare well head to receive new production tree. Rig up new tree. J1/14/2012 Nipple up new FMC Gen 3 RetroFit Production tree. Test tree to 250 PSI low, 5000 PSI high. Charted. Good. Test SSSV line to 6000 PSI. Diesel freeze protect, 75 barrels down the annulus. Allow to U -tube. Install BPV. Secure well. Prepare to RDMO. Waiting on Weather. Rig release 12:00 Hrs. 00:00 02:30 2.50 0 0 COMPZ WHDBO SEQP P PJSM. Nipple up adapter flange, nipple up tree, test adapter flange to 250 PSI low, 10 mins, 5000 PSI high 15 mins. Charted. 02:30 02:45 0.25 0 0 COMPZ WHDBO SEQP P Pull BPV, install tree test plug. 02:45 03:30 0.75 0 0 COMPZ WHDBO SEQP P Fill tree with diesel from day tank. Rig up to test tree. 03:30 04:30 1.00 0 0 COMPZ WHDBO PRTS P Pressure test tree. 250 PSI low, 5000 PSI high. 5 mins. Charted. Good. 04:30 05:00 0.50 0 0 COMPZ WHDBO SSSV P Open SSSV. Test line to 6000 PSI. 15 mins. Good. SIMOPS: PJSM with Little Red. Prepare to pump diesel freeze protect down the annulus taking returns up the tubing and into the rockwasher. 75 barrel job. 05:00 06:15 1.25 0 0 COMPZ WHDBO FRZP P Reverse circulate. Diesel freeze protect with Little Red Services. 1 BPM. 75 barrels. 200 PSI. 06:15 07:30 1.25 0 0 COMPZ WHDBO FRZP P Pumping job complete. Rig up and allow wellbore to U -Tube and reach balance. SIMOPS: Clean pits, shakers, drip pan, rig down Little Red. 07:30 07:45 0.25 0 0 COMPZ WHDBO RURD P Blow down all high pressure lines in the cellar. 07:45 08:45 1.00 0 0 COMPZ WHDBO MPSP P Install BPV. Remove low torque valves on tree, replace with blanking flange and pressure gauge. SIMOPS: Blow down and break down mud pumps for rig move. Clean pits. 08:45 12:00 3.25 0 0 DEMOB MOVE RURD P PJSM: Change out saver sub to 4'W' IF for Sharks Tooth. Empty pits of last 100 BBLS of brine on board. Clean pits. Rockwasher. Remove choke line. Change hydraulic and gear box filters on top drive. Rig Release Noon. Page 17 of 17 2\ AS WELL LOG TRANSMITTAL Alaska Oil and Gas Conservation Comm. January 12, 2012 To: Attn. Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 SCANNED APR 2 3 2013 RE: Correlation Log: 3N -11 Run Date: 1/11/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3N -11 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 21580 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -352 Fax: 907 - 273 -353 klinton.wood @halliburton Signed: / .11 -■•■■■■4- /i‘ Date: 1 • • 11 [F ALAsIA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Brett Packer Wells Engineer ConocoPhillips Alaska, Inc. 2 3 f o l t7 P.O. Box 100360 Anchorage, AK 99510 1 v v Re: Kuparuk River Field, Kuparuk River Oil Pool, 3N -11 Sundry Number: 311 -372 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. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair DATED this itiO day of December, 2011. Encl. • • Co nocoPhillips Alaska RECEIVED P.O. BOX 100360 [)E 0 J 2011 ANCHORAGE, ALASKA 99510 -0360 Alaska Oil & Gas Cons. Co as ' ncnorage November 30, 2011 Commissioner Dan Seamount State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7 Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner Seamount: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Injector 3N -11 (PTD 186 -077). 3N -11 was originally completed in July 1986 as a single A & C sand pre - produced injector. It was pre - produced for just over a year before it was permanently converted to injection. This well has been a water - only injector, averaging just over 1800 bwpd over the life of the well. The well was worked over in 2007 to replace the tubing. We did not attempt to pull the tubing at that time, instead, the tubing was cut and a poor -boy overshot and stack packer were installed. This well is located in an area which has experienced a lower than expected oil recovery as a result of several factors including: multiple baffling and sealing faults, low injection throughput, insufficient offlake points, and unswept areas across the faults. This well is part of a producer- injector pair that are being redeveloped to target three new fault blocks identified based on the latest 3D seismic survey and corresponding large pressure differentials across the faults. The purpose of this workover is to pull the entire 3 ' /z" x 2 7 /g" completion, install a 4 'h" scab liner across the Kuparuk inside the 7" casing, and re- complete with 3 %" tubing in order to set the well up for CTD in the Summer of 2012. The current SBHP as of 11/16/11 measures —4260 psi at the mid -perf depth, equivalent to 12.7 ppg EMW. The well is currently being back -flowed in an attempt to de- pressure the reservoir as much as possible prior to the workover and subsequent CTD. Another SBHP will be obtained just prior to the workover to calculate the necessary KWF, regardless, drilling mud is planned to be used. If you have any questions or require any further information, please contact me at 265 -6845. Sincerel , J. Brett Packer Wells Engineer CPAI Drilling and Wells TAT OF ALASK / ECEIVED .. ALASKA OIL AN S ONSE RVATION COMMISSION ` 4 �(' 0 f 2P APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 � � 1. Type of Request: Abandon r Rug for Redrill Perforate New Pool r Repair well Change Apprpve ogr *S SW Suspend Rug Perforations r Perforate r Pull Tubing '1 e r Operational Shutdown r Re -enter Susp. Well r Stimulate r Alter casing . Other: r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 186 -077 • 3. Address: Stratigraphic r Service I✓" • 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 21580 - 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 r No pr 3N -11 ` 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25521, 25512^ Kuparuk River Field / Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8790 • 6637 • 8571' Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 115' 115' SURFACE 4523 9.625 4558' 3632' PRODUCTION 8746 7 8777' 6627' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8420' - 8589' 6374' - 6493' 3.5 J - 55 8245 Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft) PACKER - BAKER FHL PACKER MD= 8158 TVD= 6188 PACKER - BROWN 'HB' PACKER MD= 8287 TVD= 6279 SSSV - 'DS' NIPPLE MD= 531 TVD= 531 12. Attachments: Description Summary of Proposal 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory Development $ Service d� 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 12/26/2011 Oil r Gas f WDSPL r Suspended 17 • 16. Verbal Approval: Date: WINJ r GINJ F"" WAG r Abandoned Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Brett Packer @ 265 -6845 Printed Name Brett Packer Title: Wells Engineer �i Signature , — �`�– ` Phone: Date ///3 a // Commission Use Only Sundry Number: 3 1 t - ""1 2 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity f BOP Test /Mechanical Integrity Test r Location Clearance r Other: y 600 r 5:,. o e les t - 2 S2) A r✓S L. /4vin 4".-t- �31L C am},) F4 /a« v,...v# 401.../o, torod42 AAC_ ZS 4 1i2— , 4112 CO Subsequent Form Require(: /o _ / / � i APPROVED BY f 211 I t Approved b ► D ate: COMMISSIONER THE COMMISSION m Form 10 -403 Revise S DEC 19 (L•14- Submit in Duplicate / /Wit fr • • 3N -11 Rig Workover, CTD Setup (PTD #: 186 -077) Current Status: Kuparuk well 3N -11 is an A/C sand single injector. The well is currently being back -flowed in an ./ attempt to de- pressure the reservoir as much as possible prior to the workover and subsequent CTD. Scope of Work: Pull the entire 3 '/" x 2 7 /8" completion, install a 4 ''/2 ' scab liner across the Kuparuk inside the 7" casing, and re- complete with 3 %2" tubing in order to set the well up for CTD in the Summer of 2012. / L---� s / 2,4. 7 f,_ Cs aso General Well info: MASP: • 3,617 psi Reservoir pressure/TVD: 4,260 psi / 6,433' TVD (12.7 ppg) as measured on 11/16/11. Wellhead type /pressure rating: FMC Gen 3, 7- 1/16" 5K psi top x 11" 3K btm Doyon 141 BOP configuration: Annular / Pipe Rams / Blind Rams / Mud Cross / Pipe Rams MIT results: MIT - passed on 2/9/10. Well Type: Injector Estimated Start Date: Dec. 26, 2011 Production Engineers: Jeremy Mardambek / Len Janson Workover Engineer: Brett Packer (265 -6845 / j. brett.packer @conocophillips.com) Pre - Rig Work: 1. RU Slickline: a. RIH w/ dual Panex gauges and obtain 30 min. mid A -sand SBHP at 8,532' RKB, PUH to 8,428' RKB and obtain 30 min. mid C -sand SBHP (for gradient calculation). b. Pull 1" DV at 8,090' RKB, leave pocket open. c. Lock out SSSV @ 1807' MD. 2. PT tubing & IA packoffs, FT LDS's. 3. Set BPV. Proposed Procedure: 1. MIRU. 2. Pull BPV, circulate —13.1 ppg drilling mud around until 13.1 ppg mud returns at surface. Bullhead an additional 15 bbls to the formation. SI and monitor well for 30 min. Record SITP & SICP, verify well is dead. 3. Set BPV & FMC blanking plug. ND tree, NU & test BOPE. —'+ f 0°°P R4 s -f - 4. Pull blanking plug & BPV. Circulate bottoms up. 5. MU landing joint, BOLDS, and attempt to pull tubing from the PBR. If tubing pulls free, POOH laying down 3 ''/2" EUE tbg and skip to Step #6, otherwise: a. RU E -line: RIH w/ 160 grain string shot, fire string shot centered at 8,123' RKB, POOH. RIH w/ the RCT and cut the tubing at 8,123' RKB (middle of the full joint above the PBR). POOH. RD E -line. b. POOH laying down 3 ' /2" EUE tbg. c. MU overshot and single in on 4" XT -39 drillpipe, latch onto tubing and jar seal assembly from the PBR. POOH standing back drillpipe, lay down fish. 6. MU PBR retrieving tool and RIH on 4" XT -39 drillpipe, latch onto upper PBR and jar `FH ' }aacke . free. POOH standing back drillpipe, lay down fish. 7. RBIH w/ overshot dressed for 2'/8" tubing, latch onto tubing stub and jar seal assembly from the lower PBR. POOH standing back drillpipe, lay down fish. rtie Q .) r/A well 6 rho- f t (44 he ied.://P) to ® I Con Cv/ ► 5X k 6CIA ,1'O/ 1 fr 1 ffcaf /7M t � � ,+ 0k Uh -r J te `f4 r S V 00 ( ' % / P OPt 7�e / • • 8. RBIH w/ PBR retrieving tool, latch onto lower PBR and straight pull the Brown `I-1B' packer free. If packer does not come free w/ straight pull, the packer can be released with right hand rotation. POOH standing back drillpipe, lay down fish. c S 1 hto, 9. MU & RIH w/ 7" casing scraper assembly, cleanout to PBTD. POOH standing back drillpipe. e T7 77 10. MU 4' /2" scab liner assembly and RIH to —8,690' RKB, RU SLB cementers, cement liner in lace, set line hanger and ZXP packer. POOH laying down drillpipe. G4 V " - • ( fj 11. MU & RIH w/ the new 3 ' /2" gas lift completion w/ SCSSSV. 12. Locate SBE, space out 7' off bottom, pull up just above SBE and swap out drilling mud with diesel. - 13. Space out w/ pups and MU tubing hanger, feed control line through hanger and secure w/ swage -lock fittings, G land hanger. RILDS. 14. PT the tubing to 3,000 psi, bleed tbg to 2500 psi, PT the IA to 3500 psi for 30 min and record on chart recorder. Bleed the IA to zero, then the tubing to zero. Ramp up the IA pressure quickly to shear the SOV. Function test the SCSSSV and pressure test from below. 15. Pull landing joint, set two -way check, NDBOP. 16. NU and test tree. Pull two -way check, set BPV. 17. RDMO. Post - Rig Work: 1. Pull BPV. 2. Pull SOV and install DV. 3. Turn well over to operations. • • sipe- Conloco P'hiIhps Well: 3N -11 2011 RWO Proposed Completion (CTD Setup) 16' 62# H-40 to 115' MD 9 -5/8" 36# J -55 to 4558' MD — �,� un Sr: 3 - 1/2" Gas Lift Completion "� 3 -1/2" 9.3# L-80 EUE 8rd Tubing to surface. ��n 6 B y 'f 3 -1/2" TRMAXX -CMT SSSSV @ - 1800' TVD 3 -1/2" Camco MMG gas lift mandrels @ TBD � q 2.813" Landing Nipple w/ 'X' profile @XXXX' MD o r V 15 � Baker GBH -22 seal assy. @ XXXX' MD (3" ,,,,,,,,,,,,, 4 - 1/2 " Scab Liner Baker 4 -1/2" x 7" ZXP liner top pkr @ 8,320' MD Baker 4 -1/2" x 7" HMC liner hanger @ XXXX' MD Baker 80 -40 SBE (12' length with 4" ID seal bore) 4 -1/2" 11 6# L - 80 BTC Casing to 8,690' MD C sand perfs 8420' - 8435' MD y _ A -3 sand perfs 8475' - 8490' MD — A -2 sand perfs 8498' -8560' MD - - - A -1 sand perfs 8551 - 8589 MD - — �._ F 4 -1/2" L-80 BTC shoe @ -8690' MD 7" J -55 BTC shoe at 8776' MD —■111111/11 il11111■11.-_ a •P 3N -11 ConocoPhillips ti Well Attributes Max Angle & TD Wel!bore API /UWI Field Name Well Status Intl 0 MD (ttKB) Act Btm (ftKB) j Alaska, Inc. 50 0292158000 KUPARUK RIVER UNIT INJ 49.88 2,400.00 8,790.0 ""' Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date "' SSSV: NIPPLE Last WO: 11/16/2007 39.49 4/13/1986 Well Conn, - 3N -11, 11/212010 8 59: 26 AM - --- Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod By End Date Last Tag: SLM 8,552.0 10/12/2010 Rev Reason: TAG Imosbor 11/2/2010 HANGER, 0 ..sise "" Casing Strings MIK Casing Description String 0... String ID ... Top (ttKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H WELDED Casing Description String 0... String ID ... Top (ttKB) Set Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd SURFACE 95/8 8.765 35.0 4,558.0 3,631.6 36.00 J - 55 BTC Casing Description String 0... String ID ... Top (ttKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.151 30.4 8,776.6 6,627.2 26.00 J -55 BTC Tubing Strings Tubing Description String 0... String ID ... Top (ttKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... Strin Top Thrd TUBING 3 1/2 I 2 ( 0 I 8 I 6 ' 9 I L -80 I E UE 8RD CONDUCTOR, Completion Details 36-115 Top Depth (TVD) Top Inc! Nomi... NIPPLE, 531 Olt Top (ttKB) (ttKB) (") Item Description Comment ID (!n) 0.0 0.0 0.38 HANGER FMC Tubing HANGER w /pupjt 2.992 531.2 531.2 0.68 NIPPLE 2.812 "DS' Nipple (2.856" lock) 2.812 8,144.6 6,178.5 45.32 PBR Baker PBR seal assembly (pinned 40M #)w /1' Space Out 2.992 SURFACE, A i 8,158.2 6,188.1 45.28 PACKER Baker FHL Packer (pinned 60M# shear) 3.030 35.4,556 8,200.2 6,217.7 45.08 NIPPLE 2.75 "'D' Nipple 2.750 8,238.8 6,244.9 45.01 XO Reducing 2 -7/8" pin x 3-1/2" box L-80 EUE 8RD crossover 2.480 GAS LIFT, 8,240.3 6,246.0 45.01 OVERSHOT Tubing Stub Overshot + 1' space out 3.000 8,090 c Tubing Description String 0... String ID ... Top (ttKB) Set Depth (f... Set Depth (TVD) ... String Sting ... String Top Thrd TUBING Original 27/8 2.441 8,234.5 8,358.3 I 6 6 j r... - 55 EUESrd Completion Details Top Depth (WD) Top Inc! Nomi... PBR. 8.145 Top (ttKB) (ftKB) ( ") Item Description Comment ID (in) PACKER, R158 -- - 8,270.0 6,267.0 44.95 PBR BROWN PBR 2.460 8,286.7 6,278.8 44.92 PACKER BROWN 'HB' PACKER 3.000 al ii, 8,324.7 6,305.7 44.86 NIPPLE CAMCO'D' NO GO NIPPLE 2.250 8,357.4 6,328.9 44.80 SOS SHEAROUTSUB 2.441 NIPPLE, 8,200 Other In Hole ireline retrievable plugs, valves, pumps, fish, etc.) - Top Depth \\ (WD) Top Intl Top (ftKg) (ftKB) ( ^) Description Comment Run Date ID (in) xo Rea 8,571.0 6,480.6 44.61 FISH 1" BK Latch Ring Lost in Hole; May belaying in one of 10/25/1987 Reducing, Lower GLM 9,239 OVERSHOT. 8,240 Perforations & Slots Shot - Top (TVD) Btm (TVD) Dens Top (ftKB) Btm (ttKB) (ftKB) (ftKB) Zone Date (sh... Type Comment P8R, 8,270 8,420.0 8,435.0 6,373.6 6,384.2 UNIT D, C-4, 8/23/1999 4.0 APERF 0 deg phase/90 deg CW from PACKER, 8,287 - �s r - - ° UNIT B, 3N -11 lowside; 2 1/8" EJ 8,475.0 8,490.0 6,412.4 6,423.0 A -3, 3N -11 9/26/1987 8.0 APERF 60 deg. ph; 21/8" Silver Jet NIPPLE, 8,325 8,498.0 8,518.0 6,428.7 6,442.9 A -2, 3N -11 9/26/1987 8.0 APERF 60 deg. ph; 2 1/8" Silver Jet U 8,502.0 8,503.0 6,431.5 6,432.3 A -2, 3N -11 7/16/1986 1.0 IPERF 120 deg. ph; 4" Jumbo Jet II 8,508.0 8,509.0 6,435.8 6,436.5 A -2, 3N -11 7/16/1986 1.0 IPERF 120 deg. ph; 4" Jumbo Jet II SOS. 8,357 8,510.0 8,511.0 6,437.2 6,437.9 A -2, 3N -11 7/16/1986 1.0 IPERF 120 deg. ph; 4" Jumbo Jet II 8,523.0 8,524.0 6,446.5 6,447.2 A -2, 3N -11 7/16/1986 1.0 IPERF 120 deg. ph; 4" Jumbo Jet II APERF, _ , .. 8,540.0 8,560.0 6,458.6 6,472.8 A -2, 3N -11 6/27/1996 4.0 RPERF 180 deg. ph; Orient( + / -) 90 deg F/ 6,420 _ - Lowside; 2 1/8" EJ 8,551.0 8,552.0 6,466.4 6,467.1 A -1, 3N -11 7/16/1986 1.0 IPERF 120 deg. ph; 4" Jumbo Jet II 8,557.0 8,558.0 6,470.6 6,471.4 A -1, 3N -11 7/16/1986 1.0 IPERF 120 deg. ph; 4" Jumbo Jet II APERF, 8,475 - 8,561.0 8,562.0 6,473.5 6,474.2 A -1, 3N -11 7/16/1986 1.0 IPERF 120 deg. ph; 4" Jumbo Jet II 8,565.0 8,589.0 6,476.3 6,493.4 A -1, 3N -11 7/16/1986 1.0 IPERF 120 deg. ph; 4" Jumbo Jet II • Notes: General & Safety IPERF, - End Date Annotation 8.502 - 8,503 _ 11/28/2007 NOTE: 1500 psi CSG to TUBING APERF. 6,49&9518 IPERF, 1/15/2008 NOTE: WAIVERED WELL - OA x ATMOSPHERE COMMUNICATION - 8,508 -8,509 IPERF, _ 8,510-8,511 - IPERF, 8,523-8,524 RPERF, 8,540-8,560 IPERF, 8.551 -8,552 IPERF, Mandrel Details 8,557 -8,558 Top Depth Top Port (TVD) Inc! OD Valve Latch Size TRO Run Stn Top (ttKB) (ftKB) (°) Make Model (in) Sery Type Type (,n) (psi) Run Date Com... 1 8,089.9 6,139.9 45.17 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/28/2007 See IPERF, 8,561 -8, Note FISH, 8,571 IPERF, 8,565 -8,589 0 PRODUCTION, 30-8,777 TD, 8,790 Page 1 of 2 • • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, December 16, 2011 11:19 AM To: 'Packer, J.Bret Subject: RE: 3N -11 (PTD 186 -077) Brett, Thanks for the responses. I agree with you on the first question as it was pertaining to testing the casing if you were moving packer below the old setting depths and was included to in case there was damage due to fishing... I will include the application for waiver of packer depth (280' from top perf) on the sundry as you request below. Regard, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Packer, J.Brett [mailto:J. Brett .Packer @conocophillips.com] Sent: Friday, December 16, 2011 10:48 AM To: Schwartz, Guy L (DOA) Subject: RE: 3N -11 (PTD 186 -077) Guy, Please see my responses below and let me know if you have any other questions. Thanks, J. Brett 2'ac4gr DiilEng eZ Wells Worlgver Engineer Work# (907) 265 -6845 CeI # (907) 230 -8377 From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov] Sent: Tuesday, December 06, 2011 3:37 PM To: Packer, J.Brett Subject: [EXTERNAL]3N -11 (PTD 186 -077) Brett, Followup to the phone call here is what I saw needing addressing in the sundry application. 1. No mention of testing the casing after running the casing scraper on step 9. It is not our standard procedure to test the casing in the middle of the RWO unless there is reason to suspect that the casing is bad. It is only on the West Sak single casing wells that we include a casing pressure test in the middle of the RWO, but that is only because those are packerless ESP wells, and the only time you can test the casing is during a RWO with a test packer. 3N -11 on the other hand has a packer and passed an 12/16/2011 Page 2 of 2 • • MIT -IA on 2/9/10 as indicated in the Sundry Well Info submitted, so we know our 7" casing has pressure integrity down to the top packer, therefore, I don't feel there is a need to re -test the casing it in the middle of the workover, especially since it will be tested once again after the completion is run as shown in Step #14 of the Sundry Procedure. I swapped the order of your comments below... 3. Possibility of moving the packer uphole (with waiver) to put the old packer depths behind scab liner . I appreciate your suggestion and would like to apply for a waiver to set the packer at 8,140' RKB which is 18 feet above the current FHL stack packer and 280 ft above the top perforations. Attached is a scanned copy of the zone of interest on the original cement bond log, and according to our SLB log analysts, they believe we've got pretty good cement coverage up to -8,040' RKB. 2. need cement volume and scab liner details. .. no mention of testing the scab liner and liner top packer. The scab liner will be 4 -1/2" BTC R3 casing. Given approval of the 8,140' RKB setting depth, the liner length will be 550 feet from 8,140' - 8,690', with an annular volume of 10.23 bbls. Total volume cement to pump will be 20 bbls of 15.7 ppg Class 'G', which is almost 100% excess to guarantee a good cement job behind the liner. The scab liner and the liner top packer will be tested in Step #14 of the procedure submitted in the sundry. 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I I[v: 1- . ., ro,.7f.'g.: l • 3. v A. .VII .:: • "�: - ; j:. h _S -fn 'W' a >,s :i !tai L . 4 +J+ e e ''• yl s , . „ u N f - Ir ., . , .... v.. 1. .., , . I . .. a1�r: r:3.i I ..tip' • . ,. Via. v, .,I,- „ . -� .. a. .� • X _ ' • • Page l of � r Subject: FW: INTENT PLUG for RE -DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monday, February 08, 2010 10:52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE -DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE -DRILL WELLS (IPBRD) Type Work Code in RBDMS 1. When a Form 10 -403 is submitted requesting approval to plug a well for redrill, the initial reviewer (Art or Steve D.) will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 form is checked. If the "Abandon" box is checked, we will cross that erroneous entry out and initial it orr, both copies of the Form 10 -403 (AOGCC's and operator's copies). 2. On the Form 10 -403 if "Abandon" is checked in Box 15 (Well Status after proposed work), Art or Steve J D. will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). Instead, we will check the "Suspended" box. Guy and Winton will serve as quality control for steps 1 and 2. 3. When Steve McMains receives the Form 10 -403 with a check in the "Plug for Redrill" box, he will enter the existing code "IBPRD" into RBDMS. This code automatically generates a comment under the History tab stating "Intent: Plug for Redrill." 4. When Steve McMains receives any Form 10 -407, he will check the History tab in RBDMS for this comment. If he sees the "Intent: Plug for Redrill" code, and cannot find any evidence that a subsequent re -drill has been COMPLETED, he will assign a status of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10 -407. Steve will also change the status on the 10 -407 form to SUSPENDED, and will date and initial his change. If Steve does not see the "Intent: Plug for Redrill" comment or code, he will enter the status listed on the Form 10 -407 into RBDMS. 5. When the Form 10 -407 for the redrill is received, Steve M. will change the original well's status from suspended to abandoned. 6. The first week of every January and July, Steve M. and Steve D. will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, Steve M. and Steve D. will also review the list of suspended wells for accuracy. Thanks, Steve D. file: //F: \Daily_ Document_ Record \Procedures_Instructions \FW INTENT PLUG for RE -D... 12/2/201 '. • • Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, December 02, 2011 9:28 AM To: 'NSK Problem Well Supv' Subject: RE: Seeking AA guidance for 3N -11 (PTD 186 -077, AIO 2B.024) and 3N -13 (PTD 186 -081, AIO 2B.038) 12 -01 -11 Kelly, If 3N -11 will be sidetracked /redrilled (becoming 3N -11A) then 3N -11 will cease to exist and the AA can be cancelled. If no injection is planned prior to the plugging, then you can request that the AA be cancelled. Tom From: NSK Problem Well Supv [mailto:n1617©conocophillips.com] Sent: Friday, December 02, 2011 9:08 AM To: Maunder, Thomas E (DOA) Subject: RE: Seeking AA guidance for 3N -11 (PTD 186 -077, AIO 2B.024) and 3N -13 (PTD 186 -081, AIO 2B.038) 12 -01 -11 Tom, Just so I'm clear- you mentioned that unless something physically changes, the AA will continue to apply. Since 3N -11 will be sidetracked, that sounds like a physical change to me. So that one will need a cancellation and a reapply? Thanks a ton Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907) 659 -7224 + e , : ; }! ` , 3 , I, Pager (907) 659 -7000 pgr 909 '" From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Thursday, December 01, 2011 2:38 PM To: NSK Problem Well Supv Cc: Dethlefs, Jerry C Subject: [EXTERNAL]RE: Seeking AA guidance for 3N -11 (PTD 186 -077, AIO 2B.024) and 3N -13 (PTD 186 -081, AIO 2B.038) 12 -01 -11 Kelly, I believe it is appropriate to view the AA's as suspended. They apply to the wells' operation while injecting. If the wells are returned to injection service, unless something has been physically changed in the wells the AA's should continue to apply. I hope this helps. Only thing to remember is to submit sundries to convert the wells back to injectors and provide verification of integrity. Tom Maunder, PE AOGCC From: NSK Problem Well Supv [mailto:n1617 @conocophillips.com] Sent: Thursday, December 01, 2011 11:08 AM To: Maunder, Thomas E (DOA) 12/2/2011 • • Page 2 of 2 Cc: Dethlefs, Jerry C Subject: Seeking AA guidance for 3N -11 (PTD 186 -077, AIO 2B.024) and 3N -13 (PTD 186 -081, AIO 26.038) 12- 01-11 Tom, Kuparuk wells 3N -11 (PTD 186 -077, A10 28.024) and 3N -13 (PTD 186 -081, AIO 2B.038) recently received approved sundries to temporarily produce these service wells in order to depressurize the formation in prep for CTD workovers. Since these were injectors that operated under variances, I would appreciate direction on how to handle the wells before they are put back on injection, following their temporary production period. Should I ask for an official cancellation of the AA's and resubmit applications for new ones when they are ready to be brought back on injection? Or is it sufficient to view the current AA's simply as suspended? It is my understanding that 3N -11 will be sidetracked, however 3N -13 will not be worked over (only depressurized to assist in the planned 3N- 07 CTD workover) and the time line for each is listed in the email below. Thanks Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr 909 rL ember 22, 2011 1:16 PM c -11, & 13 producers Jerry The plan as I understand it now is: 1) 3N -11 is scheduled for a workover in about a month - we would like to flow it until then to get the pressure down so it can be worked over and not have to use more expensive brine 2) 3N -13 we would like to flow for 1 to 2 months, get a pressure and then flow another month or 2 Both wells have been shut in for 5 or 6 months, but are not dropping pressure very fast. We have been in a vicious cycle - can't schedule the CTD because the psi is too high, but can't get priority to flow back and get the psi down because the wells are so far out on the schedule! Lamar 12/2/2011 • MIT ALASEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COM1tIISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Darrell Humphrey Production Engineering Specialist ConocoPhillips Alaska, Inc. r,, 0qq P.O. Box 100360 �� V Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3N -11 Sundry Number: 311 -344 Dear Mr. Humphrey: ,g4 L n Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Si - el � r 'i%I''. .man o ission DATED this D day of November, 2011. Encl. c ATE OF ALASKA 1 4 -ik ALASKA OIL AN AS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1 20 AAC 25.280 1. Type of Request: Abandon r Plug for Redrill IT Perforate New Pool IT Repair well IT Change Approved Program IT Suspend IT Rug Perforations r Perforate r Pull Tubing r Time Extension IT Operational Shutdown IT Re -enter Susp. Well IT Stimulate IT Alter casing r Other:WINJ to Prod F. 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development IT Exploratory IT 186 - 077 . 3. Address: 6. API Number: Stratigraphic IT Service r . P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 21580 - 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 r No r 3N -11 ' 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25512 ALK 2553 Kuparuk River Field / Kuparuk River Oil Pool " 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 8790 6637 8691' 6565' 8571' Casing Length Size MD ND Burst Collapse CONDUCTOR 79 16 115' 115' SURFACE 4523 12 4558' 3632' PRODUCTION 8746 7 8777' 6628' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 20 8435,8475 - 8490,8498 - 8524,8561 8:6373 - 6384,6412 - 6423,6429 - 6446,6459 - 649: 2.875 J - 55 8357 Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft) PBR - BAKER PBR SEAL ASSEMBLY (PINNED 40M #)W /1' SPACE MD= 8145 ND= 6178 PACKER - BAKER FHL PACKER (PINNED 60M# SHEAR) MD= 8158 ND= 6188 RECEIVED NIPPLE - 2.75" 'D' NIPPLE MD= 8200 ND= 6218 qp PBR - BROWN PBR MD= 8270 ND= 6267 NOV 0 4 2 W PACKER - BROWN 'HB' PACKER MD= 8287 ND= 6279 NIPPLE - CAMCO 'D' NO GO NIPPLE MD= 8325 ND= 6306 Alaska Oil & Gas Cons. Counisslion SOS - SHEAROUT SUB MD= 8357 ND= 6329 _ • SSSV= DS Nipple MD= 531 ND= 531 ' Antimage 12. Attachments: Description Summary of Proposal' ' r, 13. Well Class after proposed work: Detailed Operations Program IT BOP Sketch r Erploratory IT Development r Service IT 14. Estimatefl Date for Commencing Operations';: • , •„ " , 15. Well Statys after, proposed Work: _ , 11/15/2011 Oil r . Gas r WDSPL IT Suspended IT 16. VertaatApproval: Date: WINJ IT GINJ IT WAG IT Abandoned IT Commission Representative: GSTOR IT SPLUG I- 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Darrell Humphrey Printed Name Darrell Humphrey Title: Prod. Engineering Specialist Signature - a_.. r _ E qic �:" A- , Phone: 659 -7535 Date G 1 - [ • 1 Comm ssion Use Only 22 1 sw Sundry Numbe3l I Conditions of approval: Notify Commission so that a representative may witness �� JJ Plug Integrity IT BOP Test IT Mechanical Integrity Test i- Location Clearance IT Other: Subsequent Form Required: /n — 9o' / APPROVED BY T , ., Y / If -1( Approved by: • i . 0 H COMMISS Date: ! (j Form 10-403 Revise pp � t �� MS NOV i 9 4; ' do I N jj. jf Submit in Duplicat ' C ! 3N -11 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert KRU Well 3N -11 from Water Injection service to Oil Production service . The 16" Conductor was cemented with 250sx CS II (115' and / 115' tvd). The 9 -5/8" Surface casing (4558' and / 3643' tvd) was cemented with 1300sx AS III and 350sx Class G. The 7" Production casing (8777' and / 6639' tvd) was cemented with 300sx Class G and 175sx AS I. The top of the Kuparuk C was found at 8422' and / 6375' tvd. The top of the Kuparuk A was found at 8461' and / 6402' tvd. (WC) MITIA- passed; (State witnessed Jeff Jones) Initial T /I /0= 2700/320/3; Pressured up IA (with LRS) 2.5bbls. of diesel. T /I /0= 2700/3710/6; 15min. reading T /I /0= 2700/3670/6; 30min. reading T /1 /0= 2700/3670/3; Bled down IA Final T /I /0= 2700/325/3 p � # 4640 1 14.1" 1 war rc�si o / te/0/0 p re) /e4vc r /90 /14,/ WC0411p CV 0 0" ' /o d /#1,/ UP i 3N -11 ConocoPhillips �; Well l Max Angle D TD 14.I; 1 If 1: Wellbore APIIUWI Field Name Well Status Inc! (°) MD (ftKB) Act Btm (ftKB) L,onocdrinipa 500292158000 KUPARUK RIVER UNIT INJ 49.88 2,400.00 8,790.0 Comment H2S (ppm) Date Annotation End Date KB-Ord (N) Rig Release Date Well contp.- 3N- 11,11RR01085925 AM - SSSV:NIPPLE Last WO: 11/16/2007 39.49 4/13/1986 Schematic • Actual Annotation Depth (ftKB) End Date Annotation Last Mod By End Date Last Tag: SLM 8,552.0 10/12/2010 Rev Reason: TAG Imosbor 11/2/2010 HANGER, o'' J Casing Strings Casing Description String 0... String 10 ... Top (ftKB) Set Depth (5... Set Depth (TVD)... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H - 40 WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD)... String Wt... String ... String Top Thrd SURFACE 95/8 8.765 35.0 4,558.0 3,631.6 36.00 J BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.151 30.4 8,776.6 6,627.2 26.00 J -55 BTC Tubing Strings Tubing Descrlption String 0... String ID ... Top (fti(9) Set Depth (f_. Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 31/2 2.992 0.0 8,245.2 6,249.4 9.30 L -80 EUE 8RD CONDUCTOR, I Completion Details 38 -115 Top Depth (TVD) Top Inc( Nook... NIPPLE, 531 ; a Top (MB) (RKB) ( °) Item Description Comment ID (In) 0.0 0.0 0.38 HANGER FMC Tubing HANGER w/pup jt 2.992 Q 531.2 531.2 0.68 NIPPLE 2.812" 'DS' Nipple (2.856" lock) 2.812 8,144.6 6,178.5 45.32 PBR Baker PBR seal assembly (pinned 40M#)w /1' Space Out 2.992 8,158.2 6,188.1 45.28 PACKER Baker FHL Packer (pinned 60M# shear) 3.030 SURFACE, 558 8,200.2 6,217.7 45.08 NIPPLE 2.75" 'D' Nipple 2.750 / 8,238.8 6,244.9 45.01 XO Reducing 2 -7/8" pin x 3-1/2" box L-80 EUE 8RD crossover 2.480 , GAS LIFT, 8240.3 6,246.0 45.01 OVERSHOT Tubing Stub Overshot + 1' space out 1 3.000 8.090 r Tubing Description String 0... String ID ... Top (ftK8) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING Original J 2 7/8 I 2.441 I 8,234.5 I 8,358.3 I 6,329.6 l 6.50 I J -55 I EUE8rdABMOD Completion Details Top Depth (TVD) Top Incl Nom1.. PBR, 8,145 Top (fti(B) (RKB) ( ") Item Description Comment ID (in) PACKER, 8,158 8,270.0 6,267.0 44.95 PBR BROWN PBR 2A60 6,278.8 44.92 PACKER BROWN'HB' PACKER 3.000 8,324.7 6,305.7 44.86 NIPPLE CAMCO 'D' NO GO NIPPLE 2.250 8,357.4 6,328.9 44.80 SOS SHEAROUT SUB 2.441 NIPPLE. 8,200 -- - Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (TVD) Top Inc! Top (ftKB) MB) (1 Description Comment Run Date ID (in) l,p. Bin 8,571.0 6,480.6 44.61 FISH 1" BK Latch Ring Lost in Hole; May be laying in one of 10/25/1987 xo Reauc g 9 8285.7 Lower GLM OVERSHOT, 8,240 Perforations & Slots Shot - Top (rvD) Btm (TVD) Dens __... Top (ftKB) Bt n (ftKB) Im(8) 0 Zane Date (ab.•• Type Comment PBR, 8270 8,420.0 8,435.0 6,373.6 6,384.2 UNIT D, C-4, 8/23/1999 4.0 APERF 0 deg phase/90 deg CW from PACKER, 8,287 UNIT B, 3N-11 lowside; 2 1/8" EJ ® 8,475.0 8,490.0 6,412.4 6,423.0 A-3, 3N-11 9/26/1987 8.0 APERF 60 deg. ph; 2 1/8" Silver Jet NIPPLE. 6325 �• 8,498.0 8,518.0 6,428.7 6,442.9 A -2, 3N-11 9/26/1987 8.0 APERF 60 deg. ph; 2 1/8" Silver Jet 8,502.0 8,503.0 6,431.5 6,432.3 A -2, 3N-11 7/16/1986 1.0 'IPERF 120 deg. ph; 4" Jumbo Jet II III - 8,508.0 8,509.0 6,435.8 6,436.5 A -2, 3N-11 7/16/1986 1.0 IPERF 120 deg. ph; 4" Jumbo Jet II SOS, 8,357 8,510.0 8,511.0 6,437.2 6,437.9 A -2, 3N-11 7/16/1986 1.0 IPERF 120 deg. ph; 4" Jumbo Jet II 8,523.0 8,524.0 6,446.5 6,447.2 A -2, 3N-11 7/16/1986 1.0 IPERF 120 deg. ph; 4" Jumbo Jet II APERF, 8,540.0 8,560.0 6,458.6 6,472.8 A -2, 3N-11 6127/1996 4.0 RPERF 180 deg. ph; Orient( + / -) 90 deg F/ 8,420 - 8,435 Lowside; 2 1/8" EJ 8,551.0 8,552.0 6,466.4 6,467.1 A -1, 3N-11 7/16/1986 1.0 IPERF 120 deg. ph; 4" Jumbo Jet II 8,557.0 8,558.0 6,470.6 6,471.4 A -1, 3N-11 7/16/1986 1.0 IPERF 120 deg. ph; 4" Jumbo Jet II 8,e5 8,4450 8,561.0 8,562.0 6,473.5 6,474.2 A -1, 3N-11 7/16/1986 1.0 IPERF 120 deg. ph; 4" Jumbo Jet II 8,565.0 8,589.0 6,476.3 6,493.4 A -1, 3N-11 7/16/1986 1.0 IPERF 120 deg. ph; 4" Jumbo Jet II Notes: General & Safety IPERF, End Date Annotation 8 ' 8 ' 11/28/2007 NOTE: 1500 psi CSG to TUBING APERF, 8, 4988,518\ - 1/15/2008 NOTE: WAIVERED WELL - OAx ATMOSPHERE COMMUNICATION IPERF, 8,508 -8,509 IPERF. 8,5108.511 IPERF, 8,523-8,524 RPERF, 8,540.8,560 IPERF, 8,5518,552 IPERF, Mandrel Details 8,557 -8,558 Top Depth Top Port (TVD) Inc! OD Valve Latch Size TRO Run Stn Top(ftKB) (858) (°) Make Model (in) Sery Type Type (in) (psi) Run Date Com... 1 8,089.9 6,139.9 45.17 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 11/28/2007 See IPERF, 8,581 -8,562 Note FISH, 8,571 IPERF, 8,5658,589 PRODUCTION, O, ,777 TO, 8,700 , • • Robert Christensen/Darrell Humphrey Production Engineering Specialists. Greater Kuparuk Unit , NSK -69 PO Box 196105 ConocoPhil li ps Anchorage, AK 99519 -6105 Phone: (907) 659-7535 Fax: 659 -7314 November 1, 2011 Dan Seamount RECEIVED AOGCC Commissioner NOV 0 4 2011 State of Alaska, Oil & Gas Conservation Commission 33 W. 7 Ave. Ste. 100 Ail i(3 Commission Anchorage, AK 99501 Dear Mr. Seamount, ConocoPhillips Alaska, Inc. requests approval to convert Kuparuk Well 3N -11 from Water Injection Service to Oil Production service. Enclosed you will find 10 -403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. for 3N -11 (PTD 186 -077). If you have any questions regarding this matter, please contact myself or Robert D. Christensen at 659 -7535. Sincerely, Darrell R. Humphrey Attachments Sundry application Well schematic • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. August 24, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Bottom Hole Pressure Survey: 3N -11 Run Date: 8/7/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3N -11 Digital Data in LAS format, Digital Log Image file ICA g 1 CD Rom 50- 029 - 21580 -00 Bottom Hole Pressure Survey Log 1 Color Log 50- 029 - 21580 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: � l t Signed: 1.12_GLij ) °77 • • , , WELL LOG TRANSMITTAL PROACTIVE DIAG SERVICES, INC. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659 -5102 RE : Cased Hole /Open Hole /Mechanical Logs and/or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 101 : ' r+#1)Af C3 ` '' ii }',. 1) Caliper Report 07- Aug -11 3N -11 1 Report / CO 50-029 - 21580 -00 2) t i (--(? ot' Signed : \0 f.. ■Date : a. q o t 1 I Print Name: f r ..wo_w C3 k, -v- PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 Fax: (907)245 -8952 E-MAIL : PDSANCHORAGEOMEMORYLOG.COM WEBSITE : WWW.MEMORYLOG.COM D:\Archives\MIT Archives \ 2011\ 0g - August 2L- 307\CPAI_Kup_Cabper Template \CD_ Parts \ConocoPliillips_Transmitdoex / R L — 6 7 ? 1 • • Multi- Finger Caliper 1 t—! Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 3N -11 Log Date: August 7, 2011 Field: Kuparuk Log No.: 10259318 ZX70 State: Alaska ' Run No.: 1 API No.: 50- 029 - 21580 -00 Pipet Desc.: 7 " 26 Ib. J -55 BTC Top Log Intvll.: 8,347 Ft. (MD) Pipet Use: Casing Bot. Log Intvll.: 8,538 Ft. (MD) Inspection Type : Pre CTD- Sidetrack Inspection COMMENTS : ' This caliper data is correlated to HES injection profile dated October 24, 2011. This log was run to assess the condition of the 7" casing with respect to corrosive and mechanical damage prior to CTD- Sidetrack operations. A 3-D log plot of the caliper recordings across the proposed sidetrack ' interval is included in this report. The caliper recordings indicate the 7" casing logged below the 3.5" tubing tail and above the perforation ' interval at 8,420' appears to be in good condition with respect to corrosive and mechanical damage. No significant wall penetrations or areas of cross - sectional wall loss are recorded from 8,348' to 8,420'. The caliper recordings indicate erosion below 8,420', throughout the perforation intervals, with significant areas of cross - sectional wall loss recorded. Cross - sectional illustrations of these eroded areas are included in this report. The summary report is an interpretation of data provided by Halliburton Well Services. 1 1 Field Engineer: J. Conrad Analyst: C. Lucasan Witness: B. Boehme ' ProActive Di-agnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565 -9085 Fax: (281) 565-1369 E -mail: PDS ©memorylog.com Prudhoe Bay Field Office Phone: (907) 659 -2307 Fax: (907) 659 -2314 / 8� - 6 2 1 • • PDS Multifinger Caliper 3D Log Plot I Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 3N -11 Date : August 7, 2011 1 Description : Details of Caliper Recordings Across Proposed Interval for CTD- Sidetrack. Comments Depth Max. Penetration Maximum I.D. 3 -D Log Image Map I X ' 1ft:300ft 0 % 100 6 Inches 7 311° 0° 90° 180° 270° 0° Minimum I.D. 6 Inches 7 Nominal I.D. I • 6 7 8350 Jtl _ ' :::: ` - -- +—. • i -- • 8380 — Jt2 — _ I 8390 8400 �. -- - -- / Jt 3 � I L . ; t= Eroded 8410 -- _ I Perforation 23% X- Sectional 8420 - --' — Wall Loss i �! \ r •( —iir7 �_.. Jt 4 8430 0,1E11 — — Eroded i Perforation 8440 , • 28/ XSectional �r =r' — 1 Wall Loss - - 8450 , i _ Jt 5 , — 8460 W 1 Eroded `y Perforation 8470 1 - - - - -- 37% XSectional l� ` Wall Loss • "�` 61 • 1 8480 - - -- - - - - -- 8490 � — — — 1 Jts 1111 _ 8500 - -- Eroded -E `- Perforation e 1 8510 _ 16 �i ��P -_ - 4 8 / X- Sectional ��� =" Wall Loss , znii 8520 __ w 8530 Fi M � Jt 7 t ' 1 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 7. in 26.0 ppf J -55 BTC Well: 3N-11 Body Wall: 0.362 in Field: Kuparuk I Upset Wall: 0.362 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 6.276 in Country: USA Survey Date: August 7, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Ups % t Body Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 1 8348 0 0.02 6 2 6.24 2 8365 0 0.05 13 2 6.24 Shallow Pitting. ■ ii 3 8405 0.13 0.19 52 23 6.24 Perforation. ■■ 4 8424 0.16 0.25 69 28 6.23 Perforation. to 5 8444 0.17 0.51 100 37 6.17 Perforation. 1 I 6 8486 0.15 0.47 100 48 6.10 Perforation. 7 8527 0.10 0.12 32 10 6.07 Perforation. 8 8536 0 0 0 0 1.57 EOL I Penetration Body Metal Loss Body 1 1 1 1 1 1 1 1 1 I Page 1 1 1 • • 1 PDS Report Cross Sections I Well: 3N -11 Survey Date: August 7, 2011 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 10000429 (HAL) Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 1 Tubing: 7 ins 26 ppf J -55 BTC Analyst: C. Lucasan 1 1 Cross Section for Joint 6 at depth 8508.367 ft Tool speed = 48 I Nominal ID = 6.276 ■^ Nominal OD = 7 Remaining wall area = 52% _� Tool deviation = 44° 1 I I i 111 11 N, i pi r 1 N ,,, 1 Finger = 22 Penetration = 0.474 ins Eroded Perforation 48% Cross - sectional Wall Loss HIGH SIDE = UP 1 1 1 1 1 • • 1 PDS Report Cross Sections I Well: 3N -11 Kuparuk Survey Date: August 7, 2011 Field: Tool Type: UW MFC 24 Ext No. 10000429 (HAL) Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 1 Tubing: 7 ins 26 ppf J -55 BTC Analyst: C. Lucasan • 1 1 Cross Section for Joint 5 at depth 8479.961 ft Tool speed = 48 I OD Nominal 7 Nominal OD = 7 ` Remaining wall area = 63% IMMIlimp Tool deviation = 44° I \ 1 /4"Ill 1 1 I - 1 1 // 1 / r I Finger = 15 Penetration = 0.460 ins Eroded Perforation 37% Cross - sectional Wall Loss HIGH SIDE = UP 1 1 I 1 1 1 I ,.. , KUP 3N -11 Wellbor ConocPhillips /° Attributes ogle 8 MD TD ,.�.. e APWWI Field Narne Well Status Ind (°) r (NC8) Act Min (MB) 500292158000 KUPARUK RIVER UNIT INJ 49.88 2.40000 8,790 -0 ' "" Comment H2S (ppm) Dale Annotation End Date KB-Grtl (R) Rig Release Date I ... well Conn¢ - 3N - 11 1112120108:59 AM °,SSV: NIPPLE Last WO: 11/16/2007 _ 39.49 4/13/1986 Smematic ACtuai Annotation Depth End Dale Annotation Last Mod By - End Date Last Tag: SLM 8.5520 10112/2010 Rev Reason: TAG Imosbor 11/2/2010 HANGER, o Casing Strings Casing Description String 0... String ID... Top (Nt6) Set Depth (1... Set Depth (WVD)... String Wt... String... String Top Thrd CONDUCTOR 16 15.062 36.0 11 115.0 62.50 Hd0 WELDED I 1 3 ° Casing Description String 0... String ID ... Top (NCB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Turd SURFACE 9 5/8 8.765 35.0 4,558.0 3,631.6 36.00 J-55 BTC Casing Description String 0... Sting ID ... Top (NCB) Set Depth (f... Set Depth (TVD) String Wt_. String ... String Top Thrd PRODUCTION 7 6.151 30.4 8,776.6 6,627.2 26.00 J-55 BTC • Tubing Strings Tubing Description String 0... String ID ... Top (NCB) Set Depth (f... Set Depth (1VD) ... String Wt... String ... String Top Thrd I 1 TUBING 3 1/2 2.992 0.0 8,245.2 6,249.4 9.30 L-80 EUE8RD CONDUCTOR Completion Details 36 - 115 Top Depth (TVD) Top Ind Nomi.,. NIPPLE, 531 Top (15K8) (BEB) (°) hem Description Comment ID (in) 0.0 0.0 0.38 HANGER FMC Tubing HANGER w /pup jt 2.992 I Q 5312 531.2 0.68 NIPPLE 2_812" 'DS' Nipple (2.856" lock) 2.812 8,144.6 6,178.5 45.32 PBR Baker PBR seal assembly (pinned 40M#)w /1' Space Out 2.992 J 1 8,158.2 6,188.1 45.28 PACKER Baker FHL Packer (pinned 60M# shear) 3.030 .558 l 3sa F ss 8,200.2 6,217.7 45.08 NIPPLE 2.75 " 'D' Nipple 2.750 ' 8,238.8 6,244.9 45.01 XO Reducing 2 -7/8" pin x 3 -1/2" box L-80 EUE 8RD crossover 2480 GAS LIFE. t 8,240.3 6,246.0 45.01 OVERSHOT Tubing Stub Overshot + 1' space out 3.000 a.oeo 7 'R ang Description String 0... Si Mg ID ... Top (NCB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING Original 27/8 2441 8,234.5 8,358.3 6,329 -6 6.50 J-55 EUE8rdABMOD UR Completion Details Top Depth I PBR. 8,ia5 f (�) Top Ind Top (f6C8) MB) 1 ° ) Item Description Nord... ID (In) PACKER. 8.158 8,270.0 6,267.0 44.95 PBR BROWN PBR 2.460 1. 8,286.7 6,278.8 44.92 PACKER BROWN 'HB' PACKER 3.000 8,324.7 6,305.7 44.86 NIPPLE CAMCO 'D' NO GO NIPPLE 2.250 I NIPPLE. 8.200 al 8,357.4 6,328.9 44.80 SOS SHEAROUT SUB 2.441 Other In Hole 'reline retrievable plugs, valves, pumps, fish, etc.) Depth Top Dep (TVD) Top Ind Top (SKB) (O ( Description Comment Run Date ID (In) )(0 Reducing, 8,571.0 6,4806 44.61 FISH 1" BK Latch Ring Lost in Hole; May be laying in one of 10/25/1987 I 8,239 Lower GLM OVERSHOT, 8,240 Perforations & Slots Shot Top Top (TVD) Btm (TVD) Dens pins) Btm (NCB) gum) 'NCB) Zone Date (Nh... TYPe Comment • PBR. 8.270 8,420_0 8,435.0 6.373.6 6,384.2 UNIT D, C-4, 8/23/1999 4.0 APERF 0 deg phase/90 deg CW from i PACKER, 8,287 UNIT B. 3N -11 lowside; 2 1 /8" EJ 8,475.0 8,490.0 6,412.4 6,423.0 A -3, 3N -11 9/26/1987 8.0 APERF 60 deg. ph; 2 1/8" Silver Jet NIPPLE. 8,325 8,498.0 8,518.0 6,428.7 6,442.9 A -2, 3N -11 9/26/1987 8.0 APERF 60 deg ph; 2 1/8" Silver Jet 8,502.0 8,503.0 6,431.5 6,432.3 A -2, 3N -11 7/16/1986 1.0 IPERF 120 deg. ph; 4" Jumbo Jet II i 505,8,357 8,508.0 8,509.0 6,435.8 6,436.5 A -2, 3N -11 7/16/1986 1.0 IPERF 120 deg. ph; 4" Jumbo Jet II 8,510.0 8,511.0 6,437.2 6,437.9 A -2, 3N-11 7/16/1986 1.0 IPERF 120 deg. ph; 4" Jumbo Jet II 8,523.0 8,524.0 6,446.5 6,447.2 A -2, 3N-11 7/16/1986 1.0 IPERF 120 deg. ph; 4" Jumbo Jet II • APERF. 8,540.0 8,560.0 6,458.6 6,472.8 A -2, 3N-11 6/27/1996 4.0 RPERF 180 deg. ph; Orient( + / -) 90 deg F/ 8420 Lowside; 21/8" EJ 8,551.0 8,552.0 6,466.4 6,467.1 A -1, 3N-11 7/16/1986 1.0 IPERF 120 deg. ph; 4" Jumbo Jet II 8,557.0 8,558.0 6,470.6 6,471.4 A -1, 3N-11 7/16/1986 1.0 IPERF 120 deg. ph; 4" Jumbo Jet II i APERF, a.a�s - 849-0 8,561.0 8,562.0 6,473.5 6,474.2 A -1, 3N-i 1 7/16/1986 1.0 IPERF 120 deg. ph; 4" Jumbo Jet II 8,565.0 8,589.0 6,476.3 6,493.4 A -1, 3N -11 7/16/1986 1.0 IPERF 120 deg. ph; 4" Jumbo Jet II ■ = Notes: General 8 Safety IPERF, End Date Annotation 8,502 - 8,503 ira APERF r 11/28/2007 NOTE: 1500 psi CSG to TUBING 8,498 ;� 1/15/2008 NOTE: WAIVERED WELL - OA x ATMOSPHERE COMMUNICATION IPERF, 8,508-8,509 wpm I IPERF, 8.510-8,511 f IPERF, - 8,523 -8524 =__ RPERF. 8.540.8560 IPERF, 8 .551 -8.552 IPERF. Mandrel Details 8,557 - 8558 Top Depth Top - Port (TVD) Ind on Valve Latch Size TRO Run n Top (MUN (RK8) (°) Make Model (in) Sery TYPe Type OM (Psi) Run 0000 cam... 1 8.089.9 6.1399 45.17 CAMCO KBMG 1 GAS LIFT DMV BK 0.000 0 11/28/2007 See �.PERF Note 8551 8.552 I FISH. P588. �' IPERF. 8.565-8.589 I PRODUCTION, 30-8,7] - TO. 8,790 • s WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. November 10, 2010 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 I I RE: Injection Profile: 3N -11 Run Date: 10/25/2010 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 3N -11 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50- 029 - 21580 -00 Injection Profile Log 1 Color Log 50- 029 - 21580 -00 SQ L) NOV 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 o-3 9 5 Fax: 907 - 273 -3535 klinton.wocd� alliburtorr.com Date: Signed: r MEMORANDUM TO: ~,~31 ~~ ° Jim Regg ~~~~ P.I. Supervisor FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, March 23, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3N-11 KUPARUK RIV UNIT 3N-11 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv (~ Comm Well Name: KUPARUK RIV UNIT 3N-11 API Well Number: 50-029-21580-00-00 Inspector Name: Jeff Jones Insp Num: mitJJ100227213746 Permit Number: 186-077-0 Inspection Date: 2/9/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ 3N-11 Type nI 1860770'i ~ W SPT TVD__ • r 6188 ~ IA '~ 320 3 3710 ~ 6 3670 4 3670 3 P.T.D -- IT eTest YP - TCSt Sl ~_p 1547 , OA - - - - Interval x>:QvAIt p/F P / Tubing 270o z7oo z7oo 2700 Notes: MITIA per AIO 2B.024 ,i Tuesday, March 23, 2010 Page 1 of 1 Page 1 of 1 Maunder, Thomas E {DOA) from: NSK Well Integrity Prof ~N1878(d»nocophlips.comj Sent: Wednesday, February 10, 2fl10 2:13 PM To: Regg, James 8 {DOA); Br~ks, Phoebe L {©C)A); Maunder, Thomas E (I?OA); CAA AaflGCC Prudhoe Say Subject: Kuparuk MIT's #or AA compliance Attachments: MIT KfttJ 2C-07 02-9-10.x1s; N9iT KRU 3N-11 fl2-09-1fl.xls Jinn, Attached are the MITs #or 2C-07 {PTD 183-096, AA A1026.flfl7) and N-11 {PTD 186-077,~AA AIO 2E3.24). Jeff Jones witnessed the test. Please )et me know i# you have any questions. ~~ Thanks MJ Loveland Weli Integrity Projec# Supervisor ConocoPhillps Alaska, Inc. Othce {907) 659-7043 Cell {907)943-16$7 ~~"{`. ~ s~, i Llii' kr i , ?,, ~~~ ~ ~o 4/29/2010 U STATE OF ALASKA Email to:jim.regg~alaska.gov; phoebe.brooks~alaska.gov; tom.maunder~alaska.gov; doa.aogcc.prudhoe.bay~alaska.gov OPERATOR: ConocoPhillips Alaska Inc. FIELD /UNIT !PAD: Kuparuk /KRU / 3N-11 DATE: 02/09/10 OPERATOR REP: Colee /Phillips - AES AOGCC REP: Jeff Jones ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test • Packer De h Pretest Initial 15 Min. 30 Min. We11 3N-11 T In~. W TVD 6,188' Tubi 2,700 2,700 2,700 2,700 Interval O P.T.D. 1860770 T test P Test 1547 Cali 320 3,710 3,670 3,670 P/F P Notes: MITIA Per AIO 28.024 OA 3 6 3 3 Well T In". TVD TutM Interval P.T.D. T test Test Casi P/F Notes: OA Well T tn'. ND Tubi Interval P.T.D. T test Test Casi P/F Notes: OA Well T In". TVD Tubi Interval P.T.D. T test Test i Casin P/F Notes: OA Well T In'. TVD Tubi Interval P.T.D. T test Test Cass P/F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R = IMemal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT KRU 3N-11 02-09-10.x1s • • ConocoPhillips ~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 15, 2009 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~Ec~~V~~ FEe ~ ~ zdo~ Ai~~a ~~ ~ ~~~ Caps Co t~~~~ra~~ `said Please find the enclosed 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. we113N-11 (PTD 186-077, Sundry 308-422). The report records the ~ unsuccessful surface casing repair attempt with Brinker Platelets. Please call MJ Loveland or Perry Klein at 659-7043 if you have any questions. Sincerely, `` ~/ r ~ , MJ Loveland Well Integrity Project Supervisor • • ~~' V G® STATE OF ALASKA ~~~ ~ 7 ~Qp9 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERA~I~ ~ s Corts• ~ommissi°" 1.Operations Performed: Abandon ^ Repair Well ^~ Plug Perforations ^ Stimulate ^ ~~!tlf~`8~t? Q Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Chan e A roved Pro ram g pp g ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ SC repair wi Platelets 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: COnOCOPhilllps Alaska, InC. Development ^ Exploratory ^ 186-077 3. Address: Stratigraphic ^ Service^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21 580-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 68' ' 3N-11 . 8. Property Designation:. 10. Field/Pool(s): ADL 25512 •ALK 2553 Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 8790' feet true vertical 6637' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 115' 16" 115' SURFACE 4490' 9-5/8" 4558' 3632' PRODUCTION 8709' 7" 8777' 6628' Perforation depth: Measured depth: 8420-8435, 8475-8490, 8498-8524, 8561-8589 true vertical depth: 6373-6384, 6412-6423, 6429-6446, 6459-6493' Tubing (size, grade, and measured depth) 3.5"~2-7/8", L-801:J-55, 8238'C'8358' MD. Packers &SSSV (type & measured depth) pkr= Baker FHL Retrievable Packer pkr= 8158' SSSV= DS Nipple SSSV= 531' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure: See dally report Of Well OperatlOnS 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation N/A N/A 2064 675 3000 Subsequent to operation N/A N/A 2064 675 3000 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^ WAGQ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 308-422 Contact Perry Klein/ MJ Loveland Printed Name MJ Loveland Title Well Integrity Project Supervisor Signature ' Phone 659- 7043 ---- ~ ~ Date ~,-~ _ ` j~~, t . ! /~~~ i ~~ ~ ~ ~ 4 ~ d~ t C~ ~ ~•~/•~q Form 10-404 Revised 04/~Q~-~°• i '~. E ,~ ~ ~~ ~ ~~~~~ ~" ~~ ~ ~ ~ 7~Q9 Sub 't Original Only / .fir ~'T/~' 3N-11 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary Brinker Platelets SC Repair -inconclusive. Leak plunged prior to Initial T/I/O = 3000/675/0 Rigged up LRS to the platelet skid and started to pump diesel down the OA to establish a LLR. After pumping 1 bbl @ .1 bpm shut down at 1815 psi.. 15 min T/I/O = 3000/675/1775, 30 min T/I/O = 3000/675/1770, 45 min 3000/675/1775, 60 min 3000/675/1780. Bleed down the OA to 0 psi. Pressured the OA at a rate of .1 bpm to 1800 psi. with 3/10 the of a bbl. Bled the OA back to 0 psi. Re -pressured the OA at a rate of .5 bpm to 2000 psi. with 7/10 the of a bbl. after 30 min OA @ 1975 psi. bled down the OA to 200 .psi. after 15 min OA @ 275 psi. Bled down the OA to 0 psi. and rigged down LRS and the platelet skid. Final T/I/O = 3000/675/0 02/15/09 Ap lied ressure to OA, Fluid came to surface Platelet treatment unsuccessful • ~jr1,~11~~~1 Cs lJ~ ~~'~LL ~~~~,KS ~ld ALASKA OIL A1~TD GA,S CO1~T5ERQATI0111 CO1~II~'IISSIOI~T MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska Inc. PO Box 100360 ~(~r ~~ ~ 2~~ Anchorage, AK 99510 `~"~~~~~ SARAH PAL1N, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3N-11 Sundry Number: 308-422 ~' ~~ Dear Ms. Loveland: 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 Comrnission 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. Sincerely, P Cathy P. Foerster Commissioner ~-- DATED this ~ day of November, 2008 Encl. • • ConocoPhillips ~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 17, 2008 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7`'' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. we113N-11 (PTD 186-077) surface casing repair. Please call Perry Klein or me at 659-7043 if you have any questions. P Sincerely, G%'~-e-'' ,~' MJ veland ConocoPhillips Well Integrity Projects Supervisor Enclosures ~~`i~~. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPR01lAL 20 AAC 25280 ~\ 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other ^/ Alter casing ^ Chan a approved ro ram g p g ^ Repair well Q Plug Perrorations ^ Pull Tubing ^ Perforate New Pool ^ Stimulate ^ Time Extension ^ SC repair w! Re-enter Suspended Well ^ Platelets 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 186-077 3. Address: Stratigraphic ^ Service Q - 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21580-00 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 Q 3N-11 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25512 •ALK 2553 RKB 68' ~ Kuparuk River Field /Kuparuk Oil Pool 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8790' 6637 Casing Length Size MD TVD Burst Collapse CONDUCTOR 115' 16" 115' SURFACE 4490' 9-5/8" 4558' 3632' 3520 2020 PRODUCTION 8709 7" 8777' 6628' 4980 4320 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 3.5" L-80 8238' 8420-8435, 8475-8490, 8498-8524, 8561-8589 6373-6384, 6412-6423, 6429-6446, 6459-6493' 2-7/8" J-55 8358' Packers and SSSV Type: Packers and SSSV MD (ft} pkr-- Baker FHL Retrievable Packer pkr= 8158' SSSV= DS Nipple SSSV= 531' 13. Attachments: Description Summary of Proposal ~ 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: December ~o, 2ooa Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG Q - GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the b t of my knowledge. Contact: Perry Klein/ MJ Loveland Printed Name MJ Lovela Title: Well Integrity Project Supervisor Signature ~~' Phone 659- 7043 Date ~ G9L~ Q Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ~ - p Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ~ Location Clearance ^ Other: S~~~GJ~ ~~~J~~ °\v~~Of Mf~.~®r w / ~~~ <7~2C-C~.~iC3~S SJt~I~-~G,~ Subsequent Form Required: '~~~ Approved by: ~ COMMISSIONER APPROVED BY THE COMMISSION Date: ~ -~~~ Form 10-403 Revised 06/2006 I~y~ ~~ ~ ~ ~ ~ ~ ~..- ~v ~~• ~$ubmit ii~nplice`~ ~~ • ConocoPhillips Alaska, Inc. Kuparuk We113N-11 (PTD 186-077) SUNDRY NOTICE 10-403 APPROVAL REQUEST November 17, 2008 This application for Sundry approval for Kuparuk we113N-11 is for the repair of a surface casing leak. Kuparuk River Unit we113N-11 (PTD 186-077) was drilled and completed in April 1986 as a development well and subsequently converted to an injector. In March 2006 a surface casing leak was reported to the AOGCC. Subsequent testing indicates the leak depth in the surface casing is approximately 23' 10" down from the OA valve. Due to the depth of the leak ConocoPhillips is planning a repair attempt with Brinker Platelets. Platelets are free floating (neutral density) discrete particles which are injected into the system (in this case the OA) and transported with the fluid flow and entrained in the leak with fluid force thus providing a seal. The Platelet material is entirely inert, designed to function in oil and gas applications and within the operating conditions of the well. Each partial is individually sized to fit the predicted leak geometry. With approval, repair of the surface casing will require the following general steps: 1. Rig up Platelet manifold to OA 2. Establish liquid leak rate; 3. Deploy a finite number of Platelets; 4. Maintain specified pressure on OA for a specific amount of time (to be determined by Platelet Tech, however probably less than 1000 psi). 5. MITOA to 1800 psi; 6. Return well to normal operations, however maintaining some positive pressure on OA. 7. File 10-404 & Cancel AA AIO 2B.024 ..`SSJ ~ `a ~~~ ~`~ ~~ ~~~~ MEMORANDUM To~ Jim Regg ~ 1 P.I. Supervisor ~~~~( l ~` ~I~ FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, October O1, 2008 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3N-II KUPARIIK RIV UNIT 3N-11 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.LSuprv~~'~ Comm Well Name: KUPARUK RN UNIT 3N-11 API Well Number: 50-029-21580-00-00 Inspector Name: Bob Noble Insp Num: mitRCN080930093631 Permit Number: 186-077-0 / Inspection Date: 9/28/2008 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ! 3N-u Type Inj. W ~ TVD 6188 IA 625 3370 i 3310 3300 1860770 ~ ~ SPT P.T. ~ TypeTest ~ Test psi 3370 ~I' pA z a ~ 7 7 Interval REQVAR p~F P ~ Tubing 2300 2300 2300 2300 NOteS: MIT-IA to 1.2 times max anticipted injection pressure .~ ~ +~ '" ^ r'.': ~~- A-~ zg ,~ ~ Wednesday, October 01, 2008 Page I of I ~I I~Y~~~i~~l- Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # j ;- 02/20!08 NO.4595 1 'V ~~~R1~ FEB ~ ~ ~,Oui~ Log Description Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 2L-319 11970619 SCMT - ( 12/31/07 1 1A-02 11994615 INJECTION PROFILE (- 02111/08 1 1F-10 11994616 INJECTION PROFILE - / 02/12/08 1 2X-08 11996603 INJECTION PROFILE U=C / ~. - (~ 02/13/08 1 3N-11 11968841 INJECTION PROFILE - ~'~~. 02/16/08 1 1J-152 11994623 PRODUCTION PROFILE (p - / 02/18/08 1 2W-17 NIA SBHP SURVEY ~ _ <- 02/20108 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • • g • ' MEMORANDUM To: Jim Regg ZCZ U'~ P.I. Supervisor ~ ~~~ FROi`1: Chuck Scheve Petroleum Inspector • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, February O6> ?008 SUBJECT: iVlechanical Integrity Tests CONOCOPHILLIPS ALASKA nVC 3N-1 1 KUPARLR RIV UNIT 3N-1 1 Src: [nspector NON-CUNFIDENTIAI, Reviewed By: P.I. SuprvJ~~' Comm Well Name• KuPaRUIC RIV tNIT 3N-t t API Well Number: 50-02~-2 t 580-00-0o Inspector Name: Chuck Scheve Insp Num• mitCS080205154448 permit Number 186-077-0 Inspection Date• 2/4/2008 Rel Insp Num: Packer Depth ~ Pretest Initial 15 N1in. 30 Min. 45 Min. 60 Min. Well ~~ 3N-I 1 PC Ind • ~ ~, ~VD ~ - , -~ 6188 ~', I ~ ~ 820 2980 /~~ ?940 ~ 2940 ~ ~ ~- - P.T ,, 1860770 TYPeTest sPT Test psi --~ sa7 p - o I o o -- o - Interval wlucovx P/F P ~ Tubing ~; 1 soo 1 soo 1 soo 1 soo ~ --- - - - -- NOteS' Pretest pressures observed and found stable. GVell has known OA x conductor communication . ~~~IN~~ FEB ~ 0 204 Wednesday, February O6, 2008 Page 1 of 1 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~~~, 41 ~. W ~Vld4 t1 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon ^ Repair Well ~ Plug Perforations ^ Stimulate ^ ter` c ~ ~°~'I '' ` Alter Casing ^ Pull Tubing Q Pertorate 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 ^ 186-077 3. Address: Stratigraphic ^ service ~ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21580-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 68' - 3N-11 8. Property Designation: 10. Field/Pool(s): ADL 25512,rALK 2553 Kuparuk River Field /Kuparuk Oil Pooi 11. Present Well Condition Summary: Total Depth measured 8790' feet true vertical 6637 ' feet Plugs (measured) 8325' Effective Depth measured 8578' feet Junk (measured) 8571' true vertical feet Casing Length Size MD TVD Burst Collapse Structural - CONDUCTOR 115' 16" 115' 115' SUR. CASING 4490' 9-5/8" 4558' 3632' .,. PROD. CASING 8709' 7" 8777' 6628' Perforation depth: Measured depth: 8420'-8589' ~ ~,`~~ ~ JA~ ~ ~~~~ true vertical depth: 6373'-6493' Tubing (size, grade, and measured depth) 3.5" ! 2-7/8", L-80 / J-55, 8238' / 8358' MD. Packers & SSSV (type & measured depth) pkr---BAKER FHL retriev., BROWN 'HB' pkr-- 8158', 8287 ~ ' -- - - ° ' Camco'DS' nipple ~ 531' 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 St 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 Q ~ 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: 307-331 contact Brett Packer @ 265-6845 Printed Name Brett Packer Signature Title Phone Weils Group Engineer Date /Z~Z~ jv ~ -- Pre red b Sharon Allsu Drake 63-4612 Form 10-404 Revised 04/2004 ~~ :,?~ ~~ C€ ?00~ ,~ `~ a1~4' .hr~ ~~ 22. ~ Submit Original Onty r~ Time Logs _ Date From To Dur S. Depth E. De th Phase Code Subcode T COM 11/15/2007 22:30 00:00 1.50 8,238 COMPZ RPCOti CIRC P RU and circ 217 bbls annular vol. @ 3 b m w/ 240 si. Returns were clean. 11/16/2007 00:00 00:30 0.50 COMPZ RPCO CIRC P Chase 20 bbls 9.6 ppg Brine mixed w/ 1% by vol. CRW 132 followed by 71 bbls to spot inhibited fluid around acker 00:30 03:00 2.50 COMPZ RPCOti PACK P Rih to 8237', drop ball and rod, pressure up to 2700 psi and set acker 8148.5 - 8156' w/ top of PBR @ 8135'. Bleed down to 1000 psi, shear out of PBR @ 80k w/ 60k u wt. 03:00 04:30 1.50 COMPZ RPCO HOSO P Pooh and lay down 3 jts., PU 2-10',1-6' Pup jt, 1jt., Tbg hanger and Rih w/ 1.5' of s ace out. 04:30 06:30 2.00 COMPZ RPCOM1 DHEO P Press. test tb to 2500 psi for 30 minutes and chart, bleed doter to 1750 psi. Pressure test IA to 2500 si for 30 minutes and Charted. Bleed off tbg and shear out SOV @ 900 psi. Witneesing of the MIT Test was waived by Lou Grimaldi "AOGCC requires MITIA within 30 days of inital in'ection." 06:30 07:30 1.00 COMPZ RPCOA OTHR P Lay down landing jt and set BPV. 07:30 13:00 5.50 COMPZ RPCO ND BOP and NU tree 13:00 17:00 4.00 COMPZ RPCO Press test tree 250/5000 psi. Pulled BPV. Pumped 76 bbl of diesel down the IA, allowed to U-tube with the tubin . 17:00 18:00 1.00 COMPZ RPGO Set BPV. Rig back Little Red and clean up cellar. Release rig @ 18:00 11/16/07. ~ e ____ P~~~~ 3 ~f 3 ~ ~t~a~~t~Gt~PF~iliip~ ~i~~ska, inc. 1 ~~ \ SN-11 __ API: 5002921 TUBING i SSSVType: NIPPLE (o-823e, OD:3.500, ID:2ssz) ' ' ~ Annular Fluid: xo (8238240, OD:3.500) PBR (8270-8271, OD:2.875) PKR (8287-8288, OD:6.151) NIP (8325-8326, OD:2.875) TUBING (8238-8358, OD:2.875, ID:2.441) Pert (8475-8490) Pert (8502-8503) Perf (8498-8518) Perf (8508-8509) Pert (8523-8524) Perf (8540-8560) Pert (8551-8552) Perf (8565-8589) ~.. ~- -~ 2~ • KRU 3N-11 __ _ --- -- Well T e: I NJ An le TS: 45 de 8423 Orig 4/13/1986 Angle @ TD: 44 deg @ 8790 Com letion: Last W/O: 11/16/2007 Rev Reason: WORKOVER, Pull ball, rod, RHC, set DMY Ref Loa Date: Last Update: 12/5/2007 Last Tag: 8578' TD: 8790 ftKB i ~ Last Tag Date: 7/30/2007 Ma_x Hole Angle: 50 deg @ 2400 asing String -ALL STRINGS - - Descri lion Size To Bottom TVD YVt Grade Thread CONDUCTOR 16.000 0 115 115 62.50 H-40 SUR. CASING 9.625 0 4558 3632 36.00 J-55 PRDD. CASING 7.000 0 8777 - _ 6628 26.00 __ J-55 Tnhinn Strinn - TI IRIN[~ Size - To - Bottom TVD Wt Grade Thread 3.500 0 8238 6244 9.30 L-80 EUE8rdMOD 2.875 8238 Perforations Summary Interval TVD 8358 6329 - Zone Status Ft SP 6.50 _ F Date J-55 _ T e EUE 8RD ABM _ -- Gomment 8420 - 8435 6373 - 6384 UNIT D,C-4,UNIT B 15 4 8/23/1999 APERF 0 deg phase/90 deg CW from lowside; 21/8" EJ 8475 - 8490 6412 - 6423 A-3 15 8 9/26/19137 APERF 60 d h• 2 1/8" Silver Jet 8498 - 8502 6429 - 6432 A-2 4 8 9/26/1987 APERF 60 d h• 2 1/8" Silver Jet 8502 - 8503 6432 - 6432 A-2 1 9 9/26/19137 APERF 60 d h; 2 1/8" Silver Jet 8503 - 8508 6432 - 6436 A-2 5 8 9!26!1987 APERF 60 d h; 21/8" Silver Jet 8508 - 8509 6436 - 6437 A-2 1 9 9/26/19137 APERF 60 d h; 2 1/8" Silver Jet 8509 - 8510 6437 - 6437 A-2 1 8 9/26/19137 APERF 60 d h; 2 1/8" Silver Jet 8510 - 8511 6437 - 6438 A-2 1 9 9/26/1987 APERF 60 d h• 21/8" Silver Jet 8511- 8518 6438 - 6443 A-2 7 8 9/26/191;7 APERF 60 d h; 2 1/8" Silver Jet 8523 - 8524 6446 - 6447 A-2 1 1 7/16/191;6 IPERF 120 d h• 4"Jumbo Jet II 8540 - 8551 6459 - 6466 A-1 11 4 6/27/1996 RPERF 180 deg. ph; Orient(+/-) 90 de F/ Lowside• 2 1/8" EJ 8551- 8552 6466 - 6467 A-1 1 5 6/27/1996 RPERF 180 deg. ph; Orient(+/-) 90 de F/ Lowside• 2 1/8" EJ 8552 - 8557 6467 - 6471 A-1 5 4 6/27/1996 RPERF 180 deg. ph; Orient(+/-) 90 de F/ Lowside; 2 118" EJ 8557- 8558 6471 - 6471 A-1 1 5 6/27/1996 RPERF 180 deg. ph; Orient(+/-) 90 de F/ Lowside; 2 1/8" EJ 8558 - 8560 6471 - 6473 A-1 2 4 6/27/1996 RPERF 180 deg. ph; Orient(+/-) 90 de F/ Lowside; 2 1/8" EJ 8561- 8562 6474 - 6474 A-1 1 1 7li6/1986 IPERF 120 d h; 4"Jumbo Jet II 8565- 8589 6476-6493 A-1 24 1 7/16/1986 IPERF 120 deg._ph; 4"Jumbo Jet II Gas Lift Mandrels/Valves az mu ~ vu man mrr man i ype v mrr v r ype v uu ~aicn ron ~ nu uare nun vnr Cmnt 1 8090 6140 CAMCO KBMG DMY 1.0 BK 0.000 0 11/28/200 1 1. 1500 psi CSG fo TBG Other (plugs, equip., etc.) - COM_ PLETION , De th TVD T e Descri ion ID 31 31 HANGER FMC TUBING HANGER 3.500 531 531 NIP CAMCO'DS' NIPPLE 2.856" LOCK set 11/14/2007 2.812 8144 6178 PBR/SBR BAKER 80-40 PBR set 11/14/2007 2.970 8158 6188 PACKER BAKER FHL RETRIEVABLE PACKER set 11/14/2007 2.980 8200 6218 NIP CAMCO'D' NIPPLE set 11/14/2007 2.750 8238 6244 XO CROSSOVER FROM NEW 3.5"TBG TO ORIGINAL 2.875" TUBING @ OVERSHOT set 11/14/2007 2.875 8240 6246 Overshot BAKER POORBOY OVERSHOT set i 1/14/2007 2.480 8270 6267 PBR Brown 2.500 8287 6279 PKR Brown 'HB' 3.000 8325 6306 PLUG 2.25" CA-2 Bianki PLUG set 7/23/2007 8325' RKB 0.000 8325 6306 NIP Camco'D' Ni le NO GO 2.250 8357 6329 SOS Brown 2.441 8358 6329 TTL 2.441 .Fish -FISH -_ De h Descri lion Comment 8571 1" BK Latch Rino Lost in Hole: Mav be lavino in one of Lower GLM • • �1 SARAH PAUN, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMlrIISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -103 FAX (907) 276 -7542 ADMINISTRATIVE APPROVAL 2B.024 Mr. Martin Walters Problem Well Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 P { RE: KRU 3N -11 (PTD 1860770) Request for Administrative Approval Kuparuk River Oil Pool Dear Mr. Rogers: In accordance with Rule 9 of Area Injection Order ( "AIO ") 02B.000, the Alaska Oil and Gas Conservation Commission ( "AOGCC" or "Commission ") hereby grants ConocoPhillips Alaska Inc. ( "CPAI ")'s request for administrative approval to continue water injection in the subject well. Kuparuk River Unit ( "KRU ") 3N -11 exhibits communication between the surface casing and conductor at approximately 24 feet below the annulus valve. Mechanical integrity tests performed on the well's tubing and inner annulus ( "IA ") demonstrate the well has competent tubing and production casing. The Commission finds that CPAI does not intend to perform repairs at this time, but intends to repair the well in the future either by excavation and patching the surface casing or by using sealant technology. The Commission further finds, based upon reported results of CPAI's diagnostic procedures and wellhead pressure trend plots, that KRU 3N -11 exhibits two competent barriers to the release of well pressure. Accordingly, the Commission believes that the well's condition does not compromise overall well integrity so as to threaten human safety or the environment. AOGCC's administrative approval to continue water injection in KRU 3N -11 is conditioned upon the following: 1. CPAI shall record wellhead pressures and injection rate daily; 2. CPAI shall submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli; AIO 2B.024 • • December 24, 2007 Page 2 of 2 3. CPAI shall perform an MIT -IA every 2 years to 1.2 times the maximum anticipated injection pressure; 4. CPAI shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; 5. After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection, and 6. The MIT anniversary date is November 28, 2007. As provided in AS 31.05.080(a), within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless reconsideration has been requested. DONE at Anchorage, Alaska and dated December 24, 2007. i 4 / / ....„,, ....„ , Le, A.,....„/ , i Jo , 1 � ' 'o .' an Daniel T. Seamount, Jr. Cathy ' . Foerster hair . Commissioner Co issioner vs,t sitak 04, 44,6Q6 IF ;/ Zug 84 i • Conoco Phillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 December 4, 2007 RECEIVED Mr. Tom Maunder Alaska Oil & Gas Commission DEC 1 1 2007 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 46aska Oil & Gas Cons, CQR1mISSIQn Anchorage Dear Mr. Maunder: Enclosed please find an application for Administrative Relief request for ConocoPhillips Alaska, Inc., well 3N -11. The Administrative Relief is for approval to continue water injection with a surface casing leak. A proposal discussion document and well schematic are attached. Please call Brent Rogers or Martin Walters at 659 -7224 or Perry Klein or MJ Loveland at 659- 7043 if you have any questions. Sincerely, 761/7 kt Martin Walters ConocoPhillips Problem Well Supervisor Attachments • • ConocoPhillips Alaska, Inc. Kuparuk Well 3N -11 (PTD 186 -077) Technical Justification for Administrative Relief Request Purpose ConocoPhillips Alaska, Inc., proposes that the AOGCC approve this Administrative Relief request as per Area Injection Order 2B, Rule 9, to continue water only injection with known annular communication for Kuparuk injection well 3N -11. Well History and Status Kuparuk River Unit well 3N -11 (PTD186 -077) was drilled and completed in April 1986 as a development well and subsequently converted to an injector. In 2004, 3N -11 developed annular communication across the packer and was approved for injection with Sundry # 304 -299. On 3/30/06 the well was shut in and secured after discovering a shallow surface casing leak which was reported to AOGCC. A workover was completed in November 2007 which replaced the tubing and repaired the annular communication. Additional diagnostics performed during the workover confirm renewed production casing and tubing integrity with a passing MITT to 2500 psi and a passing MITIA to 3000 psi, as well as, wellhead seal integrity based on passing tubing and inner casing pack off tests. Surface casing diagnostics identified a leak in the surface casing —23'10" from the OA annular valve. CPAI intends to repair the surface casing leak in the future either by excavation and patching or sealant. However until a repair can be scheduled, ConocoPhillips request an AA which will allow water only injection in 3N -11. The well is currently secured with a plug in the D- nipple at 8325'. Barrier and Hazard Evaluation Tubing: The 3.5" 9.3 # L -80 tubing has integrity to the packer at 8158' MD based on passing pressure tests (MITT and MITIA) performed and charted by the rig on 11/16/07. The MITT and MITIA performed following the workover passed on 11/28/07. Production casing: The 7" 26# J -55 production casing has integrity to the packer at 8158' MD based on the MITIA described above. Surface casing: The well is completed with 9 -5/8" 36# J -55 surface casing set at 4558' MD (3632' TVD). After drilling out the surface casing and setting the production casing an OA cement shoe was pumped on 4/21/1986. 29 bbls of cement were bullheaded down the OA followed by 60 bbls of arctic pack. The cement shoe was tested to 1000 psi on 4/22/86. A near surface leak is located in the casing at approximately 23' 10" Primary barrier: The primary barrier to prevent a release from the well and provide zonal isolation is the tubing and packer. Second barrier: The production casing is the secondary barrier should the tubing fail. Monitoring: Each well is monitored daily for wellhead pressure changes. Should leaks develop in the tubing, production casing, or surface casing it will be noted during the daily monitoring process. Any deviations from approved MAOP annular pressures require investigation and NSK Problem Well Supervisor 12/7/2007 1 • • corrective action, up to and including a shut -in of the well. T/I plots are compiled, reviewed, and submitted to the AOGCC for review on a monthly basis. Proposed Operating and Monitoring Plan 1. Well will be used for water injection only (no gas or MI allowed); 2. Perform a passing MITIA every 2 -years as per AOGCC criteria (0.25 x tvd @ packer, 1500 psi minimum); 3. Submit monthly reports of daily tubing & IA pressures and injection volumes; 4. Shut -in the well should MIT's or injection rates and pressures indicate further problems; 5. Workover and/or repair the well prior to gas injection consideration with appropriate AOGCC notification. NSK Problem Well Supervisor 12/7/2007 2 . ConocoPhillips Alaskalc. KRU 3N -11 3N -11 API: 500292158000 Well Type: INJ Angle 0 TS: 45 deg (il 8423 TUBING (0-8238 SSSV Type: NIPPLE Orig 4/13/1986 Angle @ TD: 44 deg @ 8790 00:3.500, Completion: ID:2.992) Annular Fluid: Last W /O: 11/16/2007 Rev Reason: WORKOVER, Pull ball, rod, RHC, set DMY Reference Log_ Ref Log Date: Last Update: 12/5/2007 it_ Last Tag: 8578' TD: 8790 ftKB Max Hole An — Last Taq Date: 7/30/ Angle: 50 deg @ 2400 Casing String - ALL STRINGS _____ Description Size Top Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 115 115 62.50 H-40 SUR. CASING 9.625 0 4558 3632 36.00 J -55 PROD. CASING 7.000 0 8777 6628 26.00 J -55 _ Tubing String - TUBING Size Top Bottom ND Wt Grade Thread 3.500 _ 0 8238 6244 9.30 L 80 EUE8rdMOD 2.875 8238 8358 6329 6.50 J -55 EUE 8RD ABM Perforations Summary _ Interval ND Zone Status Ft SPF Date Type Comment 8420 - 8435 6373 - 6384 UNIT 15 4 8/23/1999 APERF 0 deg phase /90 deg CW D,C- 4,UNIT from lowside; 2 1/8" EJ xo B (8238 - 8240, 8475 - 8490 6412 - 6423 A -3 15 8 9/26/1987 APERF 60 deg. ph; 2 1/8" Silver Jet OD:3.500) 8498 - 8502 6429 - 6432 A -2 4 8 9/26/1987 APERF 60 deg. ph; 2 1/8" Silver Jet 8502 - 8503 6432 - 6432 A -2 1 9 9/26/1987 APERF 60 deg. ph; 2 1/8" Silver Jet 8503 - 8508 6432 - 6436 A -2 _ _ 5 8 9/26/1987 APERF 60 deg. ph; 21/8" Silver Jet PBR 8508 - 8509 6436 - 6437 A -2 1 9 9/26/1987 APERF 60 deg. ph; 2 1/8" Silver Jet (8270 -8271, 8509 - 8510 6437 - 6437 A -2 1 8 9/26/1987 APERF 60 deg. ph; 2 1/8" Silver Jet OD:2.875) 8510 - 8511 6437 - 6438 A -2 1 9 9/26/1987 APERF 60 deg. ph; 21/8" Silver Jet 8511 - 8518 6438 - 6443 A -2 7 8 9/26/1987 APERF 60 deg. ph; 2 1/8" Silver Jet PKR 8523 - 8524 6446 - 6447 A -2 1 1 7/16/1986 IPERF 120 deg. ph; 4" Jumbo Jet II (8287-8288, 8540 - 8551 6459 - 6466 A -1 11 4 6/27/1996 RPERF 180 deg. ph; Orient( + / -) 90 OD:6.151) deg F/ Lowside; 2 1/8" EJ 8551 - 8552 6466 - 6467 A -1 1 5 6/27/1996 RPERF 180 deg. ph; Orient( + / -) 90 NIP deg F/ Lowside; 2 1/8" EJ (8325 -8326, 8552 - 8557 6467 - 6471 A -1 5 4 6/27/1996 RPERF 180 deg. ph; Orient( + / -) 90 00:2.875) deg F/ Lowside; 2 1/8" EJ TUBING 8557 - 8558 6471 - 6471 A -1 1 5 6/27/1996 RPERF 180 deg. ph; Orient( + / -) 90 (8238 -8358, —or j deg F/ Lowside; 2 1/8" EJ OD:2.875, 8558 - 8560 6471 - 6473 A -1 2 4 6/27/1996 RPERF 180 deg. ph; Orient( + / -) 90 ID:2.441) I_- deg F/ Lowside; 2 1/8" EJ 8561 - 8562 6474 - 6474 A -1 1 1 7/16/1986 IPERF 120 deg. ph; 4" Jumbo Jet II 8565 - 8589 6476 - 6493 A -1 24 1 7/16/1986 IPERF 120 deg. ph; 4" Jumbo Jet II Gas Lift Mandrels Naives St MD ND Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt Perf (8475 -8490) "^ 1 8090 6140 CAMCO KBMG DMY 1.0 BK 0.000 0 11/28/2007 (1) 1. 1500 psi CSG to TBG Other (plugs, equip., etc.) - COMPLETION _ , Depth ND Type Description ID Perf - 31 31 HANGER FMC TUBING HANGER 3.500 (8502 -8503) — 531 531 NIP CAMCO DS' NIPPLE (2.856" LOCK) set 11/14/2007 2.812 Perf 8144 6178 PBR/SBR BAKER 80 -40 PBR set 11/14/2007 2.970 (ease -e51e> - 8158 6188 PACKER BAKER FHL RETRIEVABLE PACKER set 11/14/2007 2.980 8200 6218 NIP CAMCO 'D' NIPPLE set 11/14/2007 2.750 8238 6244 XO CROSSOVER FROM NEW 3.5" TBG TO ORIGINAL 2.875" TUBING @ 2.875 Perf OVERSHOT set 11/14/2007 (8508 -8509) 8240 6246 Overshot BAKER POORBOY OVERSHOT set 11/14/2007 2.480 8270 6267 PBR Brown 2.500 Perf 8287 6279 PKR Brown 'HB' 3.000 (8523 -8524) 8325 6306 PLUG 2.25" CA -2 Blanking PLUG set 7/23/2007 0 8325' RKB 0.000 8325 6306 NIP Camco 'D' Nipple NO GO 2.250 Perf 8357 6329 SOS Brown 2.441 (8540-8560) Perf — - 8358 6329 I TTL 2.441 (8551 -8552) - Fish - FISH Depth Description Comment Perf 8571 1" BK Latch Ring Lost in Hole; May be laying in one of Lower GLM (8565 -8589) Q • • ConocoPhillips Alaska, Inc. Kuparuk Well 3N -11 (PTD 186 -077) Technical Justification for Administrative Relief Request Purpose ConocoPhillips Alaska, Inc., proposes that the AOGCC approve this Administrative Relief request as per Area Injection Order 2B, Rule 9, to continue water only injection with known annular communication for Kuparuk injection well 3N -11. Well History and Status Kuparuk River Unit well 3N -11 (PTD186 -077) was drilled and completed in April 1986 as a development well and subsequently converted to an injector. In 2004, 3N -11 developed annular communication across the packer and was approved for injection with Sundry # 304 -299. On 3/30/06 the well was shut in and secured after discovering a shallow surface casing leak which was reported to AOGCC. A workover was completed in November 2007 which replaced the tubing and repaired the annular communication. Additional diagnostics performed during the workover confirm renewed production casing and tubing integrity with a passing MITT to 2500 psi and a passing MITIA to 3000 psi, as well as, wellhead seal integrity based on passing tubing and inner casing pack off tests. Surface casing diagnostics identified a leak in the surface casing —23'10" from the OA annular valve. CPAI intends to repair the surface casing leak in the future either by excavation and patching or sealant. However until a repair can be scheduled, ConocoPhillips request an AA which will allow water only injection in 3N -11. The well is currently secured with a plug in the D- nipple at 8325'. Barrier and Hazard Evaluation Tubing: The 3.5" 9.3 # L -80 tubing has integrity to the packer at 8158' MD based on passing pressure tests (MITT and MITIA) performed and charted by the rig on 11/16/07. The MITT and MITIA performed following the workover passed on 11/28/07. Production casing: The 7" 26# J -55 production casing has integrity to the packer at 8158' MD based on the MITIA described above. Surface casing: The well is completed with 9 -5/8" 36# J -55 surface casing set at 4558' MD (3632' TVD). After drilling out the surface casing and setting the production casing an OA cement shoe was pumped on 4/21/1986. 29 bbls of cement were bullheaded down the OA followed by 60 bbls of arctic pack. The cement shoe was tested to 1000 psi on 4/22/86. A near surface leak is located in the casing at approximately 23' 10" Primary barrier: The primary barrier to prevent a release from the well and provide zonal isolation is the tubing and packer. Second barrier: The production casing is the secondary barrier should the tubing fail. Monitoring: Each well is monitored daily for wellhead pressure changes. Should leaks develop in the tubing, production casing, or surface casing it'will be noted during the daily monitoring process. Any deviations from approved MAOP annular pressures require investigation and NSK Problem Well Supervisor 12/7/2007 1 • • corrective action, up to and including a shut -in of the well. T/I plots are compiled, reviewed, and submitted to the AOGCC for review on a monthly basis. Proposed Operating and Monitoring Plan 1. Well will be used for water injection only (no gas or MI allowed); 2. Perform a passing MITIA every 2 -years as per AOGCC criteria (0.25 x tvd @ packer, 1500 psi minimum); 3. Submit monthly reports of daily tubing & IA pressures and injection volumes; 4. Shut -in the well should MIT's or injection rates and pressures indicate further problems; 5. Workover and/or repair the well prior to gas injection consideration with appropriate AOGCC notification. NSK Problem Well Supervisor 12/7/2007 2 , L. ' • KRU 3N -11 �1- '' - Conoco Alaska, Inc. 3N -11 • API: 500292158000 Well Type: INJ Angle @ TS: 45 deg @ 8423 TUBING SSSV Type: NIPPLE Orig 4/13/1986 Angle @ TD: 44 deg @ 8790 (0 -8236, OD:3.500, Completion: ID:2.992) Annular Fluid: Last W /O: 11/16/2007 Rev Reason: W, ball, rod ORKOVER , RHC, PutI set - DMY Reference Log: Ref Log Date: Last Update: 12/5/2007 I Last Taq: 8578' TD: 8790 ftKB Last Taq Date: 7/30/2007 Max Hole Angle: 50 deg @ 2400 a�i t S nntn ALL STRINGS . * : . . ,:ill,''; . ,.: 4PT; ; .,, r f . , 1 ::, .. ' Description Size Top Bottom ND Wt Grade Thread ,a.2:- CONDUCTOR 16.000 0 115 115 62.50 H-40 T SUR. CASING 9.625 0 4558 3632 36.00 J -55 ill PROD. CASING 7.000 0 8777 6628 26.00 J -55 T "ubli ST jtQ..,, tJBIl ( r .. ' 4 F;: . t 4.'::::'' • 0 _ ; Y} Size Top Bottom TVD Wt Grade Thread ' IIII 3.500 0 8238 6244 9.30 L -80 EUE8rdMOD _2 X 8238 8358 6329 6.50 J-55 EUE 8RD ABM ` 1.4 - .:,51BIME l U1�.1JM .. ; arm vqi 'd i4 j;: ;' '- iis:I ;;:+ t ` 1 2.0f a '' ';`• Interval TVD Zone Status Ft SPF Date Type Comment 8420 - 8435 6373 - 6384 UNIT 15 4 8/23/1999 APERF 0 deg phase /90 deg CW MIMI D,C- 4,UNIT from lowside; 2 1/8" EJ xo B (8238 -8240, 8475 - 8490 6412 - 6423 A -3 15 8 9/26/1987 APERF 60 deg. ph; 2 1/8" Silver Jet OD:3.500) 8498 - 8502 6429 - 6432 A -2 4 8 9/26/1987 APERF 60 deg. ph; 2 1/8 " Silver Jet ia 8502 - 8503 6432 - 6432 A -2 1 9 9/26/1987 APERF 60 deg. ph; 2 1/8" Silver Jet 8503 - 8508 6432 - 6436 A -2 5 8 9/26/1987 APERF 60 deg. ph; 2 1/8" Silver Jet PBR 8508 8509 6436 - 6437 A -2 1 9 9/26/1987 APERF 60 deg. ph; 2 1/8" Silver Jet (8270 -8277, 00:2.875) = `•'1� 8509 - 8510 6437 - 6437 A -2 1 8 9/26/1987 APERF 60 deq. ph; 2 1/8" Silver Jet 8510 - 8511 6437 - 6438 A -2 1 9 9/26/1987 APERF 60 deg. ph; 2 1/8" Silver Jet 8511 - 8518 6438 - 6443 A -2 7 8 9/26/1987 APERF 60 deg. ph; 21/8" Silver Jet PKR 8523 - 8524 6446 - 6447 A -2 1 1 7/16/1986 IPERF 120 deg. ph; 4" Jumbo Jet II (8287 -8288, 8540 - 8551 6459 - 6466 A -1 11 4 6/27/1996 RPERF 180 deg. ph; Orient( + / -) 90 oD:6.151) deg F/ Lowside; 2 1/8" EJ 8551 - 8552 6466 - 6467 A -1 1 5 6/27/1996 RPERF 180 deg. ph; Orient( + / -) 90 NIP deq F/ Lowside; 2 1/8" EJ ■ (8325 -8326, Z 8552 - 8557 6467 - 6471 A -1 5 4 6/27/1996 RPERF 180 deg. ph; Orient( + / -) 90 00:2.875) deq F/ Lowside; 2 1/8" EJ TUBING 8557 - 8558 6471 - 6471 A -1 1 5 6/27/1996 RPERF 180 deg. ph; Orient( + / -) 90 (8238 -8358, deg F/ Lowside; 2 1/8" EJ OD:2.875, 8558 8560 6471 - 6473 A -1 2 4 6/27/1996 RPERF 180 deg. ph; Orient(+/-) 90 ID:z.aa >) NMI deg F/ Lowside; 2 1/8" EJ 8561 - 8562 6474 - 6474 A -1 1 1 7/16/1986 IPERF 120 deg. ph; 4" Jumbo Jet It 8565 - 8589 6476 - 6493 A -1 24 1 7/16/1986 IPERF 120 de• .. h; 4" Jumbo Jet II 4" V . _ . $ : 'r i I a R ' 7 1'. 'fi ` G Srt"77 f .. '�'i� }" ' � ` i a' �.)` il�_ld��.l��}`C�.�`,� �f- .J!�.'!~�....��,. .,, ,s .- - :���'�fU,..��;.�.._� � . .... . ..::. ?_ . F z :a.+�_ St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run VW Cmnt Pert (e475-e490) 1 8090 6140 CAMCO KBMG DMY 1.0 BK 0.000 0 1/28/200 (1) 1. 1500 s1 CSG to TBG eli (a `egt!,xx' a s : -.3P.: 7 ... or W'-:: ;4. ( ra =x Depth TVD Type Description ID Pert 31 31 HANGER FMC TUBING HANGER 3.500 (8502-8503) 531 531 NIP CAMCO 'DS' NIPPLE (2.856" LOCK) set 11/14/2007 2.812 Pert 8144 6178 PBR/SBR BAKER 80-40 PBR set 11/14/2007 2.970 (8498-8518) 8158 6188 PACKER BAKER FHL RETRIEVABLE PACKER set 11/14/2007 2.980 8200 6218 NIP CAMCO 'D' NIPPLE set 11/14/2007 2.750 8238 6244 XO CROSSOVER FROM NEW 3.5" TBG TO ORIGINAL 2.875" TUBING @ 2.875 Perf OVERSHOT set 11/14/2007 (8508 -8509) 8240 6246 Overshot BAKER POORBOY OVERSHOT set 11/14/2007 2.480 8270 6267 PBR Brown 2.500 Pert 8287 6279 PKR Brown 'HB' 3.000 (8523 -8524) 8325 6306 PLUG 2.25" CA -2 Blanking PLUG set 7/23/2007 @ 8325' RKB 0.000 8325 6306 NIP Camco 'D' Nipple NO GO 2.250 Perf 8357 6329 SOS Brown 2.441 (8540 -8560) 8358 6329 TTL 2.441 Perf - ..;�..< ,�5�, � -:,,� . . . � _ r� j.:.. u:a.:4�` r}";` ` . k."eix.T:' - ',ji i:: _ - ::., - : r -t,_x N'_°. , 4: r ' r �y�i...-i _ .- . v '.it (8551 -8552) .�',.� �����"' " ^:.+ ��'- `�i{na�., «, ` -; ;;�.;, _. �:. ;.,, .:..... ,. ^; ' «�1 - +... f.;.a�if .%�r .+ r Depth Description Comment Perf 8571 1" BK Latch Ring Lost in Hole; May be laying in one of Lower GLM (8565-8589) 1 3N-11 PTD 186-077 Regg, James B (DOA) Page 1 of 1 • From: NSK Well Integrity Proj [N1878@conocophillips.com] Sent: Friday, December 21, 2007 12:49 PM To: Regg, James B (DOA}; Maunder, Thomas E (DOA} Cc: NSK Problem Well Supv Subject: 3N-11 PTD 186-077 ~c~ ~~ ~2..11~7 Jim Here is the most recent T/I/O for 3N-11 (PTD 186-077). The well is currently SI with a TTP waiting for AA approval CHOKE FTP FTT ~ ............._.... IAP OAP 2~aa 2000 1 ~a0 ri 10x0 ~aa a 01-Jan-07 TJIIC~ Plot - ~-11 ` ~)~ Let Brent or I know if need any additional information MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7043 Cell Phone (907) 943-1687 12!21 /2007 a1-Mar-07 a1-PAati}-07 a1-Jul-a7 a1-Sep-07 a1-Nov-a7 date P ~ ~ i ~~~ -o ~~ T/l/0 Plat - 3N-11 2~oa 2000 100 1000 Sao 0 ~.........I ...............IF...........II.{..F...................y.....t~.....................................~ 200 1~0 1,.........J ............. I..I................................I................................. ................... 1 ........I ...............................I.{.........................L..............~,~........... ~ ~.1........f..14 ................................~f...............i......~............t..................i.~.......1.... ..~ 100 ~, Y ~0 .q ......................................r`,~............................. .....,.~ ........ ...... ...... ., , ~_. r' ~ , ~ r' r•, ~ '. ~ ~- .- ~,. ~, . ~, ~ ~' '_•' I `' i" ~~ ~~ ~ ~~ ~ ,, ~, , ! ~' 0 01-Jan-O? 01-Mar-O~ 01-May-O~ 01-Jul-07 Date 01-~~~-o~ 01-~vo~-o~ 3N- I 1 MIT-T's & MITIA's ~ ~ Page 1 of 1 Regg, James B (DOA) j j-ij I ~ -- ~; ~~ From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Ruesday, DecBmber 18, 2007 3:41 PM ~~~~~ I~1~~ ~`~~~ To• egg, Ja es (DOA) Cc: Fleckenstein, Robert J (DOA) Subject: RE: 3N-11 MIT-T's & MITIA's Attachments: MIT KRU 3N-11 11-16-07.x1s Sorry far the confusion generated on my part. I talked to the rig supervisor about their standard practice, reinterpreted the pressure test chart, and have edited the form to refilect the changes. Martin From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Tuesday, December 18, 2007 11:43 AM To: NSK Problem Well Supv Cc: Fleckenstein, Robert J (DOA) Subject: RE: 3N-11 MIT-T's & MITIA's Thank you for the MITs. Should the initial test pressure for 11-16-07 MITIA be 2275psi instead of 1700 psi? Jim Regg AOGCC off, ~+~~~~~' 1~~ f) t~ ~~ 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Tuesday, December 18, 2007 10:44 AM To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); Fleckenstein, Robert J (DOA); DOA AOGCC Prudhoe Bay; NSK Problem Well Supv Subject: 3N-11 MIT-Ts & MITIA's «MIT KRU 3N-11 11-28-07.x1s» «MIT KRU 3N-11 11-16-07.x1s» Jim, As per our conversation, I have attached the MIT-T's and MIT-OA's for the 3N-11 well on 11/16/07 and 11!28/07. Please contact me at 907-659-7224 if you would like to discuss further. Martin Walters CPAI Problem Wells Supervisor 12/18/2007 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.Fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov 1 OPERA70R: ConocoPhillips Alaska Inc. ;~~j ~(, FIELD /UNIT /PAD: Kuparuk/ KRU/ 3N-11 DATE: 11116/07 OPERATOR REP: Randall Dolcater AOGCC REP: Packer De th Pretest Initial 15 Min. 30 Min. Well 3N-11 T e Inj. N TVD 6,182' Tubing 0 2,600 2,570 2,550 Interval O P.T.D. 1860770 T e test P Test si 1546 Casing 0 50 50 50 P/F P Notes: Non witnessed MITT post RWO for AA OA 0 0 0 0 Well 3N-11 T e In~. N TVD 6,182' Tubing 1,700 2,275 2,275 2,275 Interval O P.T.D. 1860770 T e test P Test si 1546 Casing 50 2,625 2,625 2,625 P/F P Notes: Non witnessed MITIA post RWO for AA OA 0 0 0 0 We11 T pe In~. TVD Tubin Interval P.T.D. T e test Test psi Casin P/F Notes: OA Well T pe Inj. TVD Tubing Interval P.T.D. T pe test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. T pe test Test si Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I = Industria{ Wastewater N =Not Injecting W = Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test 0 INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 2007-1116_MIT_KRU_3N-11_MITIA.xIs • ~ SARAH PALIN, GOVERNOR ~ ~~ ALA58A OII, A1~TD ~jP ~ 333 W 7th AVENUE, SUITE 100 COrT5ERQA~'IOlY COM1~II55IO1tiT ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Brett Packer Wells Group Engineer Conoco Phillips Alaska, Inc ~~~~.~ N~~~ ~ • ~~~~ PO Box 100360 Anchorage, Alaska 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3N-11 Sundry Number: 307-331 Dear Brett 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 c7 day of November, 2007 Encl. ~.~ ~ ,~~~ Sincerely, • • ConocoPhillips P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 25, 2007 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7~` Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: R~c~~ OC1" ~ ~ ~~?~~ Alaska Oil & Gas ~nns~ ~tit~n~rissian Anchq~a ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk We113N-11 (PTD# 186-077). Injection well 3N-11 was completed in 1986 originally as an A-sand producer. It produced approximately 700 bopd for about a year before its conversion to injection in October 1987. The well has been on water injection ever since. In August 2002, the well failed anMIT-IA and aone-way leak was discovered right above the packer. Several attempts to patch the leak were made, but to no avail. Efforts to patch the leak were abandoned in July 2004, and it was decided to pump abarite/sand slurry down the IA to settle out on top of the packer. Following this procedure, the well passed an MIT-T and MIT-IA. The well continued to pass MIT-IA's with the barite/sand plug in the IA through 2005. In March 2006, tbg x IA communication was found once again indicating the barite/sand plug was no longer holding. ~ The well had to be shut in due to lack of two barriers. A downhole video log shows a leak right above the packer, either in the crossover between the packer and PBR, or somewhere in the lower part of the PBR. Due to the location of the leak, and the likelihood that the tubing will not come free anyway at maximum overpull, we will cut the tubing pre-rig, pull the tubing above the PBR, and stack a packer to restore competency to the tubing and IA, thus restoring two barriers and allowing the well to continue injection. ,~ ., J ~ ryy„~ i ~1 ~ s--~r rte, (~~, P ~C~ ~ ~ pa t d' ~ C A recent SBHP in July showed a pressure of 3665 psi @ 6433' TVD. This equates to 11.0 ppg EMW at mid-perf (6433' TVD). Following the SBHP, a plug was set in the `D' nipple at 8325' MD and a combo MIT passed indicating casing and packer integrity as well as reservoir isolation. Since we are isolated from the formation, 9.6 ppg brine will be used during the workover. The purpose of the proposed workover will be to pull the old J-55 2'/g" tubing above the PBR, stack a packer, and replace it with new 3'h" L-80 tubing. Attached is a proposed schematic along with a general f 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 ORIGINAL ~ ,o7'S ~~/s/7 ~x- aGrFivFn STATE OF ALASKA (~ - ~+ ALASKA OIL AND GAS CONSERVATION COMMISSION (~7 ~~T ~ ~ ~~~~ APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.2ao Alaska [lil ~ Cr~t ions. ~I~mmission 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ 'Waiver ~I1~fr8~Q Other ^ Alter casing ^ Repair well ^/ ~ Plug Pertorations ^ 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 ^ 186-077 ' 3. Address: Stratigraphic ^ Service 0 ~ 6. AP{ Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21580-00 ` 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 Q 3N-11 ' 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25512 "ALK2553 RKB 68' Kuparuk River Field /Kuparuk Oil Pool ' 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth M~ (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8790' - 6637' 8578' 6486' 8325' 8571' 1" BK Latch Ring Casing Length Size MD TVD Burst Collapse CONDUCTOR 115' 16" 115' 115' SUR. CASING 4490' 9-5/8" 4558' 3632' PROD. CASING 8709' 7" 8777' 6628' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8420'-8589' 6373'-6493' 2-7~8" J-55 8358' Packers and SSSV Type: Packers and SSSV MD (ft) pkr-- BROWN 'HB' pkr= 8287' SSSV= Baker'FVL' SSSV= 1835' 13. Attachments: Description Summary of Proposal 0 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-Nov-2007 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ 0 WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Brett Packer @ 265-6845 Printed Name Brett Packer ~ ~ Title: Wells Group Engineer Signature ,..., ~ Phone 265-6845 Date Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representat ive may witness -33 Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ~ Location Clearance ^ Other: S~~~L ~r~rS~~~~~ ~ S ~ ~ t ~S®~ eS~ +I`'~rr\ `r`tvv~--~~~~ ~~~ Subsequent Form Required: ~...`® INAL APPROVED BY ~ Approved by: OMMISSIONER THE COMMISSION Date: ~~ J ! Form 10-403 Revised 06/2006 ~ ~~~ ~ ~ ~"'~ , (~sil~f $) ?I~01 Submit in uplicat •r- f a7 • ~~ ConocoPhillips Alaska, Inc. KRU 3N-11 ~-' +~riiiii Well: 3N-11 2007 RWO PROPOSED COMPLETION API: 500292158000 PTD: 186-077 Wellhead: FMG Gen IV X-mas Tree: 3-1/8", 5K psi Lift Threads: 3%" EUE 8rd BPV: FMC 3%"'IS-A' Proposed 3%" Completion • Tubing = 3%", 9.3 ppf, L-80, EUE 8rd Mod . 2.813" DS-nipple at 500' • Baker PBR seal assy. at 8165' • Baker 3'/" x 7" FHL packer at 8180' . 2.75" D-nipple at 8215' • Po-boy overshot at 8250' over stub of 2'/8' tubing Existing 2%8' Completion . Tubing = 2'/8", 6.5 ppf, J-55, EUE 8rd AB-Mod Stub at ±8250' MD (proposed) • Brown PBR at 8270' • Brown 'HB' packer at 8287' • Camco 2.25" D-nipple at 8325' Directional: Max Incline: 49.9° @ 2400' MD Max Dogleg: 4.8°/100' @ 2000' MD Conductor: 16", 62.5#, H-40 at 115' Surface Casing: 9.625", 36#, J-55 at 4558' Production Casing: 7", 26#, J-55 at 8777 Gas Lift Mandrels: MD TVD Type 8130 6168 1" KBMG--DMY Pert Zones UNIT D, C-4, B-1: 8420' - 8435' (4 spf) A3: 8475' - 8490' (8 spf) A2: 8498' - 8523' (8 spf) A1: 8540' - 8589' (4 spf) Fill at: 8578' RKB Last Updated: 26-Oct-07 TD: 8,790' RKB Updated by: JBP • 3N-11 Kuparuk Injector General Workover Procedure Pull 2 % " tbg., stack packer, and replace w/ 3 % " tbg. 1. Chemical cut tubing pre-rig. 2. Circulate 9.6 ppg brine pre-rig. 3. MIRU Nabors 3S. 4. Pull BPV, verify well is dead, set BPV. 5. ND tree, install blanking plug, NU and test BOP. +•~---~ ~ ,P"~ Q~ C'G.N~S ~ \ ~~~ ,~, ~ Grrc~v~~. 6. Remove blanking plug and BPV. ~ ~~ O ~~ ` ~,~~„~~ J~ ~~,~ ~g 7. Pull and lay down old 2'/8" tubing. 8. Run new 3'h" tubing with 2'/8"po-boy overshot, packer, and seal assembly. ~~j~y 9. Locate tubing stub, spot inhibited brine, overshot tubing stub, set packer, shear PBR and pull up. ~ / 10. Space out and land completion. ~~/~ 11. Pressure test tbg and IA. Shear SOV. 12. Set two-way check. ~ h©~i~~~,~~~~~~ ~ ~`~ES~ 13. ND BOP, NU and test tree. 14. Pull two-way check, set BPV. ~~~~~~`~ ~ ` ~ S 15. RDMO 1R-20 (PTD 191-108) public file ~ Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Saturday, November 03, 2007 12:44 PM To: 'Cynthia Mciver' Cc: Davies, Stephen F (DOA) Subject: RE: LF File 186-077 (again) 1 have some additional messages to add to the file and the beginning portion is pretty disorganized. Talk to you next week. Tom From: Maunder, Thomas E (DOA) Sent: Saturday, November 03, 2007 11:35 AM To: 'Cynthia Mciver' Cc: Davies, Stephen F (DOA); 'Jody J Colombie' Subject: RE: LF File 186-077 i have reviewed the subject well file and have the following recommendation. Page 9 is a copy of an email with hand notes that Jim and I exchanged. It is marked "This copy not for file." Please examine and see if you concur that it should be removed. The notes on the document involve the internal process employed to determine the course of action and I don't believe it~should be included in the file. Tom ~~~1 N0~ ~. ~ 2flD7 11 /3/2007 3N-11 (PTD 186-07?) SC le~eport Maunder, Thomas E (DOA) From: NSK Problem Welt Supv [n1617@conocophi}lips.comj Sent: Thursday, March 30, 2006 5:56 PM To: Thomas Maunder; James Regg Subject: 3N-11 {PTD 186-077) SG teak Report Attachments: 3N-11 TIO 90 day plot 3-30-06.gif; 3N-11.pdf Tom & Jim, Page 1 of 1 A surface casing leak was discovered today on 3N-11 during DHD diagnostics. The well was suspect for a surface casing leak due to a failed MITOA in 2004 and sustained low OA pressure and scheduled for diagnostics. Diagnostics were performed in a controlled environment pumping into the QA and taking returns off the conductor to a drum with a vac truck on site. No fluids were spitted to the well cellar gravel. A pit liner wilt be installed in the cellar to prevent any spills. The welt wilt be Si and secured with a tbg fait plug as this well also has Tx1A Comm as previously reported to AOGCC (sundry approval #304-299j. Additional diagnostics well be completed to evaluate if this is an excavation repair candidate. Attached is a schematic and 90 day T/I/O plots. Please let me know if there are any questions. Marie McConnell Problem Well Supervisor 659-7224 «3N-11 TIO 90 day plot 3-30-06.gif» «3N-11.pdf» ~( f(-~~~~~-,~~~ ~~al 'fit 11 /3/2007 ) ) 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;Jim_Regg@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. KRU 3N-11 07/03/05 Arend I Rogers AES Packer Depth Well 3N-11 Type Inj. S TVD 6,279' Tubing P.T.D. 1860770 Type test P Test psi 1570 Casing Notes: Waiver compliance MIT, Sundry 304-299 Pretest 2850 2550 Initial 15 Min. 30 Min. 2850 2850 2850 3350 3220 3150 Interval P/F o P Well Type Inj. TVD Tubing Interval P.T.D. Type test T est psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test T est psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test T est psi Casing P/F Notes: Test Details: SCAj"NED ~JUL O? 2005 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 T = Test during Workover o = Other (describe in notes) MIT Report Form Revised: 06/19/02 MIT KRU 3N-11 07-03-05.xls ~ . ------ AI,ASIiA. OILAlWD GAS CONSERVATION COMMISSION I ¡ / / ì ¡ / FRANK H. MURKOWSKI, GOVERNOR ~"[!Æ1JŒ lill~ !Æ~!Æ~[ß!Æ 333 W. 7fH AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 August 23, 2004 ~ Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk 3N-ll 304-299 Dear Mr. Dethlefs: 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 23rd day following the date of this letter, or the next working day if the 23rd day t. so a holiday or weekend. Enclosure ~ ~ Conoc~ ill i pS Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 f1 f\ '[ ¡\ .< J ¡L ,I (y '¿¡JO4 July 28, 2004 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK. 99501 Dear Mr. Maunder: Enclosed please find 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 3N-l1. The Sundry regards continued injection after a repair on the well. Please call Marie McConnell or me at 659-7224 if you have any questions. Sincerely, f/~c ~ Jerry Dethlefs Problem Well Supervisor Attachments OR \ G\ NAL ~. ~ ~~ STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 ¡ i : fì (1 1. Type of Request: Abandon D Suspend D Operation Shutdown D Perforate D Variance 0 Annular Disp. D Alter casing D Repair well D Plug Perforations D Stimulate D Time Extension D Other D Change approved program D Pull Tubing D Perforate New Pool D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development D Exploratory D 186-077 3. Address: Stratigraphic D Service 0 6. API Number: P. O. Box 100360 50-029-21580-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 68' 3N-11 8. Property Designation: 10. FieldlPool(s): Kuparuk River Unit Kuparuk Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (It): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8790' 6637' Casing Length Size MD TVD Burst Collapse CONDUCTOR 115' 16" 115' 115 SUR. CASING 4490' 9-5/8" 4558' 3632 3520 2020 PROD. CASING 8709' 7" 8777' 6628 4980 4320 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8420-8435,8475-8490,8498-8523,8561-8589 6373-6384,6412-6423,6429-6446,6459-6493' 2-7/8" J-55 8358' Packers and SSSV Type: Packers and SSSV MD (ft) pkr= BROWN 'HB' pkr= 8287' SSSV= SSSV SSSV= 1835' 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program D BOP Sketch D Exploratory D Development D Service 0 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: Immediately Oil D Gas D Plugged D Abandoned D 16. Verbal Approval: Date: WAG D GINJ D WINJ 0 WDSPL D Tom Maunder 07/16/04 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Dethlefs/McConnell @ 659-7224 Printed Namd Jerry Dethlefso ~ Title: Problem Well Supervisor Signature ~ C " \ Phone 659-7224 Date '7 b .; V'" /' V Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ~-~ Plug Integrity D BOP Test D Mechanical Integrity Test gJ Location Clearance D Other: ~"\~ ~'f.-\- ~\)Q: ~~\'1 X)()~ ~~\\'i ~~~ ~ ~~"'\'1 ~~~~ ()~ ~\tt.~~~~S~~~ . Subsequent Form Requ d: AIJ623 700~ ~~ RBDII8 SF L ø BY ORDER OF &'í zJ !ÍJ ~ '- Approved 'f¡y: COMMISSIONER THE COMMISSION Date: f.--' '-../ .../ '" ---- I / ' - Form 10-403 Revised 2/2003 . ORIGINAL SUBMIT IN DUPLICATE ~ ~ ConocoPhillips Alaska, Inc. Kuparuk We1l3N-ll (PTD 1860770) SUNDRY NOTICE 10-403 REQUEST FOR VARIANCE 07/28/04 This Sundry request for variance is for continued water injection after repairs to fix T x IA communication. Kuparuk we1l3N-ll was reported to have T x IA communication to the AOGCC 8/5/02. The leak rate was measured at 1.8 gpm @ 3000 psi. A video log identified a leak in the tubing near the packer @ 8285' md. The PBR is immediately above the leak point, so patching entails a sliding assembly to move with the tubing. On 4/17/04 a retrievable tubing patch was set over the leak. An MIT was performed three times, each time failing by a small margin due to linear leak off (previously reported). The tubing patch did not fix the leak and the patch was removed from the well. On 07/09/04 a slurry of barite and sand was displaced into the IA to seal the leak from the IA side. A 10.5 ppg brine and diesel freeze protect was spotted on the solids pill. This type of slurry is expected to provide an effective barrier for fluid migration. Pressure tests during the wellwork indicated the leak was sealed, and a follow-up MIT passed @ 2700 psi (submitted previously and attached). A trend plot of wellhead pressures for a 2-week period is attached. ConocoPhillips proposes the following plan: 1. Approval for continued water-only injection; 2. Report daily injection rate, injection pressure, and annular pressures on Monthly Failed MIT report; 3. Conduct 2-year MIT-IA tests to verify the leak continues to be isolated; 4. Review well status with the AOGCC and file applicable Sundry Notices should wellhead pressures indicate the repair has failed. ~ ~ 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 3N-11 07/15/04 Brake / Rogers 0 P Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: 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 MIT KRU 3N-11 7-15-04.xls 7/20/2004 • Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Tuesday, July 20, 2004 10:40 AM To: Tom Maunder AOGCC (E-mail); Jim Regg AOGCC (E-mail); Bob Fleckenstein AOGCC (E- mail) Subject: 3N-11 (PTD 186-077) MIT data. Attachments: MIT KRU 3N-11 7-15-04.x1s ~~~ MIT KRU 3N-11 7-15-04.x1s (2 K... Bob, Tom, & Jim, Attached are the results of a diagnostic MIT for 3N-11 (PTD 186-077) completed 7/15/04. The MITIA passed. Previous reported MITIAs had failed due to a tbg leak just above the packer. A 5 bbl sand/barite pill was place on the packer on 7/9/04. Diagnostics by SL while pulling the tbg tail plug and this passing MIT show the sand/barite pill is working. A 10-403 will be submitted for approval to inject. After verbal approval was obtained from Tom on 7/16, the well was BOI on 7/17. The IA pressure has not increased above 2000 psi. Previously, the IA could not be kept under 2000 psi when on line. On 7/19/04 T/I/O = 1983j1700/ 50 with an injection rate of 1277 BWPD. Please let me know if you have any questions. Marie McConnell Problem Well Supervisor 659-7224 «MIT KRU 3N-11 7-15-04.x1s» ~~~ Lvov ~ Q zao~ 1 Re: 3N-ll (PTD 186-077) ( ( Subject: Re: 3N-ll (PTD 186-(77) . From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Wed, 16 Iun 2004 11:02:34-0800 Jerry, Jim and I talked and we are in agreement that a sundry is not required for this type of work. of the work (404) should be done and then the subsequent MIT. Tom Maunder, PE AOGCC A report NSK Problem Well Supv wrote: Jim: While Tom is gone I will send this through you. 3N-11 injector has a leak at the PBR, and multiple attempts to patch it have failed. I am going to try a solids slurry placed in the IA to plug the leak from the annulus side. The slurry is a sand/barite mix that will cover the PBR by approximately 25 feet. Brine will be placed on the slurry with a diesel freeze protect cap. My question is whether a 10-403 is required for this work since no mechanical change is being made to the well. Not a problem if so--just trying to follow the rules. Thanks for the feedback. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7224 -----Original Message----- From: Thomas Maunder [rnailto:tom maunder@admin.state.ak.us] Sent: Tuesday, June 01, 2004 7:24 AM To: NSK Problem Well Supv Subject: Re: 3N-11 (PTD 186-077) disregard 10-403 application dated 4/21/04 Thanks Marie, I will have the present 403 will look for another 403. Tom Maunder, PE AOGCC canceled. As you get new information, we NSK Problem Well Supv wrote: Tom, After reviewing 3N-11 with Jerry, the plan forward has changed. Please disregard the 10-403 submitted on 4/21/04, the plan for repairing this well has been modified. An honest attempt has been made to patch the tbg leak¡ however, TxIA comm exists post patch based on MITIA results and wellhead pressure trends. Due to the difficulty of setting a patch across the PBR at 8270, the patch will be removed. Diagnostics will be performed to confirm IA and packer integrity and a new 10-403 will be submitted. Diagnostic plan: 1. Pull retrievable patch lcl2 6/16/2004 12:37 PM Re: 3N-ll (PTD 186-077) 2. Set TTP 3. MITIA with TTP (CMIT) to verify IA and Pkr integrity 4. Submit 10-403 based on diagnostics. Please let me know if you have any questions. Marie McConnell Problem Well Supervisor 659-7224 20f2 6/16/2004 12:37 PM 1Ze: I~uparul$ Injection We113N-13 Failed MIT Subject: Re: Kuparuk Injection We113N-13 Failed MIT From: Thomas Maunder <tom maunder@admin.state.ak.us> Date: Thu, 20 May 2004 09:59:57 -0800 To: NSK Problem Well Supv <n1617@conocophillips.com> CC: "Jim Regg AOGCC (E-mail)" <jim_regg@admin.state.ak.us> Jerry, Not sure if anyone got back to you. Your diagnostic plan is acceptable. On your tests, it doesn't appear that there is a lot of differential between the tubing and IA. I guess with the pressure losses you show and not much differential that you likely shouldn't have a problem locating the leak. Keep us informed of your determinations. Tom Maunder, PE AOGCC NSK Problem well Supv wrote: Tom: Kuparuk water injection «MIT KRU 3N-13 05-15-04.x1s » well 3N-13 (PTD 1860810) failed an MIT on 5/15/04. The well has been internally waivered for minor T x IA communication and the MIT failed during the scheduled compliance test. The MIT data is attached. CPAI proposes the following plan: 1. Keep the well on water-only injection while diagnostics are performed; 2. Add the well to the monthly failed MIT report; 3. Set a tubing plug and perform leak rate tests to determine if tubing or packer leak; 4. Perform video leak detect log if appears to be tubing leak; 5. Submit 10-403 with repair or variance plan as needed depending on diagnostic results. Please let me know if you approve of our plan and let me know if you have any questions. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7224 1 of 1 8/2/2004 4:12 PM -~ 1. Type of Request: Abandon 0 Alter casing 0 Change approved program 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 68' 8. Property Designation: Kuparuk River Unit 11. Total depth MD (ft): 8790' Casing CONDUCTOR SUR. CASING Total Depth TVD (ft): 6637' Length 115' PROD. CASING 4490' 8709' I'"'. r-.., STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operation Shutdown 0 Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: Suspend 0 Repair well 0 Pull Tubing 0 Perforate 0 Stimulate 0 Re-enter Suspended Well Time Extension Other 0 50- 9-21580-00 9. Well Name and N 3N-11 10. Field/Pool( : Kuparuk Oil 001 PRESENT")!:Ll CONDITION SUMM Y Effective Depth MD (ft): 1Effective ~ TVD (ft): Plugs (m sured): Size 17 MD TVD 16" \9 115' / 115 9.518" J 455.. ~ 3632 7" \;J~ 7 7' \S 6628 -!Y \~\ PerfOrati epth TV : ckers and SSSV MD (ft) \ kr= 8287' SSSV= 1835' 13. Well Class after proposed work: Exploratory 0 Development 0 15. Well Status after proposed work: Oil 0 Gas 0 WAG 0 GINJ 0 Development Stratigraphic 0 0 Exploratory 0 Service 0 Perforation Depth MD (ft): 8420.8435,8475-8490,8498-8523,8561.8589 Packers and SSSV Type: pkr= BROWN 'HB' SSSV= SSSV 12. Attachments: Description Summary of Proposal Detailed Operations Program 0 BOP Sketch 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Tubing Size: 2-7/8" 17. I hereby certify that the foregoing is true an correct to the best of my knowledge. Printed Name ~erry D~t~fSC Signature 7~ Contact: Title: Phone 659-7224 Conditions of approval: Notify Co mission so that a representative may witness Plug Integrity 0 Other: Approved by: Form 10-403 Revised 2/2003 . Mechanical Integrity Test 0 Location Clearance f1IPIIò 9f\. O?> ')1\~h \p' ~ Junk (measured): Burst Collapse 3520 4980 2020 4320 Tubing Grade: J-55 Tubing MD (ft): 8358' Service 0 Plugged 0 WINJ 0 Abandoned 0 WDSPL 0 Dethlefs/McConnell @ 659.7224 Problem Well Supervisor Date ~ Ýtrs/ SUndry Numbe3?;i;.)-11¡' 0 RECEIVED APR 2 2 2004 Alaska Oil & Gas Cons. Commission Anchorage COMMISSIONER BY ORDER OF THE COMMISSION O~'G\NAL Date: SUBMIT IN DUPLICATE I'"'. ~ ConocoPhillips Alaska, Inc. Kuparuk We1l3N-ll (PTD 1860770) SUNDRY NOTICE 10-403 REQUEST FOR VARIANCE 04/21/04 This Sundry request for variance is for continued water injection with a failed MIT. Kuparuk well 3N-ll was reported to have T x IA communication to the AOGCC 8/5/02. The leak rate was measured at 1.8 gpm @ 3000 psi. A video log identified a leak in the tubing near the packer @ 8285' md. The PBR is immediately above the leak point, so patching entails a sliding assembly to move with the tubing. On 4/17/04 a retrievable tubing patch was set over the leak. An MIT was performed three times, each time failing by a small margin due to linear leak off (see attached form). The tubing and IA do not appear to be tracking at this time. ConocoPhillips proposes the following plan: 1. Approval for continued water-only injection for a period of 2-years; 2. Report daily injection rate, injection pressure, and annular pressures on Monthly Failed MIT report; 3. Conduct 2-year MIT-IA tests to verify leak rate does not change substantially over time; 4. Review well status with the AOGCC and file applicable Sundry Notices should alternative repairs be performed. Note: With the patch in place a tubing plug cannot be set to test the casing. Should the patch be removed from the well a tubing plug will be set for the required MIT. I'"'. ~ 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.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. KRU 3N-11 04/20104 Brake / Rogers NA . Packer Depth Pretest Initial 15 Min. 30 Min. well 3N-11 I Type Inj Is I T.V.D. I 6279 I Tubing 184O 11840 11840 11840 I Interval I 0 P.T.D. 1860770 Type Test P Test psi 1570 Casing 1000 2500 2420 2320 P/F F Notes: Post patch MIT as per Sundry 303-265, attempt #1 well 3N-11 I Type Inj Is I T.V.D. I 6279 I Tubing I P.T.D. 1860770 Type Test P Test psi 1570 Casing Notes: Post patch MIT as per Sundry 303-265, attempt #2 well 3N-11 I Type Inj Is I T.V.D. I 62791 Tubing I P.T.D. 1860770 Type Test P Test psi 1570 Casing Notes: Post patch MIT as per Sundry 303-265, attempt #3 weill P.T.D. Notes: I Type Inj I Type Test I T.V.D. I I Tubing I Test psi 1500 Casing 1840 1840 1840 I 1840 !Interval 0 2320 2500 2480 2450 P/F F 1840 I 1840 I 1840 1840 Interval 0 2410 2500 2490 2480 P/F F Interval P/F Interval P/F Well! P.T.D. Notes: I Type Inj I Type Test I T.V.D. I I Tubing I Test psi 1500 Casing 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 MIT KRU 3N-11 04-20-04.xls 4/21/2004 sssv (1835-1836, 00:2.875) PBR (8270-8271, 00:2.875) PKR (8287-8288, 00:6.151) NIP (8325-8326, 00.2.875) TUBING (0-8358, 00:2.875, 10:2.441) Perf (8475-8490) Perf (8502-8502) Perf (8508-8508) Perf (8498-8518) Perf (8523-8523) Perf (8540-8560) Perf (8565-8589) I'"'. ConocoPhillips Alask~J Inc. ,3N"11<;: ¡if ¡if , ,,¡¡ 3: ..~ ~;""....,...,....,...,...............,..."...."......,.,...,.',i,¡,~,.' , 7',' . if - =-= I API: 500292158000 SSSV Type: LOCKED OPEN Annular Fluid: - Reference Loç¡: Last Tag: 8587 Last Tag Date: 6/5/2003 .9à$lng;Strîngî;¡î ¡JiL SiJ!RINGS Description CONDUCTOR SUR. CASING PROD. CASING 1I'ubinlííStfiiii:l:i';tUBIIíIG. - Size ] Top bÀ",',' ""T2,""",..."~,'?'~',"',,,s, "','" ,'" 0 I";;vnora..ons. ummalY. Interval TVD 8420 - 8435 6373 - 6384 8475 - 8490 8498 - 8502 8502 - 8502 8502 - 8508 8508 - 8508 8508 - 8510 8510 - 8510 8510 - 8518 8523 - 8523 8540 - 8551 6412-6423 6429 - 6432 6432 - 6432 6432 - 6436 6436 - 6436 6436 - 6437 6437 - 6437 6437 - 6443 6446 - 6446 6459 - 6466 8551 - 8552 6466 - 6467 8552 - 8557 6467 - 6471 8557 - 8558 6471 - 6471 8558 - 8560 6471 - 6473 ~. KRU 3N-11 Well Type: INJ Orig 4/13/1986 Completion: Last W/O: Ref Log Date: TD: 8790 ftKB Max ~ole An~I;: 50 ~~@ 2400 Bottom 115 4558 8777 Angle @ TS: 45 deg @ 8423 Angle @ TD: 44 deg @ 8790 Rev Reason: Lock Open SS8V Last Update: 1/29/2004 TVD 115 3632 6628 Wt 62.50 36.00 26.00 Grade H-40 J-55 J.55 Thread 8561 - 8562 6474 - 6474 8565 - 8589 6476 - 6493 Gà$:LjfttMandrel$Nalve$ St MD TVD Man Man Type V Mfr V Type V OD Latch Mfr 1 2586 2279 Merla TMPD 2 4848 3829 Merla TMPD 3 6188 4776 Merla TMPD 4 6965 5343 Merta TMPD 5 7376 5637 Merla TMPD 6 7820 5950 Merla TMPD 7 8226 6236 MMH 27/8 X 1.5 Othè¡,,;{plugs¡;e( ûlP;..è(C:f~ JEWELRY Depth TVD Type 1835 1762 SSSV 8270 6267 PBR 8287 6279 PKR 8325 6306 NIP 8357 6329 80S 8358 6329 TTL FI$h - FISH' . , Depth I Description 8571 1" BK Latch Rinf GeneÍ'ål NòìEÍ$ " . . Date I Note 9/24/2002 TBG LEAK FOUND @ 8285' WITH N2 VIDEO LOL. Size Top 16.000 0 9.625 0 7.000 0 , ,.., Bottom 8358 Zone Status UNIT D,C-4,UNIT B A-3 A-2 A-2 A-2 A-2 A-2 A-2 A-2 A-2 A-1 A-1 A-1 A-1 A-1 A-1 A-1 I Grade J-55 Thread EUE 8RD ABM ,"";;;.' . Ft SPF Date Type Comment 15 4 8/23/1999 APERF 0 deg phasing/90 deg CW from lowside; 2 1/8" Enerjet 15 4 0 6 0 2 0 8 0 11 8 9/26/1987 APERF 60 deg. ph; 2 1/8" Silver Jet 8 9/26/1987 APERF 60 deg. ph; 2 1/8" Silver Jet 9 9/26/1987 APERF 60 deg. ph; 21/8" Silver Jet 8 9/26/1987 APERF 60 deg. ph; 21/8" Silver Jet 9 9/26/1987 APERF 60 deg. ph; 21/8" Silver Jet 8 9/26/1987 APERF 60 deg. ph; 2 1/8" Silver Jet 9 9/26/1987 APERF 60 deg. ph; 21/8" Silver Jet 8 9/26/1987 APERF 60 deg. ph; 21/8" Silver Jet 1 7/16/1986 IPERF 120 deg. ph; 4" Jumbo Jet II 4 6/27/1996 RPERF 180 deg. ph; Oriented (+/-) 90 deg F/ Lowside; 2 1/8" EnerJet 5 6/27/1996 RPERF 180 deg. ph; Oriented (+/-) 90 deg F/ Lowside; 2 1/8" EnerJet 4 6/27/1996 RPERF 180 deg. ph; Oriented (+/-) 90 deg F/ Lowside; 2 1/8" EnerJet 5 6/27/1996 RPERF 180 deg. ph; Oriented (+/-) 90 deg F/ Lowside; 21/8" EnerJet 4 6/27/1996 RPERF 180 deg. ph; Oriented (+/-) 90 deg F/ Lowside; 2 1/8" EnerJet 7/16/1986 IPERF 120 deg. ph; 4" Jumbo Jet" 7/16/1986 IPERF 120 dl!Q' ph; 4" Jumbo Jet II 5 2 1 24 DMY DMY DMY DMY DMY DMY DMY Port TRO Date Run 0 10/24/1987 0 10/24/1987 0 10/24/1987 0 7/16/1986 0 10/24/1987 0 10/24/1987 0 7/6/1996 Vlv Cmnt 1.0 1.0 1.0 1.0 1.0 1.0 1.5 BK BK BK BK-2 BK BK RK 0.000 0.000 0.000 0.000 0.000 0.000 0.000 Description Baker 'FVL' (LOCKED OPEN 1/27/2004) Brown Brown 'HB' Cameo 'D' Nipple NO GO Brown --=- ID 2.310 2.500 3.000 2.250 2.441 2.441 l Comment Lost in Hole; May be laying in oneof Lower GLM I"""". ~ ~ ConocoPh ¡IIi pS Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Apri121,2004 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a 10-403 Sundry Notice request for ConocoPhillips Alaska, Inc., we1l3N- 11. The Sundry is for approval to continue water injection with a failed MIT. A proposal discussion document and well schematic are attached. Please call Marie McConnell or me at 907-659-7224 if you have any questions. Sincerely, f~c~ Jerry Dethlefs ConocoPhillips Problem Well Supervisor Attachments RECEIVED APR 2 2 2004 . ion A\aska 0\\ & Gas Cons. Corom!ss Anchorage OR\G\N~L Re: 3N-II (PTD 186-077) disregard 10-403 application dated 4/21/04 Subject: Re: 3N-ll (PTD 186-077) disregard 10-403 application dated 4/21/04 From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Tue, 01 Jun 2004 07:23:49 -0800 To: NSK Problem Well Supv <n1617@conocophillips.com> Thanks Marie, I will have the present 403 canceled. Tom Maunder, PE AOGCC As you get new information, we will look for another 403. NSK Problem Well Supv wrote: Tom, Please disregard the 10-403 submitted on After reviewing 3N-11 with Jerry, the plan forward has changed. 4/21/04, the plan for repairing this well has been modified. An honest attempt has been made to patch the tbg leak; however, TxIA comm exists post patch based on MITrA results and wellhead pressure trends. Due to the difficulty of setting a patch across the PBR at 8270, the will be removed. Diagnostics will be performed to confirm IA and packer integrity and a new 10-403 will be submitted. Diagnostic plan: 1. Pull retrievable patch 2. Set TTP 3. MITrA with TTP (CMIT) to verify IA and Pkr integrity 4. Submit 10-403 based on diagnostics. Please let me know if you have any questions. Marie McConnell Problem Well Supervisor 659-7224 1 of 1 ) patch ) 6/1/2004 7:24 AM RE: 3N-ll 1""\ ,~ S!,bject: RE: 3N-ll From: NSK Problem Well Supv<nI617@conocophilhps.com> Date: Sat, 15 May200410:51:26-0800 To: Thomas Maunder <tom_maunder@admin.state.ak.us> CC: "Bob Fleckenstein AOGCC (E-mail)" <bob - fleckenstein@admin.state.ak.us>, NSK Problem Well Supv <n 1617@conocophillips.com> Tom, After we set the patch there appeared to be a good differential between the tubing and IA. even though the patch failed the MITIA (barely). As the well has remained on injection and the zone is getting recharged (increasing tubing pressure) we have also seen an increase in the IA pressure. The tubing and IA are tracking within a few hundred pounds. We just performed another MIT and the data is attached; we are still calling this a fail. The leak rate is not getting worse but is not getting better. Also attached is a trend of the well pressures. If the well keeps charging higher we may not be able to live with this and will be looking for a different repair option. If we come up with something good we will let you know (and process the paperwork'). Call if you have any questions. Bob, The MIT data is also for you. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907 - 659-7224 - - -- -original Message- ---- Prom, Thomas Maunder [:r.ail:o,tom mau~der@admin.sta:e.ak.usJ Sent, Tuesday, May 11, 2004 2'49 PM To, NSK Problem Well Supv Subject, 3N-ll Hi Marie, I was wondering if you could update how the post patch performance on 3N-ll is going?? Thanks. Tom : Content-Description: 3N-ll Trend.gif 3N-ll Trend.gif Content-Type: image/gif , Content-Encoding: base64 10f2 6/1/20047:42 AM ..--.... r'\ 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.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. KRU 3N-11 04/20/04 Brake 1 Rogers NA Packer Depth Pretest Initial 15 Min. 30 Min. we1l13N-11 I Type Inj Is 1 T.v.D. 1 62791 Tubing 11840 11840 11840 11840 I Interval 1 0 P.T.D. 1860770 Type Test P Test psi 1570 Casing 1000 2500 2420 2320 P/F F Notes: Post patch MIT as per Sundry 303-265, attempt #1 we" 3N-11 I Type Inj Is I TV.D. I 62791 Tubing I P.T.D. 1860770 Type Test P Test psi 1570 Casing Notes: Post patch MIT as per Sundry 303-265, attempt #2 Well! P.T.D. Notes: I Type Inj 1 Type Test I T.V.D. I 1 Tubing 1 Test psi 1500 Casing 1840 I 1840 I 1840 I 1840 Interval! 0 2320 2500 2480 2450 P/F F 1840 I 1840 I 1840 I 1840 Intervall 0 2410 2500 2490 2480 P/F F Interval P/F , I Interval I P/F we" 3N-11 I Type Inj Is I T.v.D. I 6279 I Tubing P.T.D. 1860770 Type Test P Test psi 1570 Casing Notes: Post patch MIT as per Sundry 303-265, attempt #3 weill .P.T.D. Notes: I' Type Inj I Type Test I T.V.D. I I Tubing I Test psi 1500 Casing 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 MIT KRU 3N-11 04-20-04-1.xls 6/1/2004 Re: 3N-II post patch update Subject: Re: 3N-ll post patch update From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Tue, 27 Apr 2004 08:37:09 -0800 To: NSK Problem Well Supv <n1617@conocophillips.com> Hi Marie, Thanks for the information. I concur that it looks like the patch is having a positive effect on the IA pressure response. It will be interesting to see how the IA responds to increasing the choke (and other operating parameters). Who will be changing out with you tomorrow?? It would seem appropriate to continue to monitor the well performance maybe into next week. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote: Tom, ) 3N-ll (PTD 186-077) is still looking good. The well was on injection at a choked rate for about a week maintaining a good pressure differential between the T & IA. The IA was lower than the tbg the entire time. Prior to the tbg patch, the IA was 500 psi higher than the T due to hydrostatic head difference between the IA and T. I'm confident that the slow rise in IA pressure since the well was BOI is thermal. Prior to the patch, the IA repressured to pre-bleed pressure within 5 hrs. Since the IA hasn't equalized with the tbg over the last week, the well was fully opened last night to test the patch at the higher tbg pressure we expect to operate the well at. I don't have any IA trend data yet at the new tbg pressure, but we will watch it for a while to determine if the patch holds under these conditions. I've attached 3 plots for you. 2 of the trends are overlays of the manual IA pressure recordings with the tbg pressure and injection rate. One plot for the 1st week post patch and another plot for the last month of injection prior to the patch. The daily OA values do not show on these plots, so I've attached a second plot of just daily manual values and daily averages of instrumented values showing T,IA,&OA. Please let me know if you have any questions. Marie McConnell Problem Well Supervisor 659-7224 «3N-ll Inj Trend 4-14 to 4-27-04.gif» «3N-ll Inj Trend Jan 2004.gif» «3N-ll 6 mo T-IA-OA daily plot thru 4-27-04.gif» ) 1 of4 4/27/20048:37 AM (!) 1;š ~ §' ..d (.) 1;j Q.. +-' '" 0 Q.. - - Z r<) I""'-, 1'"'"'\ ~ <: (") c:'! 00 '<:t 0 0 ~ t-- ~ '<:t '<:t .... 0 N (!) <a '" §' -5 1;$ Q.. ..... '" 0 Q.. - - z C') ,.-...., ,.-..., ~ < C') c:'! 00 '<:t 0 0 ~ r- ~ '<:t '<:t '- 0 C') 3N-ll post patch update ) ,---------"" --------------- -" -----_uu- ----_u_-- -- --I Content-Desèription: 3N-ll Inj Trend 4-14 to 4-27-04.gif I 3N-ll Inj Trend 4-14 to 4-27-04.gif Content-Type:" iroage/gif : I Content-Encoding: base64 ! 1 -- -" - -- - ----" - ----- -" , - -- - - -- ----" ------ ---- - ,,- -- - Content-Description: 3N-ll Inj Trend Jan 2004.gif 3N-11 Inj Trend Jan 2004.gif Content-Type: image/gif Content-Encoding: base64 ------ ------ ---" - - -" -- - n_" - - --" -- - - ,,---- ) 'I Content-Description: 3N-ll 6 roo T-IA-OA daily plot thru 4-27-04.gif" 3N-ll 6 roo T-IA-OA daily plot thru 4-27-04.gif Content-Type: image/gif - I Content-Encoding: base64 '."f 4 4/27/20048:23 AM RE: Kuparuk well 3N-11 Post Patch MIT (PTD 1860770) /'"""\ ,~, Subject: RE: Kuparuk well 3N-ll Post Patch MIT (PTD 1860770) From: NSK Problem Well Supv <n1617@conocophillips.com> Date: Fri, 23 Apr 2004 13:41:55 -0800 To: Thomas Maunder <tom_maunder@admin.state.ak.us> Tom, Attached is the requested summary for 3N-11. The well was SI on 1/25/04 while waiting on the patch installation. The well was BOI again on 4/18/04. Marie Problem Well Supervisor 659-7224 -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Friday, April 23, 2004 12:32 PM To: NSK Problem Well Supv Cc: Jim Regg Subject: Re: Kuparuk well 3N-11 Post Patch MIT (PTD 1860770) Jerry, I have pulled the file on this summary" similar to the others Thanks in advance. Tom Maunder well. Can you send me an "operational you have sent me previously? Thomas Maunder wrote: Jerry, I have received the sundry. On the sequential MITs, it appears that you were getting the IA fluid packed since the pressure loss decreased each time with a greater differential pressure to the tubing. Some pressure history will help on this. Is the well in service at the present time?? Do you have any TIO history since the patch was placed?? Tom NSK Problem Well Supv wrote: «MIT KRU 3N-11 04-20-04.xls» Tom: Attached is an MIT form for Kuparuk injector 3N-11 (PTD 1860770). As per Sundry 303-265, we were to set a patch over a known leak, MIT the repair, and file a 10-404. The 10-404 will be coming in the mail. If you review the MIT data you will find I called these (3) attempts a failure due to a very small but linear leak-off. The well remains on water injection. We have been working on this well now for about 1-1/2 years to resolve this leak issue. The leak is at or near the PBR and so our patch repair includes a sliding assembly. There has not been a good history of these type of patches succeeding routinely and it does not surprise me that we are having problems with this installation. When this problem was first discovered the injection and annulus pressure on the well was just over 3000 psi. That is the maximum we have allowed on an injector in the field. The rate into the well was choked back to reduce the pressure on both the tubing and IA, and as a result the well quit taking fluid. The goal of this patch was to be able to raise the injection rate/pressure while keeping the IA pressure down. Since this patch was installed on 4/17/04 and the well put on injection, the tubing injection pressure has been running around 1850 psi. This is well below previous injection pressures, supposedly since the well has been shut-in for awhile. We expect the injection 10f2 4/23/2004 2:07 PM RE: Kuparuk we1l3N-11 Post Patch MlT (PTU US60nO) ~ ,~, pressure to slowly increase over time back to the 3000 psi area. If this patch keeps our IA pressures low enough we may be able to operate as-is for quite awhile. If the T & IA track, we will reach a point where we either need to shut-in the well again or attempt another repair. The following actions I am suggesting we take in the near term: 1. Submit 10-404 as required for patching the well, including the MIT data; 2. Submit a 10-403 for continued water injection with a failed MIT; 3. Continue to report the well on the Monthly Failed MIT report; 4. Propose another repair via a 10-403 if/when the tubing and IA pressures increase to our allowable limits. This plan should let us keep the well on line until we either determine the patch is holding well enough to meet our requirements or we devise another repair method. Please let me know your thoughts on our plan. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7224 > --- - - --, -~- -------- - - -- ----- - - - - - -- --,,---, 3N-ll EVENTS. xIs Content-Description: 3N-ll EVENTS.xls Content-Type: applicationlvnd.ms-excel ¡ Content-Encoding: base64 -------- - --------- -- - - - - - - 2 of2 4/23/2004 2:07 PM Date Event Summary 4/20/2004 MITIA 4/18/2004 MITIA failed SET TUBING PATCH OVER THE INTERVAL 8254-8291 ELEMENT TO ELEMENT. TOP OF PATCH AT 8252. MIN ID OF PATCH IS 1.245". PATCH SET WITH EXPANSION JOINT PARTLY CLOSED, PINS SHEARED IN PROCESS OF 4/17/2004 STINGING INTO LOWER ASSY, OVERPULLING DID NOT STROKE OPEN EXPAN DRIFTED TBG TO 8325' W/ 2.175" SWAGE, 20' X 1.5" STEM, 2.05" CENT (STIFF ASSEMBLY) NO PROBLEMS OR 3/20/2004 TIGHT SPOTS ENCOUNTERED. 3/14/2004 SET PATCH - OPERATION INCOMPLETE AFTER LOWER PATCH ELEMENT SLIPS PRESET. CMIT TBG/IA TO 3500 PSI. PASSED. KNOCKED OUT SHEAR OUT DISC AND PRESSURE EQUALIZED. APPEARED THAT DEPTH OF ECLIPSE MOVED DOWNHOLE 30'. FOUND ECLIPSE PACKER TO BE ON TOOL STRING (HELD ON 2/4/2004 BY A FRICTION BITE TO 2.1 "CENTRALIZER ON S/L TOOLSTRING). SENT ECLI 2/2/2004 SET ECLIPSE PATCH LOWER PACKER WITH MID ELEMENT AT 8289'. GOOD SET. LOCKED OPEN FVL SSSV @ 1835' RKB. DRIFTED W/ TATTLE TAIL TO CONFIRM FLAPPER FULLY OPEN. PULLED 1/27/2004 CA-2 PLUG @ 8325' RKB. 1/26/2004 SET 2.25 CA-2 PLUG @ 8325' RKB (2800 PSI UNDER PLUG). IN PROGRESS. JEWELRY LOG; LOG JEWELRY FROM TD (TAGGED AT 8568') TO 7722' ACROSS JEWELRY. BHT: 74 DEGF. BHP: 5650 PSIA. WELL ON WATER INJECTION THROUGHOUT LOG (INJECTING AT 1750 BPD, 2650 PSIA). WHILE POOH, 1/25/2004 COULD NOT PASS THROUGH SSSV (TRDP TYPE), INCREASED INJECT ) 6/5/2003 TAG FILL W/ 1.75" SAMPLE BAILER @ 8567' WLM SAMPLE HAS FRAC SAND & METAL CHUNKS SAVE FOR CWG PERFORMED A REVERSE FILL CLEAN OUT TO 8,553' CTMD. RETURNS 1-1+ ALL DAY. FINE CARBOLITE WITH 6/4/2003 WHAT APPEARS TO BE MIXED WITH SLUGGIT. PREP TO HAND OVER TO FACILITIES FOR INJECTION. 5/22/2003 TAGGED FILL @ 8563' RKB. EST. 26' FILL. DRIFTED TBG W/ 2.25" X 5' BAILER TO D NIPPLE @ 8325' RKB. 9/25/2002 PULLED FRAC SLEEVE @ 1835' RKB, PULLED INJ VALVE @ 8325' RKB. FOUND LEAK IN PACKER @ 8285' RKB. VIDEO LOGGED TBG STRING USING N2 DISPLACEMENT IN TBG. LOGGED 9/24/2002 OUT OF THE HOLE WITH NO OTHER LEAKS IDENTIFIED. LEFT TBG DISPLACED W/ DIESEL SET 2.25" MCX INJECTION VALVE @ 8325' RKB.BLED DOWN TBG AND lA, GOOD TEST. SET 2.31" FRAC SLEEVE 9/21/2002 (1.81" ID) ACROSS SSSV @ 1835' RKB.WELl READY FOR CAMERA JOB. DRIFTED W/2" & TAGGED FILL @ 8569' RKB. EST 20' OF FILL.FREEZE PROTECTED TBG & FLOWLINE W/ 9/20/2002 METHANOL. JOB IN PROGRESS. 8/27/2002 PULLED PLUG @ 8325' RKB. 8/23/2002 CMIT - passed 8/19/2002 SET 2.25" CA-2 PLUG @ 8325' RKB. WELL READY FOR DHD CREW DIAGNOSTICS. 8/5/2002 POT-T - passed, PPPOT-T - passed, MITIA - failed, IA FL - near surface 8/23/1999 PERF'D 8420'-8435', 4 SPF, 0 DEG PHASED, +/- 90 CW FLSH, LOOKING DH. ) , DRIFTED TBG WITH 19' X 2.125" DUMMY GUN. TAGGED @ 8569' RKB: 134' BELOW TARGET DEPTH, EST. 20' FILL. 8/12/1999 [Tag] COMPLETED INJECTION PROFILE PER PROCEDURES. 100% OF INJECTION FLOW IS GOING INTO A3 SAND FROM 2/11/1999 8475'-8490'. 12/15/1998 GAUGED TBG W/2.2" , TAGGED FILL @ 8552' RKB. 7/6/1996 PULL DAP SLEEVE @ 1835' RKB. PULL PETREDAT, SET 1.5" DV @ 8226' RKB. PIT CSG. HPBD COMPLETED, 900 PSI DIVERSION SEEN ON 3RD STAGETOTAL SLURRY VOLUME 2327 BBLS. TOTAL 7/3/1996 PROPPANT PUMPED 10322 LBS OF #20/40. TOTAL ROCK SALT PUMPED 2400 LBS. 7/1/1996 SET PETREDAT @ 8226' RKB, PT CSG, SET SLEEVE @ 1835' RKB. PERF A11NTERVAL 8540'-8560' (REF CET DATED 4/12/86) USING 2-1/8" EJ W/ DP CHARGES, 4 SPF, 180 DEG PH, 6/27/1996 ORIENTED +/- 90 DEG PH F/ LOWSIDE 6/25/1996 DRIFT TBG W/20' X 2.125" STEM TO 8560' RKB. 6/20/1996 TAGGED @ 8573', EST. 16' FILL. DRIFT TBG: TBG CLEAR. ) ) STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 0 Suspend 0 Operation Shutdown 0 0 Repair Well [2] Plug Periorations 0 0 Pull Tubing 0 Periorate New Pool 0 4. Current Well Status: Development [2] Stratigraphic 0 Representative Daily Average Production or Injection Data Gas-Met Water-Bbl 1800 1800 15. Well Class after proposed work: Exploratory 0 Development 0 Service [2] 16. Well Status after proposed work: oilD GasD WAGD GINJD WINJ [2] 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A If C.O. Exempt: 303-265 1. Operations Periormed: Abandon Alter Casing Change Approved Program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 68' 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: Total Depth measured feet feet 8790' 6637' true vertical Effective Depth measured feet feet true vertical Casing Structural CONDUCTOR SUR. CASING PROD. CASING Size MD Length 16" 9-5/8" 115' 4490' 8709' 115' 4558' 8777' 7" Perforation depth: Measured depth: 8420-8435,8475-8490,8498-8523,8561-8589 true vertical depth: 6373-6384, 6412-6423, 6429-6446, 6459-6493' Tubing (size, grade, and measured depth) 2-7/8", J-55, 8358' MD. Packers & SSSV (type & measured depth) pkr= BROWN 'HB' pkr= 8287' sssv= SSSV sssv= 1835' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure: 13. Oil-Bbl Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations_X Contact Jerry Dethlefs / Marie McConnell Printed Name ~rry Dethlefs ~ Slg""Me ~~C ----U Form 10-404 Revised 2/2003 . Title Phone Perforate 0 Variance 0 Annular Disp. 0 Stimulate 0 Time Extension 0 Other 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 186-077 1 6. API Number: 50-029-21580-00 Exploratory 0 Service 0 9. Well Name and Number: 3N-11 10. Field/Pool(s): Kuparuk Oil Pool Plugs (measured) Junk (measured) TVD Burst Collapse 115' 3632' 6628' RECEIVED APR 2 2 2004 Alaska Oil & Gas Cons. Commission Anchorage Casing Pressure 3000 1000 Tubing Pressure 3000 1876 WDSPLD Problem Well Supervisor" / Date Ø'¿/~f/' OR'G\NAL iØ8SBFl s.',Ioz,L& ConocoPhillips Alaska, Inc. Kuparuk We1l3N-ll (PTD 1860770) SUNDRY NOTICE 10-404 REPORT OF WELL OPERATIONS 4/21/04 The following operations were conducted as per Sundry #303-265: 04/17/2004 SET TUBING PATCH OVER THE INTERVAL 8254-8291 ELEMENT TO ELEMENT. TOP OF PATCH AT 8252. MIN ID OF PATCH IS 1.245". PATCH SET WITH EXPANSION JOINT PARTLY CLOSED, PINS SHEARED IN PROCESS OF STINGING INTO LOWER ASSY, OVERPULLING DID NOT STROKE OPEN EXPANSION JOINT. TESTED IA - HELD 20 PSI FOR 15 MINUTES. BLED DOWN TO 1000 PSI AFfER TEST. Post patch MIT results next page 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 3N-11 04/20104 Brake 1 Rogers NA Packer Depth Pretest Initial 15 Min. 30 Min. we1l13N-11 I Type Inj Is I T.V.D. I 6279 I Tubing 11840 11840 11840 11840 Iinterval 0 P.T.D. 1860770 Type Test P Test psi 1570 Casing 1000 2500 2420 2320 P/F F Notes: Post patch MIT as per Sundry 303-265, attempt #1 we1l13N-11 I Type Inj Is I T.V.D. I 6279 I Tubing I P.T.D. 1860770 Type Test P Test psi 1570 Casing Notes: Post patch MIT as per Sundry 303-265, attempt #2 weill P.T.D. Notes: I Type Inj I Type Test I T.V.D. I I Tubing I Test psi 1500 Casing 1840 I 1840 I 1840 I 1840 Intervall 0 2320 2500 2480 2450 P/F F 1840 I 1840 I 1840 I 1840 Interval 0 2410 2500 2490 2480 P/F F I Interval I P/F Interval P/F we1l13N-11 I Type Inj S T.V.D. I 6279 Tubing I P.T.D. 1860770 Type Test P Test psi 1570 Casing Notes: Post patch MIT as per Sundry 303-265, attempt #3 weill P.T.D. Notes: Type Inj Type Test T.V.D. Tubing I Test psi 1500 Casing 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 MIT KRU 3N-11 04-20-04.xls 4/21/2004 sssv (1835-1836, 00:2.875) PBR (8270-8271, 00:2.875) PKR (8287-8288, 00:6151) NIP (8325-8326, 00:2.875) TUBING (0-8358, 00:2.875, 10'2.441) Perf (8475-8490) Perf (8502-8502) Perf (8508-8508) Perf (8498-8518) Perf (8523-8523) Perf (8540-8560) Perf (8565-8589) ConoeoPhillips Alaska,lnc. 3N-1.1>, U""".,."'.,."..,.",."""",.".,.".""','".""".""."".",""','"",.",'".""""""""""'., "1 ,; , ;\ 'i' " f% I API: 500292158000 SSSV Type: LOCKED OPEN Annular Fluid: Reference Log: Last Tag: 8587 Last Tag Date: 6/5/2003 Cà$in'å~SÍông,.; ,tí1Il2STeIN&S, Description CONDUCTOR SUR. CASING PROD. CASING Tublng;SmngiJTt:JBIJ\lG Size I Top 2.875 0 Per'forationsSummary, '" Interval TVD 8420 - 8435 6373 - 6384 8475 - 8490 8498 - 8502 8502 - 8502 8502 - 8508 8508 - 8508 8508 - 8510 8510.8510 8510 - 8518 8523 - 8523 8540 - 8551 6412 - 6423 6429 - 6432 6432 - 6432 6432 - 6436 6436 - 6436 6436 - 6437 6437 - 6437 6437 - 6443 6446 - 6446 6459 - 6466 Well Type: INJ Orig 4/13/1986 Completion: Last W/O: Ref Log Date: TD: 8790 ftKB Max Hole, Anøle: 50 deg @ 2400 . ,,:/" cr," ,';,. Size Top Bottom 16.000 0 115 9.625 0 4558 7.000 0 8777 ," Bottom I TVD I Wt 8358 6329 6.50 ".. Zone UNIT D,C-4,UNIT B A-3 A-2 A-2 A-2 A-2 A-2 A-2 A-2 A-2 A-1 Status Ft SPF Date Type Comment 15 4 8/23/1999 APERF 0 deg phasing/90 deg CW from lowside; 2 1/8" Enerjet 15 4 0 6 0 2 0 8 0 11 8551 - 8552 6466 - 6467 A-1 " .. 8552 - 8557 6467 - 6471 y A-1 . .- ~- 8557 - 8558 6471 - 6471 'A-1 8558 - 8560 6471 - 6473 A-1 8561 - 8562 6474 - 6474 A-1' 8565 - 8589 6476 - 6493 A-1! ;c;~S¡u:DMan~~S'Na::~." Man Ty~~>;~~tf( V Type V OD Latch Port TRO Mfr' ~'!I ' f 1 2586 2279 Merla . .-TMPD 2 4848 3829 Merla': Jr-'lPD 3 6188 4776 Merla 'TMPD 4 6965 5343 Merla nill'.p 5 7376 5637 Merla T~ß 6 7820 5950 Merla TMPD 7 8226 6236 MMH 2718 X 1.5 Otftêr:(plûQs. eQûIØ..,etc:)';'¡JEWSLR'{ Depth TVD Type 1835 1762 SSSV 8270 6267 PBR 8287 6279 PKR 8325 6306 NIP 8357 6329 SOS 8358 6329 TTL :FIsh..FISH ' Depth Description I Comment 8571 1" BK Latch Ring Lost in Hole; Maybe layinR ,in one of Lo~er GLM G8rièralNotes ' ." Date I Note 9/24/2002 TBG LEAK FOUND @ 8285' WITH N2 VIDEO LDL. 1 24 DMY -::;- DMY DMY DMY DMY DMY DMY KRU 3N-11 Angle @ TS: 45 deg @ 8423 Angle @ TD: 44 deg @ 8790 Rev Reason: Lock Open SSSV Last Update: 1/29/2004 " TVD 115 3632 6628 Wt 62.50 36.00 26.00 Grade H-40 J-55 J-55 Thread , , " . I Grade I J-55 Thread EUE 8RD ABM ," 5 8 9/26/1987 APERF 60 deg. ph; 2 1/8" Silver Jet 8 9/26/1987 APERF 60 deg. ph; 2 1/8" Silver Jet 9 9/26/1987 APERF 60 deg. ph; 2 1/8" Silver Jet 8 9/26/1987 APERF 60 deg. ph; 21/8" Silver Jet 9 9/26/1987 APERF 60 deg. ph; 2 1/8" Silver Jet 8 9/26/1987 APERF 60 deg. ph; 2 1/8" Silver Jet 9 9/26/1987 APERF 60 deg. ph; 2 1/8" Silver Jet 8 9/26/1987 APERF 60 deg. ph; 2 1/8" Silver Jet 1 7/16/1986 IPERF 120 deg. ph; 4" Jumbo Jet II 4 6/27/1996 RPERF 180 deg. ph; Oriented (+/-) 90 deg F/ Lowside; 2 1/8" EnerJet 5 6/27/1996 RPERF 180 deg. ph; Oriented (+/-) 90 deg F/Lowside; 2 1/8" EnerJet 4 6/27/1996 RPERF 180 deg. ph; Oriented (+/-) 90 deg F/ Lowside; 2 1/8" EnerJet 5 6/27/1996 RPERF 180 deg. ph; Oriented (+1-) 90 deg FI Lowside; 2 1/8" EnerJet 4 6/27/1996 RPERF 180 deg. ph; Oriented (+1-) 90 deg FI Lowside; 2 118" EnerJet 7/16/1986 IPERF 120deg.ph;4"JumboJetll 7/16/1986 IPERF 120 deg. ph; 4" Jumbo Jet II 2 1.0 1.0 1.0 1.0 1.0 1.0 1.5 Date Run 0 10/24/1987 0 10/24/1987 0 10/24/1987 0 7/16/1986 0 10/24/1987 0 10/24/1987 0 716/1996 Vlv Cmnt BK BK BK BK-2 BK BK RK 0.000 0.000 0.000 0.000 0.000 0.000 0.000 '", Description Baker 'FVL' (LOCKED OPEN 1/27/2004) Brown Brown 'HB' Cameo 'D' Nipple NO GO Brown ID 2.310 2.500 3.000 2.250 2.441 2.441 ß.Up<U~VV"'l1Jl"-ll rV"LraU,,111VUl ~rll.llOUVffV) «MIT KRU 3N-11 04-20-04.xls» Tom: Attached is an MIT form for Kuparuk injector 3N-11 (PTD 1860770). As per Sundry 303-265, we were to set a patch over a known leak, MIT the repair, and file a 10-404. The 10-404 will be coming in the mail. If you review the MIT data you will find I called these (3) attempts a failure due to a very small but linear leak-off. The well remains on water injection. We have been working on this well now for about 1-1/2 years to resolve this leak issue. The leak is at or near the PBR and so our patch repair includes a sliding assembly. There has not been a good history of these type of patches succeeding routinely and it does not surprise me that we are having problems with this installation. When this problem was first discovered the injection and annulus pressure on the well was just over 3000 psi. That is the maximum we have allowed on an injector in the field. The rate into the well was choked back to reduce the pressure on both the tubing and lA, and as a result the well quit taking fluid. The goal of this patch was to be able to raise the injection rate/pressure while keeping the IA pressure down. Since this patch was installed on 4/17/04 and the well put on injection, the tubing injection pressure has been running around 1850 psi. This is well below previous injection pressures, supposedly since the well has been shut-in for awhile. We expect the injection pressure to slowly increase over time back to the 3000 psi area. If this patch keeps our IA pressures low enough we may be able to operate as-is for quite awhile. If the T & IA track, we will reach a point where we either need to shut-in the well again or attempt another repair. The following actions I am suggesting we take in the near term: 1. Submit 10-404 as required for patching the well, including the MIT data; 2. Submit a 10-403 for continued water injection with a failed MIT; 3. Continue to report the well on the Monthly Failed MIT report; 4. Propose another repair via a 10-403 if/when the tubing and IA pressures increase to our allowable limits. This plan should let us keep the well on line until we either determine the patch is holding well enough to meet our requirements or we devise another repair method. Please let me know your thoughts on our plan. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7224 MIT KRU 3N-ll 04-20-04.xls Content-Description: MIT KRU 3N-ll 04-20-04.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 1 of 1 4/21/20049:33 AM 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.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. KRU 3N-11 04/20/04 Brake 1 Rogers NA Packer Depth Pretest Initial 15 Min. 30 Min. well 3N-11 I Type Inj S I TV.D. 1 6279 1 Tubing 11840 11840 11840 11840 Interval 0 P.T.D. 1860770 Type Test P Test psi 1570 Casing 1000 2500 2420 2320 PIF F Notes: Post patch MIT as per Sundry 303-265, attempt #1 we1l13N-11 I Type Inj Is I Tv.D'1 62791 Tubing I P.T.D. 1860770 Type Test P Test psi 1570 Casing Notes: Post patch MIT as per Sundry 303-265, attempt #2 well P.T.D. Notes: I Type Inj 1 Type Test I TV.D. 1 1 Tubing I Test psi 1500 Casing 1840 I 1840 I 1840 I 1840 Interval 0 2320 2500 2480 2450 PIF F 1840 I 1840 I 1840 I 1840 Interval 0 2410 2500 2490 2480 PIF F Interval PIF I Interval I P/F we1l13N-11 I Type Inj Is I T.V.D. 62791 Tubing I P.T.D. 1860770 Type Test P Test psi 1570 Casing Notes: Post patch MIT as per Sundry 303-265, attempt #3 weill P.T.D. Notes: I Type Inj I Type Test I T.V.D. I I Tubing I Test psi 1500 Casing 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 MIT KRU 3N-11 04-20-04-1.xls 4/21/2004 01/29/04 Schlumberger NO. 3109 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-5711 Attn: Lisa Weepie ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Color CD ( 3N-11 'K/,,"'f)7'::f 10709696 JEWELRY WITH PRESS & TEMP 01/25/04 1 1F-05 ~-J,~%i. 10709698 INJECTION PROFILE 01/27/04 1 1Y-13 i~'Ol S 10709699 INJECTION PROFILE 01/27/04 1 .' 3K-17 ',C ~/o~IS~ 10709697 LDL 01/26/04 1 1 F-01 ~ ~~ IC 10709693 LDL 01/22/04 1 3J-14 [<a:t=)-~SS 10709690 PRODUCTION PROFILE 01/17/04 1 2H-06 'f)Prlloq 10709694 SBHP SURVEY 01/23/04 1 I ( 1<, ", .... ~" ,;... ." '.'.. ,.. ,''''",' ", "'..,,;.:' RECEIVED '-.:..:., ,. ~ SIGNED: _.~\~ ~.'Y'-- \~O ~--^0 DATE: ...... " ~~.,~., ' Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-831i.Than,k_aOi!&GasCons.Commision ".' '. , .' " ' ,..',' """"'..' "'.'." 'A...ctøage . . / :""" . ,. ". >..., \ .';""., ~',: Mfil "'-'/ I.,"¡I';"~~"'''~' FEE ,n ~ ")n~¡;t :' \.'/" " . ~~("!;\W~~¥j "'I,~, .,'''r I"~ v) fi;)1 t_,. th~ R~~~ --""""'" ~, (' ( Þc..{ '5"' .,., STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: Abandon D Suspend D Operation Shutdown D Perforate D Variance D Annular Disp. D Alter casing D Repair well 0 Plug Perforations D Stimulate D Time Extension D Other D Change approved program D Pull Tubing D Perforate New Pool D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Class: 5. Permit to Dri~mber: ConocoPhillips Alaska, Inc. Development D Exploratory D 186-077 3. Address: Stratigraphic D Service 0 6. API Number: 50-029-21580-00 if P. O. Box 100360 7. KB Elevation (ft): 9. Well Name and Number: RKB 68' 3N-11 8. Property Designation: 10. Field/Pool(s): Kuparuk River Unit 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): 8790' 6637' Casing Length Size MD TVD Burst Collapse CONDUCTOR 115' 16" 1151 115 SUR. CASING 4490' 9-5/8" 4558' 3632 3520 2020 PROD. CASING 87091 7" 8777' 6628 4980 4320 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8420-8435, 8475-8490, 8498-8523, 8561-8589 6373-6384, 6412-6423, 6429-6446, 6459-6493' 2-7/8" J-55 8358' Packers and SSSV Type: Packers and SSSV MD (ft) pkr= BROWN 'HB' pkr= 8287' SSSV= SSSV SSSV= 1835' 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program D BOP Sketch D Exploratory D Development D S~rvice 0 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: ASAP Oil D Gas D Plugged D Abandoned D 16. Verbal Approval: Date: WAG D GINJ D WINJ 0 WDSPL D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: MJ Loveland/Nina Woods @ 659-7224 Printed Name MJ Lovelan~ ~ Title: Problem Well Supervisor '477// ~~ ~ ;¿./~ Signature Phone 659-7224 Date , / to r Commission Use' Only Sundry Number: - Conditions of approval: Notify Commission so that a representative may witness 303 - "2~5 ,- '.' I Plug Integrity D D ~ 'C] I BOP Test Mechanical Integrity Test Location Clearance ...') , , I' Other: :::,:; I:: i:') (,) r i :, .. i. ., Subsequent Form Required: '-\ol..\ lñ)[ß)\fj 1-M;1C~ r:w:;~!) SEP ~ "mn)~]:: IN ¡ì ..QJLt\I~,~..D k"II,," o. ,..".., ¡(, a~~~ BY ORDER OF rs;703 Approved by: COMMISSIONER THE COMMISSION Date: Form 1 0-403 Rc\f.i.~f-d @/ff)(~;ì::, ," :¡, G~ ... SUBMIT IN DUPLICATE . .,,' ~ \ ~ '.j!, '" DtC w) @ 2003 OR\G\NA ( ( ConocoPhillips Alaska, Inc. Kuparuk We1l3N-11 (PTD 1860770) SUNDRY NOTICE 10-403 TUBING REPAIR 09-02-03 This Sundry is a request for approval to repair ConocoPhillips (CPA) Kuparuk We1l3N-11 with a tubing patch. On August 05,2002 the AOGCC was notified of a failed MIT. Subsequent diagnostics show a small thread leak between the PBR and the packer. The plan is to patch the thread leak in tubing with a 38' retrievable patch that has the capability of expansion/contraction with the PBR. Following a successful MIT, the well will be returned to normal water injection. REPAIR PLAN 1. Set 38' 3.5" retrievable patch from -8261-8299' MD. 2. MIT as per AOGCC requirements (0.25 x TVD to packer) 3. Submit 10-404 post repair .. . SSSV (1835-1836. 00:2.875) PBR (827~271 , 00:2.875) PKR (8287-8288, 00:6.151) NIP (8325-8326, 00:2.875) TUBING (0-8358, 00:2.875, 10:2,441) Perf (8475-8490) Perf (8502-8502) Perf (8498-8518) Perf (8540-8560) Perf (8565-8589) ( .', Cönoco,PhilliþsAlas«a, Inc. -- -- -- =1= ==1: ;;;;;;;= ::== - == - - - - == == -- - -- -- -- -- -- - "'" .. ---..::~ ~ i' ", -' .' ,:~'. Q ,-,,', -- -- - =~ : t:: ;f;;;;; :: E== - I-- = 1= -~ -~ -~ -I-- =~ =~ -I-- -~ -~ ðG\,', """,'"',',,, . -- -- -- -- 3N~11" ,'",', , " API: 500292158000 SSSV Type: TRDP " Well Type: INJ Orig 4/13/1986 Completion: Last W/O: Ref Loa Date: TD: 8790 ftKB Max Hole Anale: 50 dea @ 2400 " Annular Fluid: Reference Loa: Last Taa: 8587 Last Taa Date: 6/5/2003 Casing Stl"Înb..ALLSTRINGS Description Size CONDUCTOR 16.000 SUR. CASING 9.625 PROD. CASING 7.000 TubingStfirìg-TUBING' , Size 1 Too 2.875 I 0 8561 - 8562 6474 - 6474 A-1 8565 - 8589 6476 - 6493 A-1 Gås:Liff'MahCtretslValves"",""'" ~"',~ St MD TVD Man Man V Mfr Mfr TvDe 1 2586 2279 Merla TMPD 2 4848 3829 Merla TMPD 3 6188 4776 Merla TMPD 4 6965 5343 Merla TMPD 5 7376 5637 Merla TMPD 6 7820 5950 Merla TMPD 7 8226 6236 MMH 27/8 X 1.5 ;Öthe'r:IPIl#isløâuip;; etc;~"JEWEL~Y' Depth TVD TvDe 1835 1762 SSSV 8270 6267 PBR 8287 6279 PKR 8325 6306 NIP 8357 6329 SOS 8358 6329 TTL Fish..FI,SH """"""",."~~,' Depth I Description 8571 11" BK Latch Rina General,Note'!;'"," """;", Date I Note 9/24/2002ITBG LEAK FOUND @ 8285' WITH N2 VIDEO LDL. Interval 8420 - 8435 8475 - 8490 8498 - 8502 8502 - 8502 8502 - 8508 8508 - 8508 8508 - 8510 8510-8510 8510 - 8518 8523 - 8523 8540 - 8551 8551 - 8552 8552 - 8557 8557 - 8558 8558 - 8560 Bottom 8358 TVD 6373 - 6384 Status 6412 - 6423 6429 - 6432 6432 - 6432 6432 - 6436 6436 - 6436 6436 - 6437 6437 - 6437 6437 - 6443 6446 - 6446 6459 - 6466 Zone UNIT D,C-4,UNIT B A-3 A-2 A-2 A-2 A-2 A-2 A-2 A-2 A-2 A-1 6466 - 6467 A-1 6467 - 6471 A-1 6471 - 6471 A-1 6471 - 6473 A-1 Baker 'FVL' Brown Brown 'HB' Cameo 'D' Nipple NO GO Brown (': KRU 3N-11 ", "'" "",' ".. "~ Anale@TS: 45dea~8423 Angle @ TD: 44 deg @ 8790 Rev Reason: Taa fill Last Update: 6/6/2003 Too 0 0 0 TVD Wt Grade Thread 115 62.50 H-40 3632 36.00 J-55 6628 26.00 J-55 " ", "," ",'" " ,c' ...' TVD I Wt I Grade Thread 6329 I 6.50 I J-55 EUE 8RD ABM ~',' ..., ~," Ft SPF Date Type Comment 15 4 8/23/1999 APERF 0 deg phasing/90 deg CW from lowside; 2 1/8" Enerjet Bottom 115 4558 8777 , '. ..,':', APERF 60 dee. oh' 2 1/8" Silver Jet APERF 60 dee. oh' 2 1/8" Silver Jet APERF 60 dee. oh; 2 1/8" Silver Jet APERF 60 dee. oh' 2 1/8" Silver Jet APERF 60 dee. oh; 2 1/8" Silver Jet APERF 60 dee, ph; 2 1/8" Silver Jet APERF 60 dea. ph; 21/8" Silver Jet APERF 60 dee. ph; 2 1/8" Silver Jet IPERF 120 deQ. ph; 4" Jumbo Jet II RPERF 180 deg. ph; Oriented (+/-) 90 deg F/ Lowside; 2 1/8" EnerJet 5 6/27/1996 RPERF 180 deg. ph; Oriented (+/-) 90 deg F/ Lowslde; 2 1/8" EnerJet 5 4 6/27/1996 RPERF 180 deg. ph; Oriented (+/-) 90 deg F/ Lowside; 21/8" EnerJet 5 6/27/1996 RPERF 180 deg. ph; Oriented (+/-) 90 deg F/ Lowside; 2 1/8" EnerJet 2 4 6/27/1996 RPERF 180 deg. ph; Oriented (+/-) 90 deg F/ Lowside; 2 1/8" EnerJet 1 1 7/16/1986 IPERF 120 dea, ph; 4" Jumbo Jet II 24 1 7/16/1986 IPERF 120deQ.ch;4"JumboJetil (""', ::":,.'¡;,,',,:;><"""""::',<:,':"":.;'" ", ,', ,:"" ~" V Type V OD Latch Port TRO Date Vly Run Cmnt 0 0/24/198 0 0/24/198 0 0/24/198 0 7/16/1986 0 0/24/198 0 0/24/198 0 7/6/1996 ,/ '" ,..;',,-r¡""", 15 4 0 6 0 2 0 8 0 11 8 9/26/1987 8 9/26/1987 9 9/26/1987 8 9/26/1987 9 9/26/1987 8 9/26/1987 9 9/26/1987 8 9/26/1987 1 7/16/1986 4 6/27/1996 1 1 DMY 1.0 BK 0.000 DMY 1.0 BK 0.000 DMY 1.0 BK 0.000 DMY 1.0 BK-2 0.000 DMY 1.0 BK 0.000 DMY 1.0 BK 0.000 DMY 1,5 RK 0.000 ,ii,;,'.;",.".."""""."~;""""~:,.,.,:,:,,,,,.,',""~:, Description ',"",' ID 2.310 2,500 3.000 2.250 2.441 2.441 "",'."',, ""~"'" ""," ," '" ' I Comment 1 Lost in Hole; May be ravine in one of Lower GLM ,;"~",;"""""""":..,,,,, ",>,"""""""" - d 0 0 -q- Phillf .. Well 3N-11 Injection Data 3N-11 Pressure vs. Rate ~. 0 500 1000 1500 2000 2500 j \IN\, ~~ -s: COY!\: ~~~ -\0 ,,*-t-c.. ~o.~\.OV -\- ~"'{<) ~<è ~\. T60~~ ~~ Ð\)\- cl~t::. \ ~t Q.~~~1 \IJ\ ~~Vt. Patch options in progress for T x IA communication 0 0 0 ('t') C) t/) Q. 0 ft 0 a.. 0 - N ::I: ~ ~  Â. ~. ~ ~ .",.. . . 0 0 0 ~ PTO: 1860770, Sundry: Reason: T x IA communication Requires: Monthly Report CMIT (08/23/02) 0 Injection Rate, BWPD I . Previous 60 days. Last Month I Date of Injection Volume Injected Tubing Pressure IA Press u re (BWPD) (psi) (psi) 31-Aug-03 1671 2551 2750 30-Aug-03 1668 2548 2750 29-Aug-03 1697 2547 2750 28-Aug-03 1717 2545 2750 27 -Aug-03 1711 2544 2750 26-Aug-03 1708 2538 2750 25-Aug-03 1706 2531 2750 24-Aug-03 1747 2522 2750 23-Aug-03 1757 2527 2750 22-Aug-03 1782 2516 2750 21-Aug-03 1815 2508 2750 20-Aug-03 1842 2495 2750 19-Aug-03 1883 2478 2750 18-Aug-03 1648 2420 2750 #~~ 17 -Aug-03 1549 2389 2750 16-Aug-03 1558 2375 2750 15-Aug-03 1175 2280 2750 ~O çp 14-Aug-03 1375 2328 2750 13-Aug-03 1092 2264 2650 ~~ 12-Aug-03 1088 2259 2650 ~ 11-Aug-03 1060 2243 2650 1 0-Aug-03 1021 2234 2650 9-Aug-03 1015 2221 2650 8-Aug-03 992 2219 2650 7 -Aug-03 985 2196 2650 6-Aug-03 911 2186 2650 5-Aug-03 930 2183 2650 4-Aug-03 960 2147 2650 3-Aug-03 698 2094 2500 2-Aug-03 705 2088 2500 1-Aug-03 718 2079 2500 31-Jul-03 293 2012 2400 • • Maunder, Thomas E (DOA) From: Tom Maunder [tom maunder@admin.state.ak.us] Sent: Thursday, September 26, 2002 12:48 PM To: NSK Problem Well Supv Subject: Re: Kuparuk 3N-11 Video Attachments: tom maunder.vcf t_ tom_maunder.vcf (2 KB) Jerry, Thanks for the info. We have a standard VHS machine so we could do it here. Let me know when you will be in town. Tom NSK Problem Well Supv wrote: > Tom: A refresher on 3N-11: On August 3rd the Drillsite Operator > reported suspected T x IA communication. On August 5 the diagnostic > crew performed an MITIA which failed with a leak rate 1.8 gpm. That > same day I reported to you of the failed MIT and a request to keep the > well on water injection while diagnostics were performed. The well was added to the Monthly Report. > On August 24 a video log was performed on the tubing to find the leak > point. A leak was found in the tubing at (or near) the packer. At this > point we need to investigate repair options; due to the proximity to > the packer we need to see if a patch can be configured to cover the > leak and provide a good top and bottom seal. ` > Do you have a video machine in your office somewhere? This is a > standard VHS format so should work in any machine. If not I can meet > you in the Tower to give you a look. > Jerry Dethlefs > Tom Maunder <tom maunder@admin.state.ak.us> > 09/26/2002 10:00 AM > To: NSK Problem Well Supv/PPCO@Phillips > cc: > Subject: Re: Kuparuk 3N-11 Video > Jerry, > Yes, please keep us informed. If you wouldn't mind, could you refresh > me on the history of this well. Also, if you have a chance an > opportunity to view that video would be appreciated. > Tom > NSK Problem Well Supv wrote: > > Tom: We just completed a video leak detect log on Kuparuk well 3N-11 > > (PTD 1860770). A leak was identified in the tubing right at the packer @ 8285' > > md. We need to do a little investigation now to determine if the > > leak can be patched. We will keep you updated with what we find out. > > Call if you have any questions. > > > > Jerry Dethlefs > > ConocoPhillips Problem Well Supervisor 1 • Maunder, Thomas E (DOA) From: Tom Maunder [tom maunder@admin.state.ak.us] Sent: Wednesday, August 28, 2002 10:36 AM To: NSK Problem Well Supv Cc: Jim Regg Subject: Re: 3N-11 Update Attachments: tom maunder.vcf ~';~ tom_maunder.vcf (2 KB) Jerry, Thanks for the follow up. Diagnostics continue. What do you estimate the timing on the video log?? Will you know some further information by mid September?? You indicated the well is still on injection. With the successful demonstration of MIT with the CMIT, this is acceptable. In the interim, please add this well to the monitoring list. Please keep us informed of your progress. Hopefully, you will be able to have the necessary determinations made to make your repairjwaiver proposal before the end of September. Call with any questions. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote: > Tom: On 8/5/02 Phillips notified you of a failed MIT on 3N-11 (PTD > 1860770). We set a tubing plug and performed a OMIT T x IA which > passed C~ 3000 psi. In the process we confirmed T x IA communication > which means it must be a leak in the tubing and not the packer or > casing. I have put the well on the list for running a video leak > detect log to identify the leak point. I will let you know how that > turns out and plans forward at that time. Call if you have any questions. > Jerry Dethlefs > Phillips Problem well Supervisor 1 • Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617@ppco.com] Sent: Tuesday, August 06, 2002 8:22 AM To: Tom Maunder Subject: Re: Kuparuk 3N-11 Failed MIT Attachments: tom maunder.vcf ~' tom_maunder.vcf (2 KB) Tom: Slickline is going to set a tubing plug tomorrow so we can start diagnostics. Depending on those results we should be able to leak detect log over the next week or two. Should have something for you by the time I am back from vacation. Neither Pete nor I will be here from August 6 (today) through August 19. If you need to talk to somebody in the Wells group you can try the following numbers: Mike Mooney: (cell) 240-5031 Chuck Fitzpatrick: 659-7221 Bill Raunchenstein: 659-7022 I'll drop you line when I return. Jerry Dethlefs Tom Maunder <tom maunder@admin.state.ak.us> 08/06/2002 07:27 AM To: NSK Problem Well Supv/PPCO@Phillips cc: Jim Regg <jim_regg@admin.state.ak.us> Subject: Re: Kuparuk 3N-11 Failed MIT Jerry, Thanks for the notification. Your plan for keeping the well on water injection and performing diagnostic testing is acceptable. What are your timing plans for accomplishing the work?? Thanks. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote: > Tom: Today (8/5/02) Phillips performed an MIT on Kuparuk well 3N-11 > (PTD > 1860770) that failed. The well had been reported the day prior as > having an > IA that would not bleed down. The MIT was performed at 3000 psi, > bleeding off to 2600 psi in 15 minutes. Over time the leak rate was > measured at 1.8 > gpm from the IA. The wellhead packoffs have tested good. The well is > an swI i > injector, injection pressure is 2000-2500 psi. > Phillips proposes the following action plan: > 1. Continue water injection while diagnostics are being performed; 2. > Set plug(s) to determine if tubing or packer leak; 3. Perform a leak > detect log to locate the leak point; 4. Review diagnostic results and > repair / variance plans with AOGCC. > Please let me know if you approve our plans or have any questions. > Jerry Dethlefs > Phillips Problem Well Supervisor (See attached file: tom maunder.vcf) 2 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate__ Plugging _ Perforate _X Pull tubing Alter casing Repair well Other _ 2. Name of oPerator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development _. 68' RKB 3. Address: Exploratory ~ 7. Unit or Property: P.O. Box 100360 Stratagrapic__ Anchorage, AK 99510-0360 Service X. Kuparuk River Unit 4. Location of well at surface: 8. Well number: 1561' FSL, 155' FEL, Sec 29, T13N, R9E, UM 3N-11 At top of productive interval: 9. Permit number/approval number: 1256' FSL, 938' FEL, Sec 20, T13N, R9E, UM 86-77 At effective depth: 10. APl number: 1503' FSL, 1001' FEL, Sec 20, T13N, R9E, UM 50-029-21580-00 At total depth: i 1. Field/Pool: 1508' FSL, 1006' FEL, Sec 20, T13N, R9E, UM Kuparuk River Field / Oil Pool 12. Present well condition summary Total Depth: measured 8790 feet Plugs (measured) None true vertical 6635 feet Effective Deptt measured 8691 feet Junk (measured) 1" latch ring in lower GLM or rathole true vertical 6565 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 250 Sx CS II 122' 122' Surface 4523' 9.625" 1300 Sx AS III & 4558' 3643' 350 Sx Class G Production 8786' 7" 300 Sx Class G & 8777' 6639' 175 Sx AS I Liner Perforation Depth measured 8420'-8435', 8475'-9490', 8498'-8518', 8523', 8540'-8561', 8565'-8589' true vertical 6373'-6384', 6412'-6423', 6429'-6443', 6446', 6459'-6474', 6476'-6493' Tubing (size, grade, and measured depth) 2.875", 6.5 lb/fi, J-55 ABM @ 8358' ~ h ?~ t - I ' Packers and SSSV (type and measured depth) Pkr: Brown NB @ 8287'; SSSV: Baker FVL @ 1835'_~ ~':" i.'~ ~ ~ i~". ~'~,.~ ~'~,-.~ ~.~ ~ ~ ..... 13. Stimulation or cement squeeze summary Perforated 'C' sands on 8/23/99. Intervals treated (measured) 8420'-8435' Treatment description including volumes used and final pressure Perforated using 2-1/8" EJ guns @ 4 spf, final pressure was 2700 psi. 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 1696 1100 2782 Subsequent to operation 0 0 2339 1100 2339 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations X Oil Gas Suspended _ Service _X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~/ Title: Production Engineering Supervisor Date Signed Form 10-404 Re~ ~6,~1 ~,t88 SUBMIT IN DUPLICATE ARCO Alaska, Inc. - KUPARUK RIVER UNIT ' ~[~ ..ELL SERVICE REPORT ~'._~ 3N-11(4-1)) WELL JOB SCOPE JOB NUMBER 3N-1 1 PERFORATIONS-E-LINE 0812992317.3 , DATE DAILY WORK UNIT NUMBER 08/23/99 PERFORATE 2128 DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR I ~ Yes O No ~'~ Yes O No SWS-ELMORE GOBER /~ ///q FIELD AFC# ICC# ! DAILY COST ACCUM COST Sign~i~.g~~/~. ~~_~ ~. ~ InitialTbg IFinalTbg IlnitiallA IFinallA IlnitialOA IFinalOA ]llLSize ~rl~lrnlD ' 'Depth 2700PSI] 2700PSII 200PSI 200PSI 50PSII 50PSII 0.000 " ! 2.312 " 1835 FT DALLY SUMMARY PERF'D 8420'-8435', 4 SPF, 0 DEG PHASED, +/- 90 CW FLSH, LOOKING DH. [Perf] I TIME LOG ENTRY 07:45 MIRU SWS 2128 ELMORE,TGSM,PT 3000#. 09:45 RIH W/SWIVEL,WTBAR,CCL,MPD,2.125" X 15'4 SPF EJ GUN, OFFSET 90 DEG CW FROM LSH LOOKING DH. 11:00 TIE IN TO SHORT JTS. 11:17 LU TO SHOOT 8420'-8435'. GOOD SHOT INDICATION, POOH. 12:15 AT SURFACE, BD, RD. 13:00 RDMO. SERVICE COMPANY- SERVICE DAILY COST ACCUM TOTAL $o.oo $40.00 APG $100.00 $100.00 HALLIBURTON $0.00 $930.00 LITTLE RED $0.00 $1,000.00 SCHLUMBERGER $7,104.50 $7,104.50 TOTAL FIELD ESTIMATE $7,204.50 $9,174.50 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Other__ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 1561' FSL, 155' FEL, Sec. 29, T13N, R9E, UM At top of productive interval 1256' FSL, 938' FEL, Sec. 20, T13N, R9E, UM At effective depth 1503' FSL, 1001' FEL, Sec. 20, T13N, R9E, UM At total depth 1508' FSL, 1006' FEL, Sec. 20, T13N, R9E, UM 12. Present well condition summary Total Depth: measured 8790 feet true vertical 6635 feet 6. Datum elevation (DF or KB) RKB 68 7. Unit or Property name Kuparuk River Unit 8. Well number 3N-11 9. Permit number/approval number 86-77 10. APl number 5o-029-21580-00 1 1. Field/Pool Kuparuk River Field/Oil Pool feet Plugs (measured) None Effective depth: measured 8 6 9 1 feet true vertical 6565 feet Junk (measured) None Casing Length Size Structural Conductor 8 0' 1 6" Surface 45 2 3' 9 - 5 / 8" Intermediate Production 8786' 7" Liner Perforation depth: measured 8475'-8490', true vertical 6412'-6423', Cemented Measured depth True vertical depth 250SxCS II 115' 115' 1300 Sx AS Ill & 4558' 3643' 350 Sx Class G 300 Sx Class G & 8777' 6639' 175 Sx AS I 8498'-8518', 6429'-6443', Tubing (size, grade, and measured depth) 2.875", 6.5#/ft., J-55 ABM @ 8358' Packers and SSSV (type and measured depth) Pkr: 8540'-8560', 6459'-6473', Brown HB-1 @ 8287'; SSSV: Baker FVL @ 1835' 8565'-8589' 6476'-6493' 13. Stimulation or cement squeeze summary Perforate "Al" sand interval on 6/27/96 0RI61NAL Intervals treated (measured) 8540'-8560' Treatment description including volumes used and final pressure Perforated using 2 1/8" EJ w/ DP charges, 4 SPF 180° PH, +/-90° f/ Iow side, fp was 2500 psi. 14. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Alas. .0il .& Ua.s Cons. Corem1 Prior to well operation 0 0 1408 700 2870 Subsequent to operation 0 0 1408 700 2870 15. Attachments Copies of Logs and Surveys run m Daily Report of Well Operations X 16. Status of well classification as: Oil Gas Suspended Service X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~lned ~~ J.o'z Form 102404 ('l~ev 06/15/~8 Title Wells Superintendent Date ~-9- 97 SUBMIT IN DUPLICATE EL UPARUK RIVER UNIT L SERVICE REPORT ARCO Alaska, Inc. ~' K1 (3N-1 1(W4-6)) WELL JOB SCOPE JOB NUMBER 3N-11 PERFORATE, PERF SUPPORT 0624961857.2 UNIT NUMBER DATE O6/27/96 DAY 1 FIELD ESTIMATE DAILY WORK PERF A1 SAND OPERATION COMPLETE JSUCCESSFUL (~ Yes (~ No I (~) Yes O No A.c~ ICC~ I DAILY COST KAWWRK ! 230DS36NL I $11,582 Imtial Tb.q Press I Final fbCl Press I Initial Inner Ann 2500 PSI! 2500 PSII 925 PSI KEY PERSON SI'FI'ON ACCUM COST $11,582 Final Inner Ann 925 PSI I SUPERVISOR PAIGE Initial Outer Ann I Final Outer Ann 250 PSII 250 PS] DAILY SUMMARY IPERF A1 INTERVAL 8540'-8560' (REF CET DATED 4/12/86) USING 2-1/8" EJ W/DP CHARGES, 4 SPF, 180 DEG PH, ORIENTED +/- 90 I DEG PH F/LOWSIDE I TIME 12:00 13:30 LOG ENTRY MIRU SWS. HELD SAFETY MTG. PT LUB TO 3000#; TEST OK. RIH W/GUN#1 - WGT BAR, MPD, CCL, 2-1/8" EJ W/DP CHARGES, 2 SPF, 0 DEG PH, AND ORIENTED -90 DEG F/LOWSIDE TO SHOOT 8540'-8560' (REF CET DATED 4/22/861 14:30 FIRED GUNS; POH. 15:15 AT SURF W/GUN#1; ALL SHOTS FIRED. 16:15 17:00 17:45 AT SURF W/GUN#2; ALL SHOTS FIRED. 19:00 RDMO. .o PT LUB TO 3000#; TEST OK. RIH W/GUN#2 - 2 WGT BARS, MPD, COL, 2-1/8" EJ W/DP CHARGES, 2 SPF, 0 DEG PH, AND ORIENTED +90 DEG F/LOWSIDE TO SHOOT 8540'-8560' (REF CET DATED 4/22/86) FIRED GUNS; POH. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL SCHLUMBERGER $11,582.00 $11,582.00 TOTAL FIELD ESTIMATE $11,582.00 $11,582.00 ARCO Alaska, Inc. Date: February 23, 1989 Transmittal Ct: 7432 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-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. 3F-15 3N-18 3F-01 3F-02 3F-09 3F-06 3F-10 3F-11 3F-15 3F-14 3N-10 3N-06 3N-09 31-01 3N-11 3N-14 3F-08 3N-01 3N-14 3F-15 3F--15 3F-13 3F-15 1B-05 1 E-25 3B-11 3A-03 3H-01 2Z-19 31-12 1 E-08 3M-18 Kupaurk Fluid Ku 2aurk Fluid Ku 2aurk Fluid Ku 3aurk Fluid Ku 3aurk Fluid Ku 2aurk Fluid Ku ~aurk Fluid Ku ~aurk Fluid Ku ~aurk Fluid Ku 2aurk Fluid Ku ~aurk Fluid Ku 3aurk Fluid Ku 3aurk Fluid Ku~aurk Fluid Ku ~aurk Fluid Ku.~aurk Fluid Ku ~aurk Fluid Ku ~aurk Fluid Ku:~aurk Fluid Ku.~aurk Fluid Ku 2aruk Well Level Report 1 2 Level Report 1 2 Level Report Level Report Level Report Level Report Level Report Level Report Level Report Level Report Level Report Level Report Level Report Level Report Level Report Level Report Level Report Level Report Level Report 1 2 Level Report Pressure Report Ku3aruk Well Pressure Report Bottom-Hole Pressure Survey Kuapruk Well Pressure Report Kuparuk Fluid Kupaurk Fluid Kupaurk Fluid Kupaurk Fluid Kupaurk Fluid Kupaurk Fluid Kupaurk Fluid Kupaurk Fluid Level Re 3ort Level Re 3ort Level Re 3ort Level Re 3ort Level Re 3ort Level Re 3ort Level Re 3ort Level Re 3ort -03-87 -18-87 8-29-87 8-29-87 8-29-87 8-29-87 8-29-87 8-29-87 8-29-87 8-29-87 5-18-87 5-22-87 5-21-87 4-24-87 4-15-87 4-13-87 4-14-87 4-20-87 -04-87 2-O2-89 8-27-87 8-27-87 8-25-87 2-20-89 2-19-89 2-20-89 2-21-89 2-21-89 2-2O-89 2-20-89 2-19-89 2-15-89 Casing Casing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Casinc~ Casinc~ Casino. Casino. Casino. Casinc. Casinc~ Casinc. Casinc. Tubing Sand 'C' SandBHP 'C' Amerada Casing Casing Casing Tubing Tubin~ Casin~[ Casin(]'-'~ 3 H - 01 Kupaurk Fluid Level Report 2-15-89 Casing 3 B - 1 3 Kupaurk Fluid Level Report 2-17-89 Casing I E-29 -- Kupaurk Fluid Level Report 2-15-89 Casing 1 C-05 Kupaurk Fluid Level Report 2-18-89 Casing/Tubing 3 M - 1 7 Kupaurk Fluid Level Report 2-16-89 Casing 2Z-20 Kupaurk Fluid Level Report 2-18-89 Tubing 30-1 0 Kupaurk Fluid Level Report 2-16-89 Casing 31- 1 2 Kupaurk Fluid Level Report 2-20-89 Tubing 3 H - 1 0 BHP Report 2-13-89 BHP Receipt Acknowledged' - .......................... Date' - ........... DISTRIBUTION: D&M State of Alaska SAPC Unocal Mobil Chevron AnChorage ,, 3 F- 14 Kuparuk Fluid Level Report 9 - 11 - 87 3F-06 Kuparuk Fluid Level Report 12-06-86 3 F- 14 Kuparuk Fluid Level Report 9 - 1 I - 87 3 F - 08 Kuparuk Fluid Level Report 10 - 11 - 87 3 F- 14 Kuparuk Fluid Level Report 9 - 1 6 - 87 3 F- 09 Kuparuk Fluid Level Report 4 - 1 I - 88 3 F- 05 Kuparuk Fluid Level Report 4 - 08 - 88 3 F - 09 Kuparuk Fluid Leyel Report 4- 01 - 88 3 F - 06 Kuparuk Fluid Level Report 3 - 26 - 88 3 F - 05 Kuparuk Fluid Level Report 1 - 30 - 88 3 N - 10 Kuparuk Fluid Level Report 10 - 12 - 87 3 N - 10 Kuparuk Fluid Level Report 10 - 15 - 87 3 N - 11 Kuparuk Fluid Level Report 10 - 28 - 87 3 N - 10 Kuparuk Fluid Level Report I 0 - 28 - 87 3 N - 05 Kuparuk Fluid Level Report 10 - 28 - 87 3 N - 04 Kuparuk Fluid Level Report 10 - 28 - 87 3N-13 Kuparuk Fluid Level Report 3- 1 9-87 3 N - 11 Kuparuk Fluid Level Report 9- 1 2 - 87 3N-18 Kuparuk Fluid Level Report 9- 1 0- 98 3N-17 Kuparuk Fluid Level Report 9- 1 0- 87 3 N - 07 Kuparuk Fluid Level Report 9 - 1 0 - 87 3 N - 15 Kuparuk Fluid Level Report 9- 1 2 - 87 3 N - 05 Kuparuk Fluid Level Report 9 - 08 - 87 3 N - 09 Kuparuk Fluid Level Report 9 - 01 - 87 3 N - 04 Kuparuk Fluid Level Report 9 - 01 - 87 3N- 14 Kuparuk Fluid Level Report 9-06-87 3 N - 08 Kuparuk Fluid Level Report 9 - 06 - 87 3 N - 06 Kuparuk Fluid Level Report 9 - 06 - 87 3 N - 02 Kuparuk Fluid Level Report 9 - 06 - 87 3 N - 10 Kuparuk Fluid Level Report 6 - 01 - 87 3 N - 10 Kuparuk Fluid Level Report 5- 31 - 87 3 N - 10 Kuparuk Fluid Level Report 6 - 03 - 87 3 N - 10 Kuparuk Fluid Level Report 6- 06 - 87 3 N - 10 Kuparuk Fluid Level Report .6 - 08 - 87 3 N - 10 Kuparuk Fluid Level Report 6 - 09 - 87 3 N - 10 Kuparuk Fluid Level Report 6 - 25 - 87 3 N - 07 Kuparuk Fluid Level Report 4 - 1 7 - 87 3 N - 01 Kuparuk Fluid Level Report 4 - 1 8 - 87 3 N - 04 Kuparuk Fluid Level Report 6 - 1 7 - 87 3 N - 04 Kuparuk Fluid Level Report 6 - 20 - 87 3 N - 09 Kuparuk Fluid Level Report 5- 07 - 87 3 N - 10 Kuparuk Fluid Level Report 8 - 24 - 87 Receipt Acknowledged' ........................... Date: Casing Tubing Casing Tubing Casing Casing Casing Casing Casing Casing Casing Casing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing ubing ubing 'ubing ubing ubing ubing ubing ubing Casing Casinc~ Casino. Casino. Casino_ Casino. Casino. Cas~nc~ Casino. Casing ,,~lb~ ' /,. J%. ~' Alaska Oil & G~s ....... ¢mcfiOrage DISTRIBIJTION: D&M State of Alaska * Mobil Chevron Unocal SAPC ARCO Alaska, Inc. Date: February 17, 1989 Transmittal Ct: 7429 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-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. 3F-1 I Sub-Surface Pressure Survey I 0-06~88 3 H - 1 2 Kuparuk Well Pressure Report 8 - 2 9 - 8 8 3 O- 0 7 Kuparuk Well Pressure Report I 2 - 2 0 - 8 8 3 F- 1 0 Kuparuk Well Pressure Report 8 - 2 9 - 8 7 3 F- 0 6 Kuparuk Well Pressure Report 8 - 2 9 - 8 7 3 F- 0 2 Kuparuk Well Pressure Report 8 - 2 9 - 8 9 3 F- 1 6 Kuparuk Well Pressure Report 8- 1 7 - 8 7 3 F- 1 6 Kuparuk Well Pressure Report 8 - 1 7- 8 7 3 F- 1 1 Kuparuk Well Pressure Report 8 - 2 9 - 8 7 3 F- 0 4 Kuparuk Well Pressure Report 6 - 2 6 - 8 7 3F~05 Kuparuk Well Pressure Report 1 2-1 2-88 3 F- 1 3 Kuparuk Well Pressure Report I 2- 3 1 - 8 8 3 N - 1 0 Kuparuk Well Pressure Report 6 - 1 1 ~ 8 7 3 N- 1 0 Kuparuk Well Pressure Report 6 - 1 I - 8 7 3 N - 0 4 . Kuparuk Well Pressure Repod 9 - 01 - 8 7 3 N- 0 9 Kuapruk Fluid Level Report 5 - 0 4 - 8 7 3 O- 1 4 Kuparuk Fluid Level Report 2 - 1 3 - 8 9 3 O- 1 4 Kuparuk Fluid Level Report 2 - 1 0 - 8 9 3 M - 1 8 Kuparuk Fluid Level Report 2 - 1 0 - 8 9 3 F- 1 6 Kuparuk Fluid Level Report 6 - 0 5 - 8 7 3 F- 1 3 Kuparuk Fluid' Level Report 6 - 0 9 - 8 7 3 F- 1 3 Kuparuk Fluid Level Report 6 - 1 8 - 8 7 3 F- 1 3 Kuparuk Fluid Level Report 6 - 1 6 - 8 7 3 F- 1 3 Kuparuk Fluid Level Report 6 - 21 - 8 7 3 F- 0 8 Kuparuk Fluid Level Report 5 - 0 8 - 8 7 3 F- 1 6 Kuparuk Fluid Level Report 8 ~ 1 8 - 8 7 3 F- 1 6 Kuparuk Fluid Level Report 8 - 2 4 - 8 7 3 F- 1 3 Kuparuk Fluid Level Report 6 - 0 5 - 8 7 3 F- 1 6 Kuparuk Fluid Level Report 6 - 2 / 3 - 8 7 3 F- 1 6 Kuparuk Fluid Level Report 8 - 5 - 8 7 3 F- 1 6 Kuparuk Fluid Level Report 6 - 5 - 8 7 3 F- 1 4 Kuparuk Fluid Level Report 9 - 8 - 8 7 #7-889 Amerada Sand 'A' Amerada Amerada Amerada Sand 'A' Sand 'A' Amerada Sand 'A' Both Sands Both Sands Sand 'A' Casing Casing Casing Casing Tubing Casing Casing Casing Casing Anchorage Tubing Casing Casing ARCO Alaska, Inc. Pes~ Office ~ox 100360 .-'~nchorage, , .,~,~:-,¢. 9951 Tc~ephone 907 278 12!5 November 9, 1988 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached in duplicate are multiple Reports of Sundry Well Operations on the following Kuparuk wells. Conversions 3N-11, 3N-10, 3N-05, 3N-04, 3F-12, 3F-03, 3F-08, 3N-03, 3N-12, 3N- 13, 1E-21, 1E-19, 1E-23, 1E-lA, 1E-04, 1E-16 and1E-27 Fractures and Stimulations 3K-14, 3C-16, 3K-17, 1E-14, 3N-17, 3F-16 and 2V-12 Perforation~ 3N-11, 3F-11 1 E-30 and 3N-8A Failed MIT If you have any questions, please call me at 265-6840. Sincerely, ¢cS~. "11w G. ood B. Senior Operations Engineer Attachments cc: J. Gruber M. L. Hagood S. P. Twiggs KOE1.4-9 ATO 1478 ATO 1120 ATO 1130 RECEI.VED ,! ,. /. NOV 1 o 1988 ~lasl~l l)il & Gas Cons, .... "~".. Anch.orage!. '::~' ...... Alaska. Inc. is a Subsidiary of AtlanficRichfieidC,,,u?{,~y STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown Pull tubing Alter casing Stimulate __ Plugging Perforate Repair well Pull tubing Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service Location of well at surface 1561' FSL, 155' FEL, Sec. 29, T13N, R9E, UM At top of productive interval 1256' FSL, 938' FEL, Sec. 20, T13N, R9E, UM At effective depth 1441' FSL, 988' FEL, Sec. 20, T13N, R9E, UM At total depth 1508' FSL, 1006' FEL, Sec. 20, T13N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 6. Datum elevation (DF or KB) RKB 68 7. Unit or Property name Kuparuk River Unit 8. Well number ;~N-11 9. Permit number/approval number 7-806 10. APl number 5o-029-21[;80 11. Field/Pool Kuparuk River Oil Pool 8790' MD feet Plugs (measured) NONE 6635' MD feet feet Effective depth: measured 8691' MD feet true vertical 6565' MD feet Junk (measured) NONE Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth 80' 1 6" 250 Sx CSII 115' MD 4523' 9-5/8" 1300SxASIII 4558' MD & 350SX Class G 8742' 7" 300SxClass G 8777' MD & 175 Sx ASI measured 8502', 8510', 8551', 8559', 8565'-8589' MD 8508', 8523', 8557', 8561' MD True vertical depth 115' TVD 3630' TVD 6626' TVD true vertical 6435', 6445', 6469', 6472' TVD Tubing (size, grade, and measured depth) 2-7/8", J-55, tbg w/tail @ 8358' MD Packers and SSSV (type and measured depth) HB pkr @ 8287' & FVL SSSV @ 1835' MD 13. Stimulation or cement squeeze summary 6430', 6436', 6465', 6471', 6475'-6492' TVD 14. Intervals treated (measured) NOV ~L 3 ~9~ Treatment description including volumes used and final pressure ~!~$~(¢[~ & GaS ~0Q~, ~0~t~0~ Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 857 600 0 1 1 7 5 118 0 0 2853 1 050 1300 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil Gas Suspended Service Water Injection 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~'~'~ /~ . r/]"!/L~,,¢(,-~ /L'0t;~'"¢' Title Form 10'-404 R~v 06/15/88 ' Date SUBMIT IN DUPLICATE ARCO Alaska, Inc"- <> Subsidiary of Atlantic Richfield Company WELL IPBDT CONTRACTOR r~EMARKS FIELD- DISTRICT - STATE OPERATION AT REPORT TIME WELL SERVICE REPORT IDAYS DATE ~ / "r'/,,J E..S. S E D ?" 4AI,,,tUL. u$ '1'0 ,.e :~,~,O PS/. ~c.E~ D,cF JChill Factor J Visibility OF "Fi jSIgned r-] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather 1 Temp. IWind Vel. Report miles . knots 1. Type of Request: 2. Name of Operator STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Operation Shutdown Pull tubing Alter casing ARCO Alaska. In(:. 3. Address P. O. Box 100360, Anchorage, AK 99510 Stimulate __ Plugging Perforate X Repair well Pull tubing Other 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 1561' FSL, 155' FEL, Sec. 29, T13N, R9E, UM At top of productive interval 1256' FSL, 938' FEL, Sec. 20, T13N, R9E, UM At effective depth 1441' FSL, 988' FEL, Sec. 20, T13N, R9E, UM At total depth 1508' FSL, 1006' FEL, Sec. 20, T13N, R9E, UM Present well condition summary Total Depth: measured true vertical 6. Datum elevation (DF or KB) 12. RKB 68 7. Unit or Property name Kuparuk River Unit 8. Well number 9. Permit number/approval number 7-618 feet 10. APl number 50-02~-21580 11. Field/Pool Kuparuk River Oil Pool 8790' MD feet Plugs (measured) NONE 6635' MD feet Effective depth: measured 8691' MD feet true vertical 6565' MD feet Junk (measured) NONE casing Length Size Cemented Measured depth True vertical depth Structural Conductor 80' 1 6" 250 Sx CSII 115' MD 115' TVD Surface 4523' 9-5/8" 1300 Sx ASIII 4558' MD 3630' TVD Intermediate & 350 SX Class G Production 8742' 7" 300 Sx Class G 8777' MD 6626' TVD Liner & 175 Sx ASI Perforation depth: measured 8502', 8510', 8551', 8559', 8565'-8589' MD 8508', 8523', 8557', 8561' MD true vertical 6430', 6436', 6465', 6471', 6475'-6492' TVD 6435', 6445', 6469', 6472' TVD Tubing (size, grade, and measured depth) 2-7/8", J-55, tbg w/tail @ 8358' MD Packers and SSSV (type and measured depth) ~.~' ~ L, "'~' ii ',,J,-,~ ~) HB pkr @ 8287' & FVL SSSV @ 1835' MD :.--. 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure · -:;:~ka .0il 14. Prior to well operation Subsequent to operation Representative Daily Average Production or In]ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 612 481 0 1 1 75 857 600 0 1 1 7 5 Tubing Pressure 114 118 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service Date /'~/~/(~ ~ ARCO Alaska, Inc- Subsidiary of Atlantic Richfield Compar ) WELL "'")NTRACTOR REMARKS WELL SERVICE REPORT IFIELD - DISTRICT- STATE OPERATION AT REPORT TIME Co,~ pct.-rE, JDAYS J DATE. C~4I~GE. c.~o~_ : z~Sz97 I ~ =.-r' c.~ ~'-r': lB, ,5 c~ · ~54.75- ~o 45P~ ~ ce~CT pc:c~ -A%~:~ /7~5 - ['-1 CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather : Temp. I Chill Factor I Visibility Wind Vel.- Report I °FI °FI' miles knots ARCO Alaska, Inc -- Post Office= x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 13, 1987 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99501 Commission Dear Mr. Chatterton' Attached in triplicate are multiple on Kuparuk wells. The wells were 1 isted below. Applications for Sundry Approvals both conversions and fractures as Well Action Anticipated Start Date 2A-3 Conversion 2A-6 Conversion 2A-7 Conversion October 19, 1987 October 19, 1987 October 19, 1987 3K-15 Conversion October 15, 1987 3N-4 Conversion 3N-5 Conversion 3N-11 Conversion October 15, 1987 October 15, 1987 October 15, 1987 3Q-5 Conversion 3Q-12 Conversion 3Q-15. Conversion October 15, 1987 October 15, 1987 - October 15, 1987 If you have Sincerely, any questions, please call G. B 1 wood Senior Operations Engineer GBS-pg'0117 Attachments cc' File KOE1.4-9 me at 265-6840. RECEIVED OCT 1 6 1~6'7 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA AL, ..~XA OIL AND GAS CONSERVATION C~...,MISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend ~ Operation Shutdown [] Re-enter suspended well [] Alter casing Time extension [] Change approved program Fq Plugging [] Stimulate [] Pull tubing ~ Amend order [] Perforate ~ Other~'~ 2. Name of Operator ARCO Alaska, ];nc 3. Address PO Box 100360, Anchorage, AK 99510 4. Location of well at surface 1561' FSL, 155' FEL, Sec. 29 T13N R9E UN At top of pro~luctive interval ~ ~ ~ 1256' FSL, 938' FEL, Sec. 20, T13N, R9E, UM At effective depth 1441' FSL, 988' FEL, Sec. 20, T13N, R9E, UN At total depth 1508' FSL, 1006' FEL, Sec.20, T13N. R9E. t~M 11. Present well condition summary Total depth: measured 8790' MD feet true vertical6635, TVD feet 5. Datum elevation (DF or KB) RKB 68 6. Unit or Property name Kuparuk River Unit 7. Well number 3N-11 8. Permit number Permit #86-77 9. APl number 50-- 029-21580 10. Pool Kuparuk River Oil Po~l Plugs (measured) None feet Effective depth: measured 8691' MD feet true vertical6565, TVD feet Junk (measured) None Casing X X X $~',~ t4L,~ Ix X X X X Conductor Surface XXX ~r~l~rl~te Production xxx~-K~xxxx Perforation depth: Length Size Cemented Measured depth 80' 16" 250 SX CSII 115' MD 4523' 9-5/8" 1300 SX ASIII & 4558' MD 350 SX Class G 8742' 7" 300 SX Class G & 8777' MD 175 SX ASI measured 8502', 8510' , 8551', 8559' , 8565'-8589' MD 8508', 8523', 8557', 8561' MD true vertical6430, , 6436', 6465', 6471', 6475'-6492' TVD 6435', 6445', 6469', 6472' TVD Tubing (size, grade and measured depth) 2-7/8", J-55, tbg w/tel] @ 8358' MD Packers and SSSV (type and measured depth) HB pkr @ 8287' & FVI_ SggV fa lg.~5' 12.Attachments Description summary of proposal [] Convert a producer to a water injection well. 13. Estimated date for commencing operation October 15, 1987 True Vertical depth 115' TVD 3630' TVD 6626' TVD Detailed operations program ~ BOP sket'(~b' ~ 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and F,~orrect to the best of my knowledge //~/~?~) -,/(~) ¢ ~-~ 'T,tle Sr. Operations Engineer Signed Commission Use Only Conditions of approval Approved by Form 10-403 Rev 12-1-85 Date10/12/87 Notify commission so representative may witness I Approval No.---~ [] Plug integrity [] BOP Test [] Location clearanceI /t .~/,/'_ ¢Commissioner by order of the commission Date/~) c~}-~ SJ Submit in triplicate STATE OF ALASKA ALA,,..,,-, OIL AND GAS CONSERVATION CO,, .,ISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~i, Suspend [] Operation Shutdown ~.' Re-enter suspended well ~ Alter casing [] Time extension rS Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order ~ Perforate~ Other Name of Operator ARCO Alaska, Inc 3. Address PO Box 100360: Anchnra?: AK 4. Location of well at surface Alt5tColp' ' ,FSL, !,55. FEL, Sec 29 T13N R9E UM eT proauc[ive inierva-i ' ' ' ' 11. 5. Datum elevation (DF or KB) RKB 68 6. Unit or Property name K~Jnar~Jk River Ilnit 7. Well number 3N-11 8. Permit number Permit #86-77 9. APl number 5O-- 029-21580 feet 1256' FSL, 938' At effective depth 1441' FSL, 988' At total depth 1508' FSI , 1 Present well condition summary Total depth: measured 8790' MD true vertical 6635' TVD FEL, Sec.20, T13N, R9E, UM FEL, Sec. 20, T13N, R9E, UM FFI ; g¢c.?FI; TI.'qN; RgF; IIM 10. Pool Kuparuk River Oil Pool feet feet Plugs (measured) None Effective depth: measured feet true vertical 8691' MD feet 6565' TVD Casing xxx~J~kKCdxxxxx Conductor Length Size 80' 16" Surface x x x J4~ ¢(~A'~Xc~t e Production xxx xxxx Perforation depth: 4523' 9-5/8" 8786' 7" measured 8502' 8510' 8508' 8523' true vertical 6430' 6436' 6435' 6445' Junk (measured) It!one Cemented Measured depth 250 SX CSII 115' MD 1300 SX ASIII & 4558' MD 350 SX Class G True Vertical depth 300 SX Class G & 8777' MD 175 SX ASI , 8551', 8559', 8565'-8589' MD , 8557', 8561' MD , 6465', 6471', 6475'-6492' TVD , 6469', 6472' TVD Tubing (size, grade and measured depth) 2-7/8", J-55, tbg w/tail @ 8358' MD Packers and SSSV (type and measured depth) MR p~r 0 8?87' & FVL SSSV @ !835' MD 12.Attachments Description summary of proposal [] 115' TVD 3630' TVD 6626' TVD RECEIVEI) SEP 2 1 Alaska 0il & Gas Cons. Commissiou Anchorage Detailed operations program ~ BOP sketch Addina perforations to an unn~rfnrat~rl interval 13. Estimated date for commencing operation September 20, !987 14. If proposal was verbally approved Name of approver L. Smith Date approved 9/16/87 15. I hereby,certify that the. foregoing is true and correct to the best of my knowledge . ~, ~-(] /?~'~c- , _:~,u,~-z,.Z:- Title · Signed //%1:~.~,~ /~ .,( , 4,¢4' '/ Sr Operations Engineer Commission Use Only Date 9/16/87 Conditions of approval Approved by Notify commission so representative may witness [] Plug integrity [] BOP Test © Location clearance ~ _~;-'.~:Tf'..:~ } ~- :: .... ~ .... ~_~ ~ .... .. Commissioner J Approval No. ../_. &//,..~ by order of the commission Date Form 10-403 Rev 12-1-85 Submit in triplicatet~ ~ STATE OF ALASKA f~zu/ ALASKA OIL AND GAS CONSERVATION u,JMMISSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL YI~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 86-77 3. Address 8, APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21580 4. Location of well at surface 9. Unit or Lease Name 1561' FSL, 155' FEL, Sec.29, T13N, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1256' FSL, 938' FEL, Sec.20, T13N, R9E, UM 3N-11 At Total Depth 11. Field and Pool 1508' FSL, 1006' FEL, Sec.20, T13N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kupaurk River Oi 1 Pool 68' RKBI ADL 25512 ALK 2553 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 0/+/05/86 0/+/11/86 08/15/86'I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 8790 'MD ,6635 'TVD 8691 'MD,6565'TVD YES~ NO []J 1835 feetMD 1700' (approx) _ 22. Type Electric or Other Logs Run DIL/SP/SFL/GR, FDC/CNL, CAL, CET, Gyro (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 115' 24" 250 sx CS II 9-5/8" 36.0# J-55 Surf 4558' 12-1/4" 1300 sx AS III & 350 sx Class G 7" 26.0# J-55 Surf 8777' 8-1/2" 300 sx Class G & 175 sx ~S 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) 2-7/8" 8358' 8287' See Attached. ~6. ACID, FRACTURE, CEMENTSOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED See attached adden(lum, dated 9/02/86, for fracture data 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS'OIL RATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATEDI~ OIL-BBL GAS-MCF WATER-BBL OILGRAVITY-API (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. None !''i;' ;'" Form 10-407 Rev. 7-1-80 * NOTE: Drilled RR 4/13/86. Perf'd well & ran tubing 7/17/86. CONTINUED ON REVERSE SIDE WC1/110 Submit in duplicate 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 8419' 6371' NA Base Kuparuk C 8428' 6377' Top Kuparuk A 8464' 6403' Base Kuparuk A 8614' 6510' . 31. LIST OF ATTACHMENTS Addendum (dated 9-02-86) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /,~ ~/~(_j,~/~'/'~'~-- Title Associate Engineer Date ~'/7-/J'~. 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 Se~:Vice 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~ lng 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 (Cont'd) 3N-11 ITEM 24: MD 8502 8508 8510 8523 8551 8557 8559 8561 8565 - 8589' TVD 6430 6435 6436 6445 6465 6469 6471 6472 6475 - 6492' All perforated w/1 spf ~ 90° phasing WCl:lO8c:dmr 9/12/86 ADDENDUM WELL: 4/24/86 8/15/86 3N-11 Arctic Pak well w/175 sx AS I, followed by 60 bbls Arctic Pak. Frac'd Kuparuk "A" sand perfs 8502' 8508' 8510' 8523' 8551' 8557' 8559' 8561' ' ' , , , & 8565 -8589 in 7 stages perf 7/28/86 procedure using gelled diesel, 100 mesh & 20/40 mesh sand. Press'd ann to 2420 psi w/diesel. Tst Ins to 7560 psi; OK. Stage 1: Pmp'd 79 bbls gelled diesel pre-pad @ 20 BPM, 4220 psi Stage 2: Pmp'd 20 bbls gelled diesel w/1 ppg 100 mesh @ 20 BPM, 4220 psi Stage 3: 153 bbls gelled diesel pad @ 20 BPM, 4400 psi-4200 psi Stage 4: 18 bbls gelled diesel w/3 ppg 20/40 mesh @ 20 BPM, 4200-4280 psi Stage 5: 39 bbls gelled diesel w/6 ppg 20/40 mesh @ 20 BPM, 4280-6100 psi Stage 6: 37 bbls gelled diessl w/8 ppg 20/40 mesh @ 18 BPM, 6100-6530 psi Stage 7: 51 bbls gelled diesel flush @ 18 BPM, 6530-4150 psi Final ann press TM 3440 psi. Pmp'd 840# 100 mesh & 23,793# 20/40 in formation leaving 735# 20/40 above top perfs. Underflushed job by 3 bbls per procedure. (Note: Lost top cut & piece of btm cup off treesaver in hole.) Load to recover 397 bbls of diesel. Job complete @ 1206 hrs, 8/15/86. Turn well over to Production. Drilling Supervisor Date $ UB-$ URFA CE DIRECTIONAL SURVEY I'~UIDANCE ~]ONTINUOUS I-'~OOL RECEIVED AUG- 1 ]986 Alaska 0il & Gas Cons, Commission Anchorage Company Well Name Field/Location ARCO ALASKA, INCORPORATED 3N-11 (1561' FSL, 155' FEL, S29 KUPARUK, NORTH SLOPE, ALASKA , T13N, RgE,UM) Job Reference No, 71465 Locjclecl By: SALAZAR Date 12-MAY-86 Computed By: KRUWELL GCT DIRECI'I2NAL SURVEY CUSTDMER LISTIN2 FOR ARCD ALASKA, INC. 3N-11 KUP~R~K NORTH SLOPE,ALASKA SURVEY DATE: 23-APR-B6 ENGINEER: S&L&Z~R METHOgS OF COMPUT&TIO.4 TOOL LOC4TI3N: T~NGENTI&L- AVER&GE2 DEVIATION ~ND 4ZIM~TH INTERPOLATI3N: LINEAR VERTICAL SECTI3N: 90RIZ. OIST. PRDJECTED OqTO ~ T~RGET AZIMUTH OF NORTH ? DE~ 13 4IN ~EST COMPUTATI3N DATE: 12-M&Y-85 PAGE ARCO ALASKAs I~C. 3N-11 K'JPARUK NORTH SLOPEtALASKA INTERPOLATED VALUES FOR TRUE SJB-SEA ME&SURE3 VERTICAL V:RT[CAL DEPTH DEPT~ DEPTH EVEN 100 FEEF OF 0.00 0.00 -88.00 100.00 100.00 32.00 200.00 200.00 132.00 300.00 300.00 232.00 400.00 399.99 331.99 500.00 499.99 431.99 500.00 599.98 531.9~ 700.00 699.95 631.95 800.00 799.85 731.85 900.00 899.54 831.54 DATE DF SURVEY: /3-APR-86 KELLY BUSHING ELE~'~TION: 58.00 FT ENGINEER: SALAZAR 1000.00 998.58 930.58 1100.00 1096.72 1028.72 1ZO0.O0 1193.53 1125.63 1300.00 1289.16 1221.16 1400,00 1382.59 131~,59 1500.00 1474.31 1405.31 1630.00 1563.52 1495.62 1700.00 1650.21 1582.21 1~00.00 1733.74 1665.74 1900.00 1813.84 1745.84 MEASURED DEPTH CDjRSE V=RTICAL DOGLEG REJTAN 3EVICTION AZIMUTH SECTION SEVERITY NORTH/ DEG ~IN DE~ MIN FEET DEG/IO0 FEE 0 0 N 0 0 0 21 N 78 37 0 19 S 88 15 0 2~ S 86 29 0 32 S 84 9 0 ~3 S 87 31 0 59 N 35 ii, 2 8 N 6 35 3 4 N 8 39 6 3 N 15 45 2000.00 1888.95 1820.95 2100.00 1959.57 1891.57 2200.00 2027.34 195~.34 2300.~0 2092.78 202~.78 2~00.00 2157.14 2089.14 2500.00 2222.00 215~.00 2600.00 2287.51 2219.51 2700.~ 2352.51 228~.61 2800.00 2418.41 2350.41 2900.00 2485.50 2417.60 9 12 15 19 22 24 28 31 34 38 27 N 15 36 N 13 ~,5 N 11 3 Nil 15 N 10 55 N 10 23 N 9 37 N 10 58 N lO 51 N 8 3000.00 2554.09 2~86.09 3100.00 2622.03 2554.03 3200.00 2690.14 ~622.14 3300.00 2750.04 2592.04 3400.00 2629.75 2761.75 3500.00 2898.72 2830.72 3500.00 2967.34 2899.34 3700.00 3035.94 2967.94 3800.00 3104.90 3035.90 3900.00 3172.63 310~,63 43 32 N ~6 14 N 48 21 N 49 37 N 49 53 N 49 17 N 49 7 N 49 22 N 48 17 N 47 11 N 0.00 D.O0 0.06 0.05 0.02 0.09 -0.07 0.15 -0.26 0.07 -0.47 0.25 -0.08 1.24 2.29 1.51 6.69 2.22 14.37 3.36 O. O. O. O. O. O. 2. T. 14. 38 W 27.82 Z.BB 27. 18 W 46.86 2.75 46. 33 W 71.35 2.49 70. 13 W 100.78 ~.29 99. 10 ~ 136.33 2.35 134. 3 W 175.10 3.65 173. 5 W 221.01 3.35 218. 47 W 270.95 3.50 267. 37 W 325.77 3.27 321. 18 W 385.53 5.17 380. 7 2 W 5 53 t~ 8 30 W 7 60 W 7 15 a ? 27 W 7 12 W 7 $ W 46 53 N 6 55 W 47 28 N 6 3¢ W 46 5 N 5 43 W 45 60 N 7 21 ;~ 46 4 N 7 1) W 46 ZO N 7 33 W 47 0 N 10 0 W 46 10 N 10 1 W 45 52 N 9 35 W 47 53 N 8 35 W 451.49 3.93 445. 522.27 2.39 515. 595.79 2.08 588. 671.38 1.0~ 563. 747.91 0.93 739. 524.02 0.55 814. 899.57 0.59 889. 975.48 0.91 964. 1050.77 1.15 1039. 11~.83 1.58 1113. SUL~R COOROIqATES HDRIZ. DEPARTURE SOUTH EAST/~EST OIS[- AZIMUTH T FEET' FE~T' OEG MIN 1197.70 0.71 1185. 1271.08 0.36 1258. 1344.28 2.29 1330. 1415.79 0.82 1401. 1487.48 0.93 1473. 1559.89 2.60 1544. 1532.58 1.01 1516. 1705.26 0.15 1688. 1777.60 1.24 1759. 1851.13 1.49 1832. O0 N 0.00 E 0.00 N 0 0 E 09 N 0.29 E 0.30 N 72 13 E 13 N 0.85 E 0.86 N 8.1 30 E 12 N 1.48 E 1.48 N 85 32 E 03 N 2.30 E 2.30 N' 89 14 E 06 S 3.23 E 3.23 S 88 52 E 46 N 4.22 E 4.24 N 83 47 E 94 N 4.97 E 5.78 N 59 23 E 35 N 4.76 E 8.75 N 32. 56 E 87 N 3.01 E 15.17 ~ Il 26 E 96 N 0.70 W 27.97 N 1 26 ~. 53 N 5.57 W 46.86 N 5 49 W 57 N 10.68 W 71.38 N 8 36 N 47 N 15.6~ W 100.86 ~ 9 29 W 50 N 23.09 W 136.46 N 9 44 W 59 N 30.13 W 176.29 ~ 9 50 W 03 N 37.48 W 221.23 ~ 9 45 ~ 27 ~ 46.11 W 271.22 N 9 4? ~ 21 N 56.54 W 326,15 N 9 58 ~ 18 N 66.5? W 385.96 N 9 55 N 59 N 75.07 W ~51.87 N 9 33 ~ 86 N 83.55 W 522.58 N g 12 d 73 N 93.31 W 596.08 N 9 0 ~ 49 N 104.66 W 671.69 N 8 57 W 2~ N 115.27 W 748.22 N 8 51 ~ 77 N 125.02 W 824.30 N 8 43 W 56 N 134.94 W 899.8~ N 8 37 W 91 N 144.97 W 975.74 N $ 32 W 59 N 15~.58 W I051.02 N $ 27 W O? N 163.82 W 1125.06 ~ 8 22 ~ 38 N 172.75 W 1197.90 N 8 17 ~ 26 N 181.38 W 1271.26 W 8 12 d 98 ~ 189.79 W 1344.44 ~ 8 6 W 96 N 198.42 ~ 1415.94 N 8 3 ~ 04 N 207.87 W 1%87.63 N 8 1 W 89 N 215.~0 W 1560.03 N 7 59 ~ 72 N 228.21 W 1532.75 N ~ 2 ~ 37 N 240.87 W 1705.47 N 8 7 W 72 N 253.32 W 1777.85 N 8 ll ~ 36 N 264.95 W 1851.41 N 8 13 ~ COMPUT~TI3N D&TE: 12-M~Y-85 P~$E 2 ARSD ALASKA, I~C. 3N-11 KUPARUK N3RTH SLOPE,AL~SK~ INTERPOLATED VALUES FOR EVEN 100 FEET TRUE SJB-SEA MEASURED VERTICAL VERTISAL DEPTH DEPTH DEPTH COURSE VERTICAL DDSL DEVIATION AZIMUTH SECTION SEVE DEG ~IN DEG MIN FEET DEG/ 4000.00 3239.49 3171.49 4100.00 3307.95 3239.95 4200.00 3378.93 3310.93 4300.00 3450.21 3382.21 4400.00 3520.~8 3452.88 4500.00 3590.63 3522.63 4500.00 3659.38 3591.38 4700.00 3727.23 3659.23 4800.00 3795.18 3727.18 4900.00 3863.52 3795.52 47 23 N 7 3 W 1925.47 45 58 N 6 lO W 1993.36 44 21 N 7 0 W !068.78 44 44 N 5 55 W 2138.91 45 Z4 N 4 24 W 2209.62 46 7 N 2 42 W 2281.12 47 0 N 2 12 W Z353.47 47 18 N 3 ? W 2426.67 4'7 1 N 5 29 W 2499.94 46 44 N 5 48 W 2572.92 5000.00 3932.12 3854.12 5100.00 4001.01 3933.01 5200.00 ¢070.28 4002.28 5300.00 4139.79 4071.79 5400.00 4209.63 4141.63 5500.00 4279.86 4211.86 5600.00 4350.57 4282.67 5T00.03 4422.10 ~354.10 5~00.00 4494.04 4425.04 5900.00 ~556.07 449~.07 46 36 N ? 2 W 2645.6T 46 17 N ? 21 W 2718.16 46 3 N 7 22 W 2790.27 45 ~9 N ? 29 W 2a62.17 45 31 N ? 45 W 2933.74 45 11 N ? 59 ~ 3004.92 44 38 N 8 7 W 3075.53 44 10 N ~ 14 W ~145.50 43 55 N ~ 22 W 321~.94 43 52 N 8 41 W 3284.30 6000.00 4638.26 4570.26 6100.0~ 4710.71 ~642.71 6200.00 4783.34 4715.34 6300.00 4856.40 ~788.40 6400.00 4929.$8 4851.68 6500.00 5002.87 4934.~7 6600.00 5075.89 5007.89 6700.00 5149.18 5081.18 6800.00 5222.51 5154.51 6900.00 5295.14 5227.14 43 ~2 N 8 49 W 3353.47 43 27 N 9 Z W 3422.37 43 1? N 9 10 W 3491.05 42 57 N 9 1T W 3559.30 42 52 N 9 32 W 3627.30 43 6 N 9 34 W 3595.39 42 55 N 9 2~ ~ 3763.65 42 43 N 9 42 W 3831.62 43 12 N 10 33 W 3899.54 43 27 N 11 27 W 3968.12 ?000.00 5357.10 5299.10 ?100.00 5438.34 5370.34 7200.00 5509.54 5441.64 7300.00 5581.D3 5513.03 7400.00 5552.12 5584.12 7500.00 5722.89 565~.89 7500.00 5793.~7 5725.4? 7700.00 5~63.~6 5795.96 7~00.00 5934.4? 5866.47 7900.00 6004.71 5935.71 44 34 N 12 35 W ~037.31 44 32 N 12 56 W 4107.15 44 26 N 12 59 ~ 4176.90 44 34 N 12 50 W 4246.59 44 47 N 12 50 W 4316.57 45 3 N 12 55 W ~386.88 45 I1 N 12 44 W 4457.38 45 ? N 12 56 W ~52T.9B 45 14 N 12 58 W 4598.52 45 24 N I3 i5 W 4669.33 DATE OF SURVEY: 23-APR-85 KELLY BUSHINS ELE~'ATIDN: 68,00 FT ENGI4EER: SALAZAR OF MEASURED DEPTH EG RECT~NDULAR RITY NORTH/SOUTH 100 FEET CODROIN~TES H3RIZ. DEPARTURE EAST/WEST DIST.: ~ZIMUTH FEET FEET: DEG MIN Z,63 1905.99 N 275, 3,07 1978,42 N 283, 0,55 2048,37 N 291, 1..13 2118.05 N 299. 1.73 2188,50 N 305. 1,51 2250.01 N 310. 0,9~ 2332,58 N 313. 2.1? 2405,97 ~ 316, 0.54 2479,09 N 322. 0.~? 2551.74 N 329. 0,85 2624,05 N 337, 0,32 2595,94 N 345, 0.06 2767,47 N 356, 0.32 2~38.76 N 365. 0.43 2909.70 N 374. 0.53 2~80,20 N 384. 0.64 3050.13 N 394. 0.55 3119.40 N 404. 0.19 3188,13 N 414. 0.35 3256.73 N 424- 0,35 3325.12 N 435, 0,12 3393,21 N 446. 0,62 3461,08 N 456. 0.17 3528.47 N 457. 0.19 3595.60 N 479. 0.44 3562.80 N 490. 0.35 3730,18 N 501. 0.32 3797,26 N 512. 1.6~ 3~64.25 N 524. 0.55 3931.59 N 537. O.TZ 3999.59 0,18 4068,02 0,15 4136.33 0.30 4204,50 9.37 4273.16 0.07 4342.03 0.32 4411.09 0.20 4480.27 0,38 4549.35 0.55 4618.69 29 W' 1925,77 N 8 13 W 45 W 1998,62 N 8 9 W 63 W 2069,03 N 8 6 66 W 2139,14 13 W 2209,80 N 7 5T W 53 W 2281.25 N T 49 39 W 2353.54 N 7 39 W 47 W 2~25,70 N 7 29 34 W 2699.96 N 7 24 W 54 W 2572.93 N ? 21 W 60 W 2545,57 83 W 2718,16 07 W 2790.28 33 W 2862,17 83 W 2933.74 64 W 3004,92 52 W 3075.54 50 W 3145.51 52 W 3214.96 80 W 3284,32 N 7 19 W 7 19 W 7 19 W N 7 19 W 7 21 W N 7 22 W N 7 23 W N 7 24 W 33 W 3353,50 N 7 27 W 09 W 3q. 22.40 N 7 29. W 94. W 3491,11 N 7 31 ~' 91 W 3559.36 N 7 33 W 03 W 3627.37 N 7 35 W 36 W 3595.48 N 7 37 W 53 W 3763.76 N 7 39 ~1 94 W 3831.75 N 7 41 W 62 W 3899.70 N 7 43 W 89 W 3968.31 ~ 7 47 W N 552. N 567. N 583. N 599, N 61~, N 630, N 646 · N 662. N 678. N 694. 40 W 4037.56 97 W 4107.48 74 W 4177.3Z 37 W 4247.10 99 W 4317.19 81W 4387.62 59 W 4458.23 28 W 4528.95 26 W 4599.64 33 W 4570.59 N 7 51 N 7 56 N 8 1 N 8 6 N $ 11 N 8 15 N 8 20 N 8 24 N 8 28 N 8 32 CDMPUTATI2N DATE: 1Z-MAY-85 P~GE 3 ARCO ACASKA, INC. 3~-11 KUPARUK N3RTH SLOPE~ALASKA D~TE 2F SURVEY: 23-A~R-86 KELLY &USHIN3 ELEVATION: 6~.00 PT~ ENGINEER: S4LAZAR INTERP'OL~TED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH VERTICAL SECTION FEET 4740.00 ~810.55 4881.05 ~951.32 5021.14 5091.02 5160.89 5230.07 TRUE SUB-SEA COJRSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DES MIN 8000.00 5075.36 5007.05 45 18 N 13 33 W 8100.00 5145.~8 6077.~8 ~5 10 N 13 ~0 N 8200.00 6215.94 5147.94 45 10 N 14 0 W 8300.00 5286.58 5218.58 44 54 N 14 22 W 8~00.00 5357.59 5289.59 44 ~3 N 14 45 W 8500.00 5428.50 536~.50 44 ~9 N 15 D W 8500.00 5499.58 $431.5~ 44 31 N 15 13 W 8700.00 5570.92 5502.92 44 29 N 15 15 W 8790.0D 5535.12 5567.12 44 29 N 15 15 W 5292.52 DOGLEG RECTANGULAR COORDINATES H]RIZ. DEPARTURE SEVERITY NDRTH/SOUTH EAST/WEST DIST. AZIMUTH DEG/IO0 FEET FEET FEET' DEG MIN O.B7 0.68 0.27 0.51 0.37 0.62 0.92 O.O0 O.OO ~587.84 N 710.73 W 4741.~1 N 8 37 W 4756.B4 N 727.44 W 4812.14 N 8 41 N ~825.76 N 744.37 W 4882.83 N 8 46 ~ 4894.39 N 761.72 W 4953.31 N 8 50 ~ ¢962.54 N 779.40'W 5023,37 fl 8 55 W 5030.57 ~ 797.55 W 5093.50 N 9 0 ~ 5098.57 N 815.90 W 5163.44 N 9 5 ~ 5166.17 N 834.33 W 5233.11. N 9 10 ~ $227.02 N B50.94 W 5295.83 N 9 14 W COMPUIATIDN DATE: 12-M~Y-86 PASE 4 ARCO ALASKA, INC. 3N-11 KUPARUK NORTH SLOPE,ALASKA D~TE OF SJRV'EY: 23-APR-86 KELLY BUSHING ELEVATION: 5B.O0 FT ENGINEER: SALAZAR INTERPOLATED VALUES FOR EVEN 1000 FEET DF MEASURED DEPT TRUE SOB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPT~ DEPTH CDJRSE VERTICAL DOGLEG RECTAN2ULAR DEVI&TION AZIMUTH SECTION SEVERITY NORTH/SOUTH DEG ~IN DEG MIN FEET DEG/IOO mEET 0.00 0.00 -68.00 1000.00 998.58 930.58 2000.00 18'88.95 1820.95 3000.00 2554.09 2485.09 4000.00 3239.49 3171.49 5000.00 3932.12 3864.12 6000.00 ~638.26 45?0.26 7000.09 5367.10 5299.10 8000.00 6075.06 5007.06 8790.,00 6635.12 5567.12 0 0 N 0 O E 0.00 0.00 0.00 N 9 27 N 15 38 W 27'82 2.88 27.96 N 43 32 N 7 2 W 451.49 3.93 445.59 N 46 53 N $ 55 W 1197.70 0.71 1185.38 N 47 23 N 7 3 W 1925.47 2.63 1905.99 N 46 36 N 7 2 N 2545.67 0.85 2524.05 N 43 42 N 8 49 W 3353.47 0.35 3325.12 N 44 34 N 12 35 ~ ~037.31 0.72 3999.59 N 45 18 N 13 33 W ~740.00 0.37 4587.84 N 44 29 N 15 15 W 5292.52 0.00 5227.02 N COORDINATES HDRIZ. DEPARTURE EAST/WEST DIST. AZIMUTH FEET FEET DEG MIN 0.00 E 0.00' N 0 0 E 0.70 W 27.97 N. 1 26 ~ 75.07 W 451.87 N 9 33 W 172.75 W 1197.90 N 8 17 W 275.29 W 1925.77 N 8 13 W 337..$0 W 2645.67 N ? 19 ,4 435.33 W 3353.50 N 7 27 ~ 552.40 W 4937.56 N 7 51 ~ 710.73 W 4741.41 N 8 37 ~ 850.94 W 5295.83 ~ 9 14 ~ COMPUTATION DATE: 12-M&Y-85 PAGE ARCO ALASKA, INC. 3N-11 KUPARUK NORTH SLOPE,ALASK~ INTERPOLATED VALjES' FDR EVEN 100 FEET OF TRUE SdS-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 0.00 0.00 -63.00 58.00 68,00 8.00 158.00 168.00 100.00 258.00 268,00 209.00 368.01 368.00 309.00 468.01 468.~0 400.00 558.02 568.00 500.00 668.04 668.00 600.00 758.12 768,00 700.00 868.32 868.00 80D.O0 969,03 968.00 1'070,63 1068,00 1173,42 1168.00 1277,71 1268,00 1384,27 1368,00 1493.07 1468.00 1604.97 1568,00 1720.98 1668,00 1842.15 1768.00 1971.33 1868,00 2112,20 1968.00 2261.86 2068.00 2416.91 2168.00 2570.24 2268,00 2723.57 2368,00 2873.95 2468.00 3020.3? 2568,00 3167,86 2668,D0 3311.39 2768,00 3455.35 2858,00 3600,96 2968,00 3?46,35 3068,D0 3893.13 3168,00 4041.81 3268.00 4184.7~ 3368,00 4325,07 3468,00 4457.43 3568.00 4612.67 3668.00 4760,09 )768.00 4906.53 3868.00 COURSE DEVIATIQN AZIMUTH DEG MIN DEG MIN 0 0 N 0 0 E 0 21 N 53 1Z E 0 18 N 89 45 E 0 22 N 89 35 E 0 29 S 8% 5 E 0 31 $ 83 26 E 0 ~2 N 53 25 E 1%0 N 13 31 E 2 38 N 5 29 W 4 58 N 1~ 2 W 900.00 8 32 IOOD,O0 11 ¢5 1100.00 14 59 1200.00 18 7 130~.00 21 51 1400.00 24 ~2 1500,00 28 33 1600.00 32 ZO 1702.00. 36 23 1800.00 42 19 N 15 45 N 14 25 N 11 37 Nli 31 N 10 11 N 10 5 N 9 7 N 10 58 N 9 58 N ? 1~ 1900.00 46 31 2000.00 49 16 2109.00 49 %6 2200.00 49 1 2300.00 49 8 2400.00 47 30 2500.00 47 1 2600.00 46 ~5 ZTOO.O0 45 ~1 2800,00 46 26 N 6 58 W N 8 35 W N 7 33 W N 7 38 W N 7 24 W N 7 9 W N 6 52 W N 6 38 W N 7 29 W N 7 4 I,.,I 2900,00 47 1 3000.00 46 21 3103.00 47 ~8 3200.00 46 51 3300.00 44 ZO 3400.00 44 ~2 3500.00 45 52 3600,00 47 6 3700.00 47 lO 3800.00 46 ~3 N 10 OW N 9 55 W N 8 39 ~ N 6 28 W N 7 0 W N 5 35 W N 3 13 W N Z 14 W N 4 58 W N 5 51 W V:RTI~AL~ ~ DO~LEG SECTZON SEVSRITY FEET DEG/IOO 23. 40, 64, 93, 130, 173. 223. 282, 350, ¢31, 531. 642. 760. 877. 993. 1105. 1212. 1320. 1423. 1527. 1633. 1738. 1846. 1956. Z058. 2156. 2257. 2362. 2470. 2577. O0 03 O4 O4 19 4O 38 28 13 36 O2 70 34 78 46 24 35 03 27 93 09 40 .87 10 33 63 58 98 94 48 29 69 05 05 12 57 77 71 74 68 0.00 3,29 0.0~ 0,12 0,23 0o15 1,22 1,43 0,97 3,03 3.64 2,84 3.11 4,11 2,58 3,45 3.35 3,51 3.74 ~,76 2,38 1,22 1,33 0.62 1,09 0,81 0,69 2,32 0,84 0.5~ 1 ,OD 0.75 1.4! 0.63 0,50 1.10 1.33 0.60 1.68 0.63 DATE DF SURVEY: 23-A~R-85 KELLY BUSHING ELEVATION: 58,00 FT ENGINEER: SALAZAR SUB-SE~ DEPTH RECTANG NDRTH/S FEET UL&R COORDINATES H]RIZ. DEPARTURE OUTH EAST/WEST DIST. AZIMUTH . FEET FEST DEG MIN 0.00 0.04 0.13 0.12 0.06 0.04 0.11 1.89 5.79 11.94 N 0.00 E 0.00 N 0 0 E N 0.09 E 0,10 N.65 34 E N 0.$7 E 0,68 ;~ 79 7 E N 1.26 E 1.27 N 84 31 E N 2.01 E 2.01 )~ 88 16 E S 2,93 E 2,93 S 89 18 E N 3.90 E 3.90 N 88 23 E N 4,80 E 5,16 ~ 68 26 E N 4.95 E 7.62 N 40 31 E N 3.~)0 E 12.53 N 17 39 E 23,2 40,5 53,6 92,5 128.7 170.8 220.3 278,1 345.3 426.1 N 0,61 E 23.29 N 1 30 E N 4,08 W 40,71 N 5 '45 W N 9,28 W 64,3.5 N 8 17 W N 15.23 W 93.84 ~4 9 20 W N 22,05 W 130.58 N 9 43 W N 29.63 W 173.42 N 9 50 W N 37.84 W 223.57 N 9 44 W N 48.22 W 282.33 N 9 50 N N 60.98 W 350.69 N 12 0 W N 72.66 W ~32.32 q 9 40 W 524,6 534,B 752,1 867,4 982,6 1094.0 1ZOO,1 1307,8 1512.7 N 84.59 W 531.39 ~ 9 9 W N 100.38 W 542.70 N 8 59 W N 117,01 W 761.17 N 8 50 W N 131.~3 W 877.37 N 8 38 W N 147.27 W 993.59 N 8 31 ~ N 161.43 W 1105.86 N 8 23 W N 174.55 W 1212.79 N 8 16 W N 187,08 W 1321.15 N 8 8 ~ N 199.45 W 1~24,09 N 8 3 ~ N 212.82 W 1527.63 N 8 0 W 1517,41 N 228,33 W 1533,~5 N 8 2 W 1721,33 N 246,70 W 1738,92 N 8 9 W 1827.33 N 264.18 W 1346.33 N 8 13 ~' 1936,36 N 278,25 W 1~56,33 N 8 11 W 2337.80 N 290.31 W 2058.37 N 8 6 W 2135,52 N 301.43 W 2155.79 N 8 2 W 2236.53 N 309.31 W 2257.92 ~ 7 52 W 2341.85 N 313.75 W 2362,78 N ? 37 W 2449.99 N 319.60 W 2%70.75 N 7 25 W 2556.47 N 330.02 W 2577.68 N 7 21 W COXPUTATI3N D4~E: 12-M4Y-85 PAGE 6 ARCO ALASKA, INC. 3N-11 KUPARUK NORTH SLOPE,ALASKA iNTERPOL4TED VALUES FOR EVEN lO0 FEET, OF TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 5052.17 3968.00 3900.00 5196.71 4068.00 ~000.00 5340.45 4168.00 5483.15 4258.00 4209.00 5624.33 4368.00 4300.00 5763.84 4468.00 5902.68 4568.00 6041.11 4668.00 4600.00 6178.90 4768.00 ~700.00 6)15.85 ¢868.00 4800.00 6452.31 ~968.00 4900.00 6589.24 5058.00 5000.00 6725.62 5158.00 5100.00 6852.61 5268.00 5203.00 T001.27 5368.00 5300.00 7141.53 5458.30 5403.00 7281.71 5568.00 5500.00 7422.39 5668.00 5600.00 7563.87 5768.00 5700.00 7735.73 5868.00 5800.00 7847.54 5968.00 5900.00 7989.96 5068.00 6000.00 8131.92 6168.00 6100.00 8273.74 6268.00 6200.00 8414.65 5368.00 5309.00 8555.58 5468.00 5400.00 8595.90 $568.00 6500.00 8790.00 5635.12 6567.12 DATE OF SURVEY: 23-AmR-86 KELLY BUSHING ELEVATI2N: ENGINEER: SALAZAR SU)-SEA DEPTH COURSE VERTICAL DOGLEG RECTANGULAR gEVI~TID4 ~ZIMUTH SECTION SEVERITY NORTH/SOUTH DEG ~IN DEG MIN FEET DEG/IOO FEET 46 27 N ? 20 W 2683.54 0.41 46 3 N 7 22 W 2787.90 0.06 45 44 N ? 36 W 2891.16 0.32 45 16 N 7 59 W 2992.95 0.48 44 30 N 8 9 W 3092.61 43 57 N 8 18 W 3189.87 0.26 43 52 N 8 41 W 3285.16 0.34 43 35 N 8 58 W 3381.83 D.35 43 23 N 9 ? W 3476.58 0.28 42 55 N 9 18 W 3570.09 3.15 $8.00 FT 42 57 N 9 33 W 3662.88 0.22 42 57 N 9 25 W 3756.33 0.55 42 43 N 9 44 W 3848.99 9.20 43 28 N 11 12 W 3942.48 0.44 44 34 N 12 36 W 4038.20 0.70 44 31 N 13 D W" 4135.20 0.31 44 30 N 12 50 W 4233.31 0.45 44 52 N 12 53 W 4332.28 0.45 45 6 N 12 59 W 4431.87 D.SI 45 7 N 12 57 W 4532.02 0.20 45 ZZ N 13 0 W ~632.20 1.05 45 17 N 13 29 W 4732.90 9.50 45 12 N 13 43 W ~833.02 0.70 45 0 N 14 18 W %932.90 0.33 44 45 N 14 48 W 5031.37 0.3? 44 41 N 15 9 W 5129.76 0.14 44 29 N 15 15 W 5227.22 44 29 N 15 i5 W 5292.52 0.00 2661'51 N 2765.12 N 2867.50 N 2~68.36 N 3067.04 N 3163.31 N 3258.57 N 3353.16 N 3446.77 N 3539.13 N COORDINATES HgRIZ. 'DEPARTURE E~ST/WEST DIST. ~ZIMUTH FEET FEET' DEG MIN 342.39 W 2583.55 N. 7 19 W 355.77 W 2787.91 N 7 19 W 369.15 W 2891.16 N 7 20 W 382.98 W 2992.96 N 7 21 ~ 396.9~ W 3092.62 N 7 22 W ~10.88 W 3189.88 N 7 24 W 425.08 W 3286.18 N ? 25 W 439.73 W 3381.87 N' 7 28 W 454.64 W 3476.63 N 7 30 W 469.$5 W 3570.15 N 7 33 ~ 3530.72 N 48 3722.96 N 50 3814.40 N 51 3906.48 N 53 4000.47 N 55 4095.48 N 57 4192.08 N 59 42~8.56 N 61 4386.09 N 64 448~.22 N 66 4582.34 N 4580.90 N 4778.81 N 4876.41 N 4972.51 N 5368.43 N 5153.40 N 5!27.02 N 4.95 W 3562.96 N 7 36 W 0.44 W 3756.44 N 7 39 W 5.87 W 3849.13 N 7 42 W 2.84 W 3942.66 N ? 46 W 2.59 W 4038.45 N ? 51 W 4.52 W 4136.57 ~ 7 59 W 5.52 W 4234.30 ~ 8 5 W 8.51 W 4332.93 N 8 12 W 0.91 W 4432.67 ~ 8 18 W 3.19 W 4533.00 ~ 8 24 W 685.82 W 4533.38 N 8 30 W 709.05 W 4734.30 q B 36 W 732.80 W 4834.67 N 8 43 W' 757.12 W 4934.83 N 8 49 W 782.03 W 5033.63 N 8 56 W 807.72 W 5132.39 N 9 3 W $33.58 W 5230.25 N 9 10 ~ 850,94 W 5295.83 N 9 14 ~ Cm''3' ARCO ALASKA, INC. 3N-1! , KUPARUK NORTH SLOPE~ALASK~ TOP BASE TOP BASE PBTD TD MARKER KUP~RUK ' KUPARUK C KUPARUK ~ COMPUTATI3N INTERPOLATED V,aLUES =OR MEASJRED DEPTH BELOW KB 8419.00 ~%28.00 8464.00 8514.00 8691.00 8790.00 DATE: 12-M~Y-85 CHOSEN H2RIZ3NS FROM KB $371.08 5377.47 5403.00 6509.55 6564.50 5635.12 ORIGIN: 1561 SUB-SEA 630,3.08 6309.4? 5335.00 6~41.55 $496o50 6567o12 PAGE 7 DATE DF SdRVE¥: 23-APR-86 KELLY BUSHING ELEVATION: 58.00 ENGINEER: SALAZAR S'~'R FSL, 155 FELT RECTAN NORTH FACE LOCATION SEC 29~ TI3N~ RgE~ GU'L~R COORDINATES /SDUT,q EAST/WEST 4975.47 N 782°82 W 4981.59 N 784-44 W 5006.12 N 790.97 W 5108.06 N 818.4B W 5150.09 N 832.57 W 5227.02 N 850.94 W FT UM COMPgTATI3N DATE: 12-MAY-86 PAGE 8 ARCO ALASKA, I~C. 3N-11 KUPARUK NORTH SLOPE,ALASKA TOP BASE TOP BASE PBTO TD MARKER KUPARUK C KUPARUK C KUP~RUK ~ KUPARUK A m~~~ STRATISRAPdIC MEASDRED DEPTH BELOW KB 8619.00 8~28.00 8664.00 $514o00 8591.00 87gO.O0 DATE DF SURVEY: 23-APR-85 KELLY BUSHINS ELEVATION: 5B.O0 FT ENGINEER: SALAZAR SUMMARY FROM KB ORIGIN: 1551 SUB-SE~ FSL, 155 S~'RFA F~L, SE RECTANGU NORTH/S CE LOCATION ~T C 2~, T13N, RgE, LAR COORDINATES DUT~ EAST/WEST 5371.08 5377.47 6~03.00 $509.55 6564.50 5635.12 $303.08 6309.67 5335.00 5~41.$5 5¢96.50 5567.12 49?5.4 4981.5 5006.1 5108o0 5150o0 5227.0 782.82 W 784.~6 W 7B0.97 W 818.~8 W 832.57 W 850.94 W UM FINAL WELL LOCATION ~'T TO: TRUE SUB-SE~ MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 8790o0D 5635.12 5567.12 HORIZONTAL DEPAqTURE DISTANCE AZIMUTt FEET D.EG MIN 5295.83 N 9 1~ W SCHLUMBERGER El I REC T I ONAI_ SUR V E Y COMPANY ARCO ALASKA iNC WELL 8N- 1 1 F ~ c=O KUPARUK COUNTRY USA RUN 2 OATE LOOOEO 28 - APR - 86 REFERENCE 00007146S RECEIVED Ala~l<a 0i~ & Gas Cons. Commissio'.q Anchorage WELL 3N-11 (1561' FSL, 155' FEL, S29, T13N, R9E HORIZONTAL PROJECTION NORTH '7000 R£F 0000'7146S BCALE = 1/IOOO IN/FT ~000 SOOO 4000 9000 2000 1 ooo SOUTH - 1000 -4000 WEST ..... ....... · .;..¢..¢. ! .... ; : .~...~..; "'hr" i 'j' ! '?"!"-i"- ;----:-. 4 -.. i-..;..!. ? , ;- :-...;-.-.;..! .: i..i....! "~ ' ~"'?"'F"?'"~" r.-~--- ~ --~ ..... +--~...}.--~--~ ......~ ~...; ..i...; ..1...~.. ;...i...... t-+"t"!- f..f..4 ...... +'--?~.--!.-r--f...f.-i---!..t..+..-~--i-.-~.-.i-.4..!....L f"r"f-'T"{"-i'-'F.-I q ..... i..;., i'"~ ?"1" ~ ....... 'I i....i ....... ~.-~-.i...~...L. f'f-"j'"f"?"':-'-~ .... ~.-~.--~-..=.t--.4---~...~...: ..... !...;...~ ...... ~..4-. i.. i F+'i--T-.~ ....... ! ........ f--.4..-~.-.l..!...;-..:..~, i.~...;..L.i...; ; i ............. ~ ........ :"'~'"f'fl"f'"~"f"f'i '~--+.--.-'.; ; "~"~'"r"r ~--':..:.? :. !--!.-;--i '-f"f--i'.)-.j.-.!.-i..:.~ i!i?~;i~;;L~..4...:..u ~'~ ~ i..i !----~- :--.-N- i--~ -.!.. i---.4..~-. ;.~-.~ ..~.: ..... -'+'-~.-+--~---f- i-!--~ :---- ..-i---~..-~...i...~..i...i...~ :.' i--~--,~ 4-- ~ ; .......... ~ .. ~ ....... ~....! .{. ~ ~ ~ . ~ i ~---~. i~ ' ~I ...... ~..;. ;...i.4 L.L..~ }: i } ~ ~.4...;_.: ,..i..; .L.~...!..!..L ~:'EZ"i' ~"'~"~'- ............ ; ~ . ~ : . , . . I -9000 -2000 - 1000 0 1000 2000 :9000 4000 EAST WELL 3N-11 (1561' FSL, 155' FEL, S29, T13N, R9E VERTICAL PROJECTION L'!: ~'~ ' ~' ~ !-t !.. ~..-~.. i ~. ;;;'~';;;;"/': ;;.;;'-;';'-;;:; ~---?'--rI"-h~ -~ ..... i"~'"~'"~"'?;- ~'' ~'' ;-'"" .:-.~.;.!.-L':;"i;'l ~';;;;-;2?-, '?':---:-?-~---, - --; ........ ~-.~ ...... L] ;' ;": ~ ~"~ '"~ "~ ' .......~...~...~ ....... : -J...L~f' ~'~ ....~"7'~ '~ ~"~"~'"r'~: ...... ~.~. :.. ~ ~. , ;.: ~ : ~"?" '~' r';'",'-r~--t--r~ ............ ; ....... ~..L.;...h;...L.~...i. · · · , ' · ·¢"~ .................. ~..4..~..=..;...~ . ' .................... . - - ' ' f ..... r" ' ....~- ~ .... ~ ~; ~ ~ Z : ' ' ~ '.'"7: .......... ~---.,.-~ ........... :.-J. ~..;. ,. ~.. ~ ; ; ~ : . ¢'; ,' . - -~ -_.~ . ..x.-.. , ~;i %F7~~.. :.'. ' ~7"; .'-? ~2~ ';' '-;' "= ;- ¢ ..... 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' .......... ':- ~V~ - '- ' -'-""~ ~ .... -' ' ..... ...~~., ~~-;._'-~ '-'. ~ - RTtCAL, SECTION - .. . ; .~; ~;~. ;.';; . :;i..~..~ , ::¢.._: ....... ~ ,~-~~. .. -_~. ;~ _';;~-;-;-~-. ..... ": 'f" -, I -. ~.;;;I;.;.,~'.;.:;'~.;~',: .... :-~ ,. :.;;";;~;~';".~" ~'j'":~ .... :~-.~..: -g.~ .' .... ~ ; ,. .... ~ . ' i . . . ". .... ~-; - ~.: ~..~ ....... ~ .... · ; . : - - . ~ ; _ ~ "'- ' ~~ ' ' ......... 'r .... ' ' '" .......... , : ~ '"[ .... 't-~ ............ f ...... ~ .......... ; ....... : .... ; .... - ' - : ' . .... ¢ - . .. L - : , ' . : ' ' :': ':': ~-: ~ ......... :..~ : ~ ~~~ ' · . ~ ..... .. ~ ..... ~ . ; : . - : ; ..... , ....... , ~ . ~~ . ~ ....... :::~ ..;.'; i"~ .... ~;.,..~ ..... ~ :.- ....... ~'- . . , - ..~ .:. . : i : -'- T ~ '"; T ~ - : '- :. . · . ' ' ; '' ;· · , ; · [ · ' ~ ~ . . . . i . ' , 'r--: ........ ;.' ' ; ' ".': ' ' · ' I . ~ ~ :.:.: ~ ~ '.~'~" ~ .... .'~ f .... ~' -.-i ~-: ~-;- ;--.: :._ ' . _ . : ? :'7'--~'. ,' ' -~-I ~ ~ ~. ~"7'.'-'; - ~-.--' ~--;- .}..}..;. :._ ~...L..; ._. ; - - : - ~ ~ - I .., . ; . : ~ ~ :--- . ; ~ ~' : - - · . ' · : . .... ' ~ ..... .... ' i ' 'f ........ ' 4... ~ . ' . . i ~--~ ' - .... : · , - . : . . : " ; .... t.. ~ ¢...~ ~.; ~...:.~ ~ ~ ~ : , ;'f';': ': ' ;... .- _ ¢ - · t ............. : .... J - . · ~ : ' ~ ?"T'"':"~ ..... ? .......... ~'- ~ ---~' : . . · - - - . · ' ' ... i.- . --;.:.. '..":"~'"L';"'~":'~ ....... ~---:.--~--I-.-:--.,.-,-:-i, ~:...~ ....... :.~.;:-~:';:, . . . . ...: ¢...~...:. ' ] "'~ ....... ~.. :.~ ..... ¢ ........ : . ~ - ,: . i..L.L ;...; ............. .... .... .... ;:~---; .~;" ;I }.; .-; ,, .;.7-..-.;..; ......... ~ ....................... ~.~._~.._~ ~ ', ;,.. :.,- . ;- ., ..:. ~ :. : - / ..... - ·* - - I f ............ - , . . ' ; : ~ - - '~ ~ ! . : : : ' ~ ., ; ;.~ . _ . ; ~ - r-- - . - - . ~ : ' · : . , · * . ...... : ...... ~ . - ; ~ - , . : ..... . ~ . ;. . ~ ...... . : . ,:- . ; ..... . ·__~ - PROJECT[ON 0N VERT[E~L PLRNE 352. - 172. SCRLEO IN VERTiCaL DEPTHS HOR[Z SCALE = I/ :000 [N/FT ARCO Alaska, Inc Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 30, 1987 Transmittal # 5966 Return to: Transmitted receipt and ARCO Alaska, Inc. Attn: Kuparuk Records Clerk AT0-1119 P.O. Box 100360 Anchorage, AK 99510-0360 herewith are the following items. Please acknowledge return one signed copy of this transmittal. 3N-7 CET 4-1-86 6202-7597 3N-6 CET 4-1-86 6061-7583 3N-11 CET 4-22-86 7600-8675 3N-12 CET 4-29-86 6396-7965 3N-10 CET 4-14-86 7462-9~30 3J-16 CET 3-29-86 7704-8727 3J-15 CET 3-29-86 7400-8398 IA-8 CRT 1-5-86 5755-6154 2Z-7 CRT 4-14-87 8250-8491 2Z-? CRT 4-12-87 8246-8595 2Z-? Squeeze & Retainer Record 4-15-87 8250-8491 2Z-? Squeeze, BP & Retainer Record 4-~2-87 8290-8588 Receipt Acknowledged: DISTRIBUTION: NSK Drilling Chevron Mobil Date: SAPC Unocal Vault BPAE (film) ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc - Post Office x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 · DATE 10-01-86 TRANSMITTAL # 5783 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 Transmitted herewit~h are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Final Prints: Schl: Open Hot~ Logs: One * of each 3N-11 5" DIL/SFL-GR 2" 'DIL/SFL-GR 5" Den/Neu-GR (poro) 2" Den/Neu-GR (poro) 5" Den/Neu-GR (raw) 2" Den/Neu-GR (raw) Cybertook 04-12-86 Run #1 04-12-86 Run #1 04-12-86 Run #1 04-12-86 Run #1 04-12-86 Run #1 04-12-86 Run 31 04-12-86 RUn 31 3N-12 5" DIL/SFL-GR 2" DIL/SFL-GR 5" Den/Neu 2" Den/Neu 5" Den/Neu 2" Den/Neu Cyberlook (poro) (poro) (raw) (raw) 04-20-86 Run 31 04-20-86 Run 31 04-20-86 Run #1 04-20-86 Run 31 04-20-86 Run 31 04-20-86 Run #1 04-20-86 Run #1 4558-8768 4558-8768 7250-8742 7250-8742 7250-8742 7250-8742 8250-8760 4084-8079 4084-8079 6400-8049 6400-8049 6400-8049 6400-8049 750O-8000 Receipt Acknowledged: CS t~at~ ~> NSK Files*bi ARCO Alaska. Inc. Js · Sub$i~liary of AtlanlicRichfieldCompln¥ STATE OF ALASKA ALAL., OIL AND GAS CONSERVATION COb, .SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate ~ Plugging ~ Perforate ~ Pull tubing Alter Casing C Other ~ Com;Lo'lete 2. Name of Operator ARCO Alaska, Inc. 3. Address P.0. Box 100360 Anchoraoe. AK 99_510 - . 4. Location of well at surface 1561'FSL, 155'FEL, 5ec.29, T13N, R9E, UN At top of productive interval 1256' FSL¢ 938'FEL, Sec.20, T13N, RgE, UN At effective depth 1441'FSL~ 988'FEL, Sec.20, T13N, R9E, UN At total depth 1508'FSL, IO06'FEL, Sec.20, T13N, R9E, UM 5. Datum elevation (DF or KB) RKB 68 ' 6. Unit or Property name '"'~. ........ r Uni t 14'U,_ _ r,, ,I.- 7. Well number 3N-11 8. Approval number 83 9. APl number 50-- 029-21580 10. Pool Kuparuk River Oil Pool Feej.¢ 11. Present well condition summary Total depth: measured 8790 true vertical 6635 Effective depth: measured 8691 true vertical 6565 Casing Conductor Surface Length 80' 4523' 8786' Production Size 16" 9-5/8" 7" feet feet feet feet Plugs (measured) None Junk (measured) None Cemented 250 sx CS II 1300 sx AS III & 350 sx Class G 300 sx Class G & 175 sx AS I Measured depth 115'MD 4558'MD 8777'MD ~ue Vertical depth 115'TVD 3630'TVD 6626'TVD Perforation depth: measured 8502'MD 8508'MD true vertical 6430'TVD 6435'TVD Tubing (size, grade and measured depth) 2-7/8", J-55, tbg w/tail ~ 8358' Packers and SSSVtype and measured depth) HB pkr ~ 8287' &(FVL SSSV ~ 1835' 8510'MD 8523'HD 6436'TVD 6445'TVD 8551 ' r4D 8557 ' MD 6465 ' TVD 6469'TVD 8559'MD 8561'MD 6471'TVD 6472'TVD 8565'-8589'HD 6475'-6492'TVD RECEIVED 12. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure AUG- l 1986 · Alaska Oil & Gas Cons. Commission Anchorage 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Completion Well Hi story) Daily Report of Well Operations Copies of Logs and Surveys Run ~ Gyro 1.6. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (.~ ~/O,~, ~ ~~ TitleAssociate Engineer Form 10-404 Rev. 12-1-85 ~ (DAM) SW0/079 Date ~'~0 ¢~ Submit in Duplicate ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday atter 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, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the enlire operation if space is available. Accounting cost center code State Alaska District ICounty or Parish Alaska Field ~Lease or Unit I Kuparuk River Auth. or W.O. no. ITitle I AFC AKl185 Nordic 4 Operator A.R.Co. ARCO Alaska, Inc. Spudded or w.O.completebegun Date 7/17/86 7/18/86 Date and depth as of 8:00 a.m. North Slope Borough ADL 25512 Completion IWell no. 3N-11 Complete record for each day reported API 50-029-21580 W.I. [Total number of wells (active or inactive) on this Icost center prior to plugging and 56.24% labandonment of this well I IHour I Prior status if a W,O. 7/16/86 / 1200 hrs. I / 7" @ 8777' 8691' PBTD, Tst SSSV 9.9+ NaC1/NaBr Accept rig @ 1200 hrs, 7/16/86. ND tree, NU & tst BOPE. RIH, perf w/4" gun, 1SPF 8502', 8508', 8510', 8523', 8551', 8557', 8559', 8561' & 8565'-8589'. RU & RIH w/2-7/8" compl. 7" @ 8776' 8691' PBTD, RR Diesel Rn 266 jts, 2-7/8" tbg w/SSSV @ 1835', HB Pkr @ 8287', TT @ 8358'. Set pkr, ND BOPE, NU & tst tree. Displ well w/diesel. RR @ 1530 hrs, 7/17/86. RECEIVED AUG- 1 1986 Alaska 011 & Gas Cons. Commission Anchorage Old TD New TD PB Depth 8691 ' PBTD Released rig Date Kind of rig 1530 hrs. 7/17/86 Rotary Classifications (oil, gas, etc.] Type completion (single, dual, etc.) Oil Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data 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 above is correct Drilling Supervisor For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. _. " STATE OF ALASKA ALASI',~-, ,.)IL AND GAS CONSERVATION COMMI,_.,;ION 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 Alaska, Inc. 68' RKB 3. Address 6. Unit or Property name P. O. Box 100360 Anchorage~ AK 99510 Kuparuk River Unit 4. Location of well at surface 7. Well number 1561'FSL, 155'FEL~ Sec.29, T13N, R9E, UM At top of productive interval 8. 1267'FSL, 785'FEL, Sec.20, T13N, R9E~ UH (approx.) At effective depth 1441'FSL, 915'FEL, Sec.20, T13N, R9E, UM (approx.) At total depth 1509'FSL¢ 931'FEL, Sec.20, T13N, RgE, UH (approx.) 3N-11 Permit number 86-77 9. APl number 50_029-21580 10. Pool Ku'paruk River Oil Pool 11. Present well condition summary Total depth: measured 8790 true vertical 6648 feet Plugs (measured) No ne feet Effective depth: measured 8691 feet Junk (measured) None true vertical feet 6578 Casing Length Size Cemented Measured depth Conductor 80' 16" Conductor report 115'MD not avail able. Surface 4523' 9-5/8" 1300 sx AS Ill & 4558'ND 350 sx Class G Production 8786' 7" 300 sx Class G & 8777'MD 1 75 sx AS I _. Perforation depth: measured N o n e ~ue Verticaldepth 115'TVD 3643'TVD 6639'TVD vertical N o ne , ~ true Tubing (size, grade and measured depth) None Packers and SSSV (type and measured depth) None 12.At;.t;ac, h, me,rlts. , ,D~scr(ption, summary of pr.o_p_o, sal [] Detailed operations program [] BOP sketch we~/ rl~St:ory, ~ooenoum tdated '4/2 8/86} 13. Estimated date for commencing operation June, 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 Signed ~r0 ~ ~~L,fL_, Title Ass°ci ate Engineer Commission Use Only Date (DAM) SA/028 Conditions of approval Approved by Notify commission so representative may witness ~ Plug integrity ~ BOP Test [] Location clearance -. ,/,x:.-, '5',"4 Commissioner I Appr°valN°' i~.~ by order of the commission aate,_~ Form 10-403 Rev 12-1-85 Submit in triplicate ARCO 0il and Gas Company Well History- Initial Report- Daily Inatructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are starled. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Alaska ICounty. parish or borough North Slope Borough ILease or Unit ADL 25512 JTitle Drill IState Field Kuparuk River Auth. or W.O. no. AFE AKl185 Doyon 9 Alaska IWell no. 3N-11 API 50-029-21580 Operator ARCO Alaska, Inc, Spudded or w.O,spuddedbegun [Date 4/5/86 IHOur Date and depth as of 8:00 a.m. 4/05/86 thru 4/07/86 4/08/86 4/09/86 4/10/86 4/11/86 Complete record for each day reported 1830 hrs. FARCO W.I, Prior status if a W.O. 16" @ 115' 2310', (2195'), Drlg Wt. 9.5, PV 23, YP 22, PH 9.0, WL 12.8, Sol 8 Accept rig @ 0630 hfs, 4/5/86. NU diverter sys. 1830 hfs, 4/5/86. Drl & surv 12¼" hole to 2310'. 576', .9°, N36E, 576 TVD, .69 VS, 761', 2.5°, N6 E, 760 TVD, 6.02 VS, 1105', 12.7°' Nll.75W, 1101.66 TVD, 1508' 2101' Spud well @ .77N, .56E 6.27N, 1.58E 49.00 VS, 48.31N, 8.53W , 25.0°, N 8.75W, 1481.37 TVD, 181.32 VS, 178.83N, 31.12W , 45.5°, N 5.75W, 1966.23 TVD, 519.25 VS, 513.42W, 78.78W 16" @ 115' 4572', (2262'), POH Wt. 9.0, PV 22, YP 16, PH 9.0, WL 13.4, Sol 5 Drl & surv to 4572', short trip, C&C, POOH to rn 9-5/8" csg. 2258', 48.8°, N8.75W, 2072.3 TVD, 633.6 VS, 626.8N, 93.2W 2858', 47.4°, N7.75W, 2467.1TVD, 1085.3 VS, 1074.3N, 155.0W 3602', 46.7°, N9.75W, 2980.0 TVD, 1623.3 VS, 1608.0N, 222.9W 4522', 45.8°, N1.75W, 3618.3 TVD, 2285.8 VS, 2266.6N, 296.5W 9-5/8" @ 4558' 4682', (100'), Drlg Wt. 8.5 Fin POH. RU & rn 114 its, 9-5/8", 36#, J-55 BTC csg w/Fa @ 4558', FC @ 4476'. Cmt w/1300 sx AS III w/lO#/sx Gilsonite & 350 sx C1 "G" w/l% S-I, .2% D-46 & .2% D-13. Displ using rig pmps, bump plug. ND diverter, NU & tst BOPE. TIH w/BHA to FC, tst csg to 2000 psi. DO cmt, flt equip & new 10' new hole. Conduct formation tst to 12.5 ppg EMW. Drl 8½" hole to 4682'. 56.24% 9-5/8" @ 4558' 7220', (2538'), Drlg Wt. 9.4, PV 5, YP 2, PH 9.5, WL 7.6, Sol 7 Drl 8½" hole to 7220'. 4803', 47.1°, N4.75W, 3811.9 TVD, 2489.0 VS, 2469.9N, 308.0W 5517', 45.0°, N6.75W, 4306.5 TVD, 3003.7 VS, 2981.8N, 363.0W 6183', 43.5°, N6.75W, 4784.8 TVD, 3467.2 VS, 3442.0N, 417.4W 9-5/8" @ 4558' 7910', (690'), Drlg Wt. 9.9, PV 14, YP 9, PH 9.0, WL 7.2, Sol 10 Drl & surv 8½" hole to 7910'. 7252', 44.4°, Nll.75W, 5559.8 TVD, 4202.7 VS, 4168.3N, 536.9W The above is correct Signature For form preparation ar~ distribution, see Procedures Manual,"Section 10, Drilling, Pages 86 and 87. JDate / Title I Drilling Superintendent AtlanticRichfieldComPany Daily Well History-Final Report Instructiona: 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, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District J County or Parish Alaska I North Slope Borough Field JLease or Unit Kuparuk River J ADL 25512 Auth. or W.O. no. ~Title AFE AK1185 J Drill Doyon 9 Operator I A.R.Co. W.I. ARCO Alaska, Inc. Spudded or W.O. begun Date Spudded Date and depth Complete record for each day reported as of 8:00 a.m. 4/12/86 thru 4/13/86 Accounting State API 50-029-21580 ITotal number of wells (active or inactive) on this 56.24% Icost center prior to plugging and I labandonment of this well I lHour I Prior status If a W.O. 4/5/86 / 1830 hrs. I / 7" @ 8777' 8790' TD, 8691' PBTD, RR 9.9 ppg Brine Drl & surv 8½" hole to 8790' TD, 20 std short trip, CBU, POH. RU Schl, log DIL/SP/SFL/GR f/8774' WLM - 4558' WLM. Rn FDC/CNL f/8774' WLM-7300' WLM & CAL f/8774' WLM- 4558' WLM, RD Schl. Make cond'g rn f/7". RU & rn 213 its, 7", 26# BTC J-55 csg + 1 mkr jt w/FS @ 8777', FC @ 8693', Mkr Jt @ 8448'. Cmt w/lO0 sx 50/50 C1 "G" w/8% D-20, .2% D-46 & .5% D-65 & .5% D-112, followed by 200 sx C1 "G" w/3% KCL, .9% D-127, .3% D-13 & .2% D-46. Displ w/9.9 ppg brine. ND BOPE, NU tbg spool &tst to 3000 psi. RR @ 2130 hrs, 4/13/~6. cost center code Alaska Iwa,, n~N_l 1 Old TD ~ New TD PB Depth 8790' TD Released rig Date IK nd of rig 2130 hrs. 4/13/86 I Classifications (o11, gas, etc.) I Type completion (single, dual, etc.) Oil I Single Producing method I Official reservoir name(s) Flowing I Kuparuk Sands Potential test data 8691' 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 % GOR Gravity Allowable Effective date corrected The above is correct Signature For form preparation(e~nd distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent ADDENDUM WELL: 4/24/86 3N-11 Arctic Pak well w/175 sx AS I, followed by 60 bbls Arctic Pak. Drilling Supervisor Date ARCO Alaska, I. 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 04-29-86 TRANSMITTA~ # 5652 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Open Hole LIS Iapes plus Listing: Schl: One copy of each 3B-7 05-25-85 Run ~1 3296.0-7270.0 ~C~I~***~* ~-~ o~-~-~ ~ ~ ~.o-~o o~ ~ ~?_ Receipt Acknowledged: State of AK Date: April 4, 1986 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska ,~ Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Telecopy: (907) 276-7542 Re: 3N-l! ARCO AlaSka, Inc. Permit No. 86- 77 Sur. Loc. !56t'FSL, !55'FEL, Sec. 29, T13N, R9E, Btmhole Loc. 1514'FSL, '817'FEL, Sec. 20, T13N, R9E, 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 by 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. ~here 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. V~., tru~v~¥~urs ~ ~ ¢. V. Chatre-rtOn Chai~n of Alaska Oil and Gas Conservation Co~ission BY ORDER OF THE COM/~ISSION dis Enclosure Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ARCO Alaska, Inc. Post Office Box ~o0360 Anchorage, Alaska 99510-0360 Telephone 907 276 12i5 April 3, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Kuparuk 3N-1i Dear Mr. Chatterton' Enclosed is a Permit to Drill application for Kuparuk 3N-11. We estimate spudding this well on April 4, 1986. We propose to drill this well using the attached diverter diagram. We are therefore requesting a variance for this Kuparuk well. A modification has been planned and should be completed in approximately 4 weeks. The modified system will be operationally equivalent to the new requirements. If you have any questions, ~Regional Drilling Engineer please call me at 263-4970. J BK/LNK/tw PD/L02 Enclosures A RO 3 19B6 ARCO AJaska, Inc. Js a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA O,- AND GAS CONSERVATION CO~,,:vllSSlON PERMIT TO DRILL 2O AAC 25.005 I la. Type of work Drill Re-Entry 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 68', PAD 34' feet Kuparuk Rive~' Field 3. Address 6. Property Designation Kuparuk River Oi 1 Pool P.O. Box 100360 Anchorage, AK 99510 ADL 25512 ALK 2553 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20AAC25.025) 1561'FSL, 155'FEL, Sec.29, T13N, R9E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well nu ,mber Number 1267'FSL, 785'FEL, Sec.20, T13N, R9E, UN 3N-11 #8088-26-27 At total depth 9. Approximate spud date Amount 1514'FSL, 817'FEL, Sec.20, T13N, R9E, UM 04/04/86 $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 8781 'MD 817' feet 25' @ surface feet 2560 (6641 'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth700 feet Maximum hole angle 46 0 Maximum surface 291 5 psig At total depth O'VD) 3347 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) ~4" 16" ~2.5# F~-~O w'~]d 80' 35' 35' 115' 115' ~-~nn ~,f 12~,'~ .9-5/8" HF-Ff;W 8~" 7- 26,0# J-55 BTC 8747' 34' 34' 8781 ' 6641 ' 300 sx Class G HF-EI~W 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 RECE!VFr) Surface IntermediateAPR 0 i986 Production Liner Alaska 0il & Gas Cons. u~,,,mission Perforation depth: measured Anchorage true vertical 20. Attachments Filing fee Drilling fluid program_..__,~ Time vs depth plot 21. I hereby certi~tha~ the foregoing is true and correct to the best of my knowledge Signed Title Regional Drilling Engineer Date Commission Use Only ( LWK ) PD/PD248 APl number I Approval date I See cover letter Permit Number ,'¢~" ?¢ 50-- ¢'2.-?- 'Z/.~_~-~ 4/4/86 for other requirements I I Conditions of approval Samples required f~ Yes [] No Mud Icg required ~ Yes ~ No Hydrogen sulfide measures ~ Yes 1~ No Directional survey required '~ Yes ~ No Required working pre~ssure for BCP-~ ,~.,21VJ; .~ 3M; ~ 5M; © 10M; ~ 15M Other: ~/~/,,.,//~~ by order of 4/4/86 Approved by Commissioner the commission Date Form 10-401 Rev. 12-1-1 } Submit in triplicate J T ~ 6 5 4 3 2 DIAGRAM #1 I..~-5/8" ...hOD PSi RSRRA BC;P STACK I. 16' - 2000 PSI TAt~CO STARTII'~ 2. 11' - .3000 PSI CA.SING I-F_AD 3. I1' - 3000 PSI X 13--5/8" - ~ PSI SPAQ~ 4,. 13-5/'8' - 5000 PSI PIPE 5. I,,3-5/8' - 5000 PSI DRILLIN3 SPOOL W/O-O<E AN:) KILL LI~_S 6. 13-Er'8' - 5000 PSI DOUBLE R.AM W/PIPE R,AVB Cig TCP, '7. 13-~8' - 5000 PSI ACCLMJLAT~ CAPACITY TEST I. OEO( AND FILL A~TCR RESE]2VOIR T0'PEESPF_R LEVEL WITH HYDRAIX. IC FLUID. 2. ~ TNAT A~TOR PR~SSU:~ IS 3COO PSI WITH I~ PSI ~TRF_AM OF ~ Rt~GUL.ATCI~. 3. OBSER~ TI~E, T1-6N CLOS~ ALL UNITS SINtJLT~OJSLY ANS) FF~ THE TI~E At~D PRESSLR~ RE]VAINING AFFER ALL UNITS ARE CLOSED WITH CIHARGIN3 ~ CLX', 4. RECO2D ON NADC REPCRTo TI-E ACCF_PTABLE LCIAE~ LIMIT IS 4S SEOSNS~ CLOSING TINE: AN3 1200 PSI RE1~INING PRESSL~. RECEIV,tF.. ,.h APR 0 3 1986 --~ Alaska Oil & Gas Cuns. uumtmssion 13-5/8" BC:P ~I~QeTEST I. FI~ B~ STA~ ~ ~ ~IF~ WI~ ~IC DIE~. 2. ~ ~T ~ L~ ~ ~ IN ~~ ~ ~Y ~RA~. ~T %~T ~ IN ~~ WI~ ~I~ ~ ~ ~ IN L~ S~. 3. ~ ~ ~ ~ ~~ KZLL ~ ~ LI~ V~VES ~~ ~0 ~ STA~ ~L ¢~ V~S ~ ~ ~ ~ ~. 4. P~~ ~ TO 2~ ~~ F~ I OMIN. I~ ~ ~~ TO ~ RSI~ ~ F~ I0 MIN. BL~FD ~~ TO 0'~ LZ~ VALVES. ~E T~ PIPE ~ ~ ~ VALVES ~ K~LL ~ ~E L~S~ 6. TEST TO 2~ PSI ~~~ IN ST~ 4. ~. ¢I~ TESTI~ ALL V~VES, LI~S, ~ ~S WITH A ~ PSI L~ ~ 3~PSI HI~. TEST AS ST~ 4. ~ ~T ~~ TEST~ ~ ~T ~S .~T A .~_L ~~ p~I~]VE ~ ~ ~Y 8. ~ T~ PI~ R~ ~ ~ ~~ PI~ R~. TEST B¢~ PIPE R~ TO ~ ~I ~ ~ 9. ~ B~ PIPE R~, ~ ~ ~I~ ~ ~ .10. ~ ~I~ ~ ~ TEST TO 2~ ~I ~.~ PSI. II. ~ ~I~ R~ ~ ~I~E ~ST ~. ~ S~ ~UID. ~ A~ VALVES IN ~I~I~ P~ITI~ - I~. TEST STRIPE VALVES, K~Y, ~Y ~S, ~ILL PI~ S~Y VALVE, ~ I~I~ B~ TO ~ PSI 3~ RSI. 13. RE~ TEST I~~TI~ ~ ~~ ~ TEST 14. P~~ ~ETE B~ ~ST ~ NI~I~ ~ ~Y TH~~~ ~I~LY ~~ B~ ~ILY. KUPARUK RI VER UNIT 20" -DI VERTER SCHEMAT I C DE S CR I P T I ON i. I G · C~CTOR. 2, TANKO STARTER HEAD. 3. TAI~O SAVER SUB. 4, TAI'~O LO~ER OJICK-C~CT ASSY. 5, TAI~<O UPPER COICK-CONNECT ASSY, 6. 20' 2000 PSI DRILLING SPOOL W/I0' -OOTLETS. "f. I0' HCR BALL VALYES W/lO' DIVERTER LINES, VALVES OPEN AUTOMATICALLY UPON CLOSURE CF AI~I.)LAR PREVENTER. 8. 20' 2CX::X:) PSI AI~t, iJLAR PREVENTER° R£c£iVF, D APRO ~ 1986 Gas ConS, t;u~miSsi0~ Anohorage MAINTENANCE & OPERATION __ 2 I. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVES HAVE OPENED PROPERLY. 2. CLOSE ANINULAR PREVENTER AND BLOW AIR .THROUGH DIVERTER L:[NES EVERY 12 HOURS. CLOSE Ab/NULAR PREVENTER IN THE EVENT 'THAT AN INFLUX OF ~ELLBORE FLUIDS OR GAS IS DETECTED. IF NECESSARY, MANUALLY OVERRIDE AND CLOSE APPROPRIATE VALVE TO ACHIEVE DONNWlI'~ DIVERSION, DO NOT SHUT IN ~ELL UI~E>ER ANY ClRCUMSTA~ES. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS 1. Move-in rigA. 2. Install Tankco diverter system, 3o Drill 12¼" hole to 9-5/8" surface casing point according to directional plan. 4. Run and cement 9-5/8" 5. Install and test blow out preventer. 6. Drill 8½" hole to logging point according to directional plano 7o Run open hole logs. 8° Continue drilling 8½" hole to provide 100' between plug back total depth and bottom of Kuparuk sands. 9. Run and cement 7" casing. 10. Downsqueeze Arctic Pack and cement in 7" x 9-5/8" annulus. 1io Nipple down blow out preventer and install temporary Xmas tree. 12o Secure well and release rig° 13. Run cased hole logs. 14. Move in workover rig° Nipple up blow out preventer. 15. 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. 16o Perforate and run completion assembly° 17. Nipple down bl°w out preventer and install· Xmas tree. 18o Change over to diesel and set packer 19o Flow w~ll to tanks° Shut in° 20° Secure well and release rig° DPROC/G1 /ih Degos~er fto~ ~rr~S DEGA$$ER j DRILLING FL[lID floe' De s o n~er $uc1 ion DES~NDER' STI~ Ilo J, Deli It~r REMOVAL STIR Spud Mud (To Surface Casing Point) ADDITI~)N ' u=....~ STIR o~j..,~u~- STIR floe' lo~le Use polymer mud salvaged from previous well. Adjust funnel viscosity to 150-200 sec/qt (25-35 YP) and maintain as needed for effective hole cleaning. Allow viscosity to come down as hole cleaning requirements are reduced to accommodate finer shaker screens. Funnel viscosities of 50-80 sec/qt should be adequate below the initial gravel zones. Run all solids control equipment to reduce solids content. Thin mud back to 15-25 YP before cementing surface casing. Refer to attached surface casing running and cement procedure. Bo Nondispersed Polymer Mud (Surface Shoe to 400' above Ku. paruk) Drill out from surface casing shoe and change over to nondispersed polymer mud. A portion of the spud mud can be conditioned with water and mechanical equipment to a funnel viscosity of 30-35 and a mud weight of 8.8-9.2 ppg. to be used as the:base fluid. Keep clay content around 15 ppb. Keep the"pH 9.5-10.5 with'Caustic'Soda through this interval. Use XC Polymer (.25-.75.ppb) :to adjust yield point.as needed for good hole claaning~ Initial YP should be in the' 8-12 range and increase as dictated by actual hole conditions. : The mud system will be dispersed after Kuparuk is drilled (after running logs). However, all efforts should be made so maintain the nondispersed system ~o that point. Run the fines= shaker screens as possible. Run the mud cleaner as a desilter, and along with the desander, discharge the underflow from the comes to the reserve pit. Use the centrifuges on the active system ~o strip solids and recover the liquid phase. Ce Weishted Pot.vmer Mud (400' above. Upper Kuparuk) Adjust mud weight to 10.3 ppg 400' above the Upper Kuparuk. Use mud cleaner and apply centrifuges as'necessary to avoid excessive drilled solids buildup. PAD 3N, i WELL NO. 1-1 PROPOSED - :: -" / Il ........... KUpARUK__FIELD_,..__.N__OR_IH SLOPE-, ALASKA / EASTMAN WHIP. STOCK:,: INC. "- i ..... : .... ~ _. . . ~. ; ; ...... _ .. :_.;. . : =' .... - . . . ~ ............. ~ _ .............. 0 ._SURF^C~ ' - ' __.:.. ..... : . : - : i P TVD=700 TMD=?O0 DEP=O · ~_ooO__L'..-_ ' ? .... ~ ', ' . ..... _- i - [ __' '' BUILD ,3 DEO-} ..... i ..... · ~., 15 .... , PER 100 ~ ~ -' : : .... ; , ' : ' '_ ; ....... 33 .............. i .... i _ ! .... : . . .~ .. _ .... ~i------20OQ~.,_. ~i-ZEoc----.r_v ~2069: T MD= 2!26,DEF,=57:8 ................................ ~ / '-;- --' 7;. ;;- --~ ToPw SAK SNDS TVD=3, 87 TI'ID-3829 DEP-1727 2 J i_ i____ .... i} _"..' ..... .... _.'"N K-1 2 TVD=3427 TMD=41 ~'3 DER=I 973 - o 1 ...................... .~.?- 9 5/8' 'CSO pT ..... r--> J /'~- TVD=3627 THD=4460 DEP=2179 4ooo-t ............................. : ........... . .......... ................. = I AVERAGE ANGLE ~ ......'-I:........ ~'5'[jE~t~-4S" i ~ ~ .X ..... ---;------ ...... .-""'""-I ................... ----- ............................................. ....... ___~__i ........ ~ ........... Z-,K---5 ..... -TvD=551T--TMD=-7-1-70.-DEP 41.21-- ............ . ................ ~,~,,: .......................... -~ .... !"-;_ ' ~' -~I'~ .... ~_i:~;. i-;-_';;i _'__.~-)-:--_-_~_:-:_'i_;:i~_.~_;~. _ ~'7_:..-.-;;: :, ..... :- . . i ~i.i.i .... . ~:_ i-_ ....... T/ ZONE'A~ TVD=6398!TMD=8433 DEP=5026 ....... r ..... ~ T-^ROET--- CN TR----T-¥D= 6450--1 ~D= 8508 -D£P= 5079 _ i .'~'~ 8/-KUP' SNDS_ .TVD=6501. TMD=8581; DEP=5132': ........... : ...... . - -- ~ - - TD (LOG PT) TVD=6641. -TMD=8781 .-DEP=5275 - ---_~_~...-.Tnnn. - - - -:- ' - ! ..... : ............ ~ ..... ~ ....................... - .......................... .... _; _ __;_ - - [ ..... , ............. ; .................................... - _ ; ~ . .... .: o:; .......; ~ 0o0 ; _- "-i~ 2000 ' 3000"-' .......~,000' 5000 6000" ' --.-_-%'; ............ ~:- . . - ! - ! . _ .'. ..... , .............. , .... ; ~ , - : - . .... , ..... · ....... :~. ............. ~ ....... ~ HOR I7 ON TAL~ ._PRO JEC T I ON ~_ t ,LE 1.IN..= 1000 FEET . .................. -, ...................... ~ ........ .-~ ................... . ................................... PAD 3N.-WELL NO~ l l'iPROPOSED i ' · KUPARUK FIELD,-NORTH:SLOPE, ALASKA :. _ .................................. i L,_i_ .- /_ WEST_EAST ...... 3000 '2000 1000 0 6000 ' I' '- i .... I . . · TARGET LOCATION,-' 1320' FSL, ?92' FEL SEC. 20. T13N. RgE _. 1000 TD LOCATI Old ~ 1514.' FSL, 817" FEL ............. SEC'..20. T13N. RgE ' - TARGET CENTER 4000. -TVD=6450 " THD-8508 - DEP=50?9 - · . NORTH 5039 WEST 638 z :3000 -- ' .... ~ c~.' .................. - - ....; ~ -.~ .................. ~" "~ ~-ZL ~'~-' ?' ~;;;=-=~ -5~]-~T- ~ .... ~ ........ ,--'_. -~; ............... ~ ~ ......... ~ .... ~.~ ._. : .... ~---~'~ 1~1' FSL. I~' FEe ........... SEC. 2g, T13N, R~ . - ............ ~ ..... ; . _ . . .............. ;. :;:.._ ;;. ~.ooo ...... ''-~;:-;N; .... 7-:.-DEG: .... t-3 .... H-t N .... W- ............................................. - · - ' ....- :-:;5079' (TO TARGET). ' ' 800 ~700 .6O0 1',500. 11400 0 3O0 200-i I 300 4.00 i , 500 ' ! , i " I · . ! I 400 .. _. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 31, 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 - 3N Pad (Wells 1- 18) Dear Mr. 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 GRU13/L45 Enclosure If .. Alaska Oil ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldComl~any Il II I . ~ I ~ I ~ . 20~21 !LOCA~TED IN PROTRACTED SEC', 28 & _9, T15 N, RgE,U.M. --'" ?_9 ~THIS SURVEY~ ~ ~' ~ ) '~~ ' LOCATED IN PROTRACTED LOCATED IN PROTRACTED SEC. 29, T~N~ RgE~ U.M. SEC 29~TI3N~ RgE~ U M ~ 1 - Y = 6,013,799.67 LAT. 70~26'55.9615'' 10 - Y = 6,013,799.37 LAT. 70°26'55.9519" X = 517,946.19 LON6.149o51'12.938" X = 518,~Z1.07 LONE.149o51'04.865'' 454' FEL 1562' FSL 0G ' 28 2 PAD = 33.7 179' FEL, 1561' FSL O~ : 28.5 PAD = 34.0 2- T = 6,013,799.65 LAT. 70~6'55.9606" 11 - Y = 6,013,799.32 LAT. 70~26'55.9508.'' X = 517,971.21 LONE. 149~51' 12.~03" X - 518,246.03 LONG. 149°51'04. 132 429' FEL, 1562' FSL 0~ = ~8.~ PAD = 33.8 !55' FfL, !561' FSL 0~ = Z8.5 PA~ = 33.8 3 - Y : 6,013,799.54 LAT. 70026'55.9590" 12 - Y = 6,013,799.45 LAT. 70~26'55.9515'' X = 517,996.25 LONE. 1~9~51' 11-468'' X = 518,270.89 LONG. 149~51'03.403" 404' FEL, 1562' FSL 06 = 28.4 PAD : 33.9 130' FEL, 1561' FSL 0G = 28.5 4 - Y = 6,013,799.50 LAT. 70~26'55.9580" 13 - Y = 6,013,799.41 LAT. 70~26'55.9505 [~ X = 518,921.16 LONG. 149~51' 10.736" X = 518,295.97 LON~. 149~51'02.666' ~ FSL OG = 28.5 PAD = 34. ~ 379' FEL, 1562' ff$L 06 = 28 4 PAD = 33.7 105' FEL, 1561' 5 - y 6,013,799.~ LAT. 70~26'55 957~" = . .~ 14 - ~ = 6,013,799.33 LAT. 70~6'55.9491" X = 518,046.18 LON~. 149~51' 10.00Z" ~ X = 518,3~0.91 LONE. 149~51'01.934'' 354' FEL, 156~' FSL 0~ = 28.5 PAD = 33.7 ~ ~ 80' FEL, 1561' FSL OG = 28.5 PAD 6 - Y ~ 6,013,799.44 LAT. 70~26'55.9562'' ~ (O ~ 15 - Y = 6,013,799.28 LAT. 70~26' 55. 9480" X = 518,071.24 LONG. 149~51'09. 266" ~ X = 518,345.77 LONE. 149~51'01. ZO4'' 3~9 ~EL, ~56Z' FSL O~ = ~8.5 PAD = 33 9 ~ C~ ~ ~ ~ ' ' . ~ ~ ~ 55 FEL, 1561 FSL 0G = 28.5 PAD = 34.0 7 - Y = 6,013,799.~4 LAT. 70~26'55.9556" ~ - ~ ~ ~ 16 - Y = 6,013.799.25 LAT. 70~26'55.9471" X = 518,096.21 LON~'149o5I'08'533" ~ O ~ ~c) X = 518,370.74 LONE.149o51'00.470" 304' FEL, 1561' FSL OG = 28.5 PAD = 33.9 ~ ~ ~ ~ 30' FEL, 156i' FSL OG : 28.5 PAD : 34.1 8 - Y = 6,013,799.45 LAT. 70~26 ' 55. 9551'' ~ ~ ~ 17 - Y = 6,013,799.26 LAT. 70026'55.9466'' X = 518,121.15 LONG. 149°51'07.800" X = 518,395.63 LONG.149050'59.739" 279' FEL, 1561' FSL OG : 28.6 PAD : 33.9 ~ ~ ~ 5' FEL, 1561' FSL OG = 28.5 PAD = 34.1 9- Y = 6,013,799.42 LAT. 70026'55.9542" ~ X = 5!8,146.15 LONG. 149~51'07.066'' c~ SEC. 28,TI3N, R9E, U.M. 254' FEL, i561' FSL OG = 28.6 PAD = 34.0 ~ 18 - Y : 6,013,799.15 LAT. 70026'55.9449'' X = 518,420.80 LONG. 149°50' 59.000'' NOTES ~0' F~L, ~6~' FSL 0G: ~.~ ,~ I. ALL COORDINATES ARE A.S.P.,ZONE4. 2. SECTION LINE DISTANCES ARE TRUE. ,~ 3. HORIZONTAL POSitrONS BASED ON ON-PAD PILING CONTROL PER LHD & ASSOC. i! 4. VERTICAL POSITIONS BASED ON MODULE PILES 3JOI -8 ~ 3J01-4. 5,0. G. ELEVATIONS INTERPOLATED FROM S/C DRAWING CED-RIXX-3090 rev,~, ~ ~ e~eeeee :F '~ MADE BY ~IE O~ uN~E~ MY S~,PE~'/IS;ON , AND ~ ~ ee ~ I -~ ...... M~S O~S AN~' OTHER DET~'~S ~ ~" ~:, 1 :, ~ ~ ~ ,~,:y~3 ~Nn ~ A~CU AIOSKO, Inc. ~,~~ ~, : JU,[ ': w. DRILL SITE 5N CONDUCTOR tc %;. CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (1) Fee Zz/~,_ ~- ~ ~"~ 1. (2) Loc //~._. 'V'"t/. ~ (.. thru 8) (23 thru 28) Company /~//!C.o Lease & Well No. YES. NO 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 .... 14. 15. 16. 17. 18. 19. 20. 21. 22. Does operator have a bond in force .... , ............................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate .............................. ~~ ' Does the well have a unique name an~'~umbe~ . . ~..i .... " Is conductor string provided ........................................ Will surface casing protect fresh water zones ....................... Is enough cement used to circulate on conductor and surface ......... ~ ... Will cement tie in surface and intermediate or production strings ... ~ .. Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore .............. Is old wellbo're abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ 23. 24. 25. 26. 27. 28. Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to t~O~O psig .. Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. REMARKS (29 thru 31) (6) Add: .Geology: Engineering: WVA~ MTM HJH ~$~' J~ rev: 04/03/86 6.011 For exploratory and Stratigraphic wells: 29. Are data presented on potential overpressure zones? ................. 30. Are seismic analysis data presented on shallow gas zones ............ 31. If an offshore loc., are survey results of seabed conditions presented 32. Additional requirement~ ............................................. ~_ POOL INITIAL CLASS STATUS GEO. I UNIT AREA NO. ON/OFF SHORE Additional Remarks: O ~0 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. ********************** ~ - h ~ ~ ~ ~ . ~ w ~ ~ ~ ********************** *-------~~---------~-* *----SCHLUM8ERGER----* *--------------------* ~~¿~~~h¿h~~~~&..~h~.¿~ ¥¥..~~~¥¥¥¥¥¥¥¥.¥¥¥.¥Y LIS T~PE VERIFICATIO~ lISTING """"""""""""""-,.",,,',,..' /( l-LttL r be k 3 ¡Y- II [ò p-en htJ Ie) -4f' C) ~ C¡S7 MI(ROfIL~£D Date -, \. RE.(EIVED r. ,1l'\\l~' ~ r'ì ,M¡ ,... 'iJ ¡"" :.ì""', ; '.. '-, h . I '..) ,¡""u',", A!a3~œ Oil & Ga3 Cons. Commission Anchorage .V? OlO.HO2 VE~IFICATrON LISTING ~~ DFt-L H~A'DcR h~ , ~ ~- ~,~ ~Y ;E~VICE NA~E :EDIT )ATE :36/04/19 lR I GIN: ~EEL NAME :149306 :DNTINUATION # :01 ?R E V IOU S RE E L. : CO~~ENTS :LISRARY TAPE ~* TAP E H E A DE R 1.=~::; S~RVICE NAME :EDIT DATE :86/04/19 Q"RIGIN :FS1A TAPE NA\1E : ~"ONTINUATION #. :01 PREVIOUS TAPE: C.D~~ENTS :LIBRARY TAPE ~h~~'~~~~~~ _OF ~~~hhhh~.. ',"""""'1""""""""",....., I: """"'\"""""',"""('0"""" , \ *'* FILE HEADER ** 6,;1 LE " N A r~ E : ED IT. 001 S'iER\¡' ICE N A ME' : gqll,,~I~N ## : MAXIMUM LENGTH: 1024 f=iILE TYPE: ~:R E V IOU S PI L E : "." ** IN FOR MA T I Q N RE COR 0 S ~:(* ~:ii,M., ..C,GN;:f.6N$"S.", ---- "" -----Ô!"-- Ci'N : WiN': "iN : RA.~ G : .I.",awN: ¡('E C T : CD J N : $T.A r: r.1.N E M AReo ALL\SKA, IN::. 3N-l1 KUÞARUK 96 13N 29 NORTH SLOPE ALASKA CONTENTS 'i.J N r~; ____" .,--- -------- , :rXP;E " ,C,AI.J; ---,- -...-- PAGE 1 -,--- $"lZ"E " "CDoe" 018 006' ,008 0.02 004 OD2 012 006 51 z: E ---- ---- 065 {fóS 065 065 0.65 06'5' 065 065 CODE ---,- PRES: E 000 000 001 065 *~c COMMENTS **. !Jt~..... J~ ,'.... "" ,'. J",'" .'~ ,,* "...I~"".... i'."¡. ,I. ..J. ."".'. ..1.. oJ.. .'. oJ. ,'. .'. ,I. .'" oJ...... .".." .'. oJ.. "'~'..,.¡" "'..~/".,J. ....' ......... J.. ""-':; ,"" ..J..",J..I.,'. ,Î. *'" ",..ø.. J...f. ,'" ~.. ...... ¿, ..'.. 'J.. ,J.. ..'" ..,..* ~ ..... J.. h ~..'.. .1...1.' .... * .... * ......,.. ,.c.. J..,~ "t'..,.. '...' 'I'" '.",' .... """","""f".... '('0 '." "" ,-," """,""'1" 'I' .,.. '."," .... -"" "I'-" .,"',."" ,,' -,' .... ',"," ... ... ... ...' ..., "I"," .("... .; ~ ..,. '..." Ii/. .... .... ..' ", ~,.,..,.. '," '," ..." .,.. ..... '.. .... .." "" "" 'f" i¡¡ ...'," ',' ..,...,...,.. '...... "'1""'" '., ...... 000 000. 000' 000 000900 000 000 000 000 000" 000 000 000 OOD 000 TYPE CATE ---- ---- ~.,.,"," .."_.....,"~,,,' "'-" "."'",.,'."'..., -"':-""""""""""""",""~""-"""'."".'.."'.,"..:."""""",.~",.,.:-,.,...", ",,""""""."" -""'" .""-""""""""""""""""""- / -v~ OlD.HO2 VERIFICATIJN LISTIN~ P,~C;E ,') "- ..,. ..~ h 't' SCHLur'13ERGER ALASKA CJM?UTIN~ CE~TER ,',. ...~ ,'.. "i' ************************************************************~*********************** CO~ÞANY = ARC~ ALASKA INC WELL = 3N-1'1 FIELD = KUP~~UK COU~TY = NORT~ SLOPE 30ROUGH STATE = ALAS<A JOB NUM9ER AT Ace: 11410 RU~ #ONS, DATE LOGGED: 12 ~PR 85 LD?: T"iALSTEAJ CASING = 9.62511 ~ 4558' TYPE FLU!:) = LSND DE~SITY = 3.9 La/G RM = 4 440 @ VISCOSITY = 31.0 S RMF = 4.980 @ ~H = 9.5 RMC = 3.870 @ FLUID LOSS = 6.4 C3 RM AT 8HT = 1.873 @ MATRIX SANDSTON~ ~*::o;~~; THIS DATA HAS NOT BEEN DEPTH SHIFTED - OVERLAYS FIELD PRINTS ::~***~; ~~~~~~h~~¿h.¿~~~~.~~~~.~.~~h~~~~.~h~h~.~~*h.~~*.~h.~*"*.**~.hh*~h~~hh~*hh~*~hh¿~ 't"'I""~"" ""~',~""""""¥"(o¥',"'i"""""""""-¡"""""'f""i"""¥""'"~'I""""""f""""I"""""¥'~<"I"'t~"""""""""""" ,........,~¥"'" ',.. ""¥"'~"" ....."i"""....""'i"{'o .i"""'i"r'r"'I"'I"""""""~ 5IT SIZE =8.5" TO 8790" 55 OF 5S OF 55 OF 140 OF ."',',' .""".~'~".""""""""""""""",,""",""'..,"..-,.",.,_...-....,."",.,........""..~......,..~"".."",.."'""",,"""" LVP OlO.HO2 VERIFICATra~ LISTIN~ PAGE 3 * * * * * * * * * * * * * * * * * * * * * * * ~ * * * * * * ~ h ~ .~ * SCHLUMaERGE~ lOGS INCLUDED WITH T~IS MAGNETIC TAPS: * h ~ ¥ . * DJAL r~DU:TIJ~ SP~ERICALLY FOCUSEJ LOG (OIL) * * DATA AVAILAB~E: 8768' TO 4558' * h ~ ¥ ~ * FJRMATION DENSITY COMPENSATED LOG (FDN) * * C)MPENSAT=D ~EUTRJN L3G (FDN) * * DATA AVAILAB~E: 3742' TO 7250' * h ¿ ~ ~ * GAMMA RAY IN CASING (SR.CNL) * * DATA AV~ILABLE: 4600' TO 2400' * ~ ~ ~ ¥ ~ h ~ ~ ~ ~ h h h ~ ~ ~ ~ ~ h h h ~ ~ ~ ~ ~ ~ ~ ~ ~ h ~ . ~ ~ y ~ ~ ~ ¥ ~ ¥ ? ~ ¥ Y ¥ ¥ ~ ¥ ¥ ¥ ¥ ~ ~ ~ ¥ ¥ ~ ~ ¥ ¥ ¥ ¥ ** DATA FORMAT RECORD ** EN TRY 13 L 0 C K S SIZE 1 1 4 4 1 1 R~PR CC)E 66 66 73 65 66 66 ENT~Y 0 1 - 60 .1IN 1 0 TYPE 2 4 a , 1S 0 ¡jATUM SPECIFICATION StaCKS MNEM SERVICE SE~VICE JNIT ..', IO 0 R DE R # erE PT FT ;,SìFl.lJ D It QriMM, API API API API FILE LOG TYPE CLASS MOD ~D. 00 000 00 0 0 ,,00220 01, G ' {), SIZE SPL REPR PROCESS CODE (OCTAL) 4 1 68 UOOOOOQOOOO~OO itl 68 OOQJJO 00000,0.0.0.0 ,.,,'... " . .' """",'" "'" ... LV P OlO.HO2 VERIFICATI J\4 LISTIN~ ?~GE 4 ItD OIL 0 "H~ ~1 00 120 46 0 0 4 1 63 00000000000000 ILM JIL JiMM 00 120 44 0 ., 4 1 63 000.00000000000 '.I SP OIL M:V 00 010 01 a a '+ 1 69 00000000000000 ;;R OIL G!\PI aD 310 01 a :') j '\ 63 00000000000000 >.I .... ... GR FJN :;~p I 00 310 01 0 0 4 . 53 00000000000000 J. CALI FDN 1\4 00 230 01 0 0 4 1 68 00000000000000 RHJ3 ;:)N ";/C3 00 350 02 a 0 4 1 68 00000000000000 DRiiJ FON :;/C3 00 356 01 0 I) 4 ' 6.3 00000000000000 ... ~RA T FDN 00 420 01 0 0 4 ' 53 00000000000000 J. RNRA FDN 00 000 00 0 ... 4 1 58 00000000000000 v NÞHI FaN PJ 00 890 00 0 0 4 '1 58 00000000000000 N.CNL FJN ""'?- 00 330 31 0 0 4 1 68 00000000000000 1.,,::> FC~L FDN r-ps 00 330 30 0 0 4 1 58 00000000000000 1,.., GR C~L GAPI 00 310 01 0 :"\ 4 1 63 00000000000000 <¿ J- <J- DATA ,'.. ,'- """1" '(" '," DEPT SP RHaf:) N,P HI OEPT SP RAOB ~;pHI OtEPT s,p R,HOB NP'HI Q:,EPT SP a,M."c}ß<. 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