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186-028
Originated:Delivered to:15-Dec-20 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 2V-02 50-029-21037-00 906786479 Kuparuk River Multi Finger Caliper Field & Processed 30-Oct-20 0 1 2 2V-02 50-029-21037-00 n/a Kuparuk River Hole Finder Record Field- Final 8-Oct-20 0 1 3 2V-02 50-029-21037-00 n/a Kuparuk River Packer Setting Record Field- Final 10-Oct-20 0 1 4 2V-02 50-029-21037-00 n/a Kuparuk River Hole Finder Record Field- Final 25-Oct-20 0 1 5 3C-12 50-029-21354-00 906791278 Kuparuk River Multi Finger Caliper Field & Processed 28-Oct-20 0 1 6 3C-12 50-029-21354-00 906786466 Kuparuk River Packer Setting Record Field- Final 28-Oct-20 0 1 7 3N-07 50-029-21539-00 906745120 Kuparuk River Multi Finger Caliper Field & Processed 3-Oct-20 0 1 8 3S-03 50-103-20458-00 n/a Kuparuk River Plug Setting Record Field- Final 3-Oct-20 0 1 9 10 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: Received by the AOGCC 12/16/2020 12/16/2020 Abby Bell PTD: 1860280 E-Set: 34423 Originated:Delivered to:16-Oct-20 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 3B-13 50-029-21286-00 906617822 Kuparuk River Plug Setting Record Field- Final 22-Jul-20 0 1 2 3H-20 50-103-20093-00 906518944 Kuparuk River Leak Detect Log Field- Final 2-Jul-20 0 1 3 3N-07 50-029-21539-01 906614634 Kuparuk River Plug Setting Record Field- Final 23-Jul-20 4 3N-07 50-029-21539-01 906604302 Kuparuk River String Shot Record Field- Final 16-Jul-20 5 3N-07 50-029-21539-01 906659750 Kuparuk River Leak Detect Log Field- Final 21-Aug-20 6 2K-04 50-103-20099-00 906595531 Kuparuk River Multi Finger Caliper Field& Processed 9-Jul-20 7 2K-04 50-103-20099-00 906595531 Kuparuk River Plug Setting Record Field- Final 8-Jul-20 8 3A-17 50-029-22691-01 906634080 Kuparuk River Plug Setting Record Field- Final 2-Aug-20 0 1 9 3K-23 50-029-22771-00 906648363 Kuparuk River Tubing Punch Record Field- Final 10-Aug-20 0 1 10 3N-19 50-029-23056-00 906659750 Kuparuk River Leak Detect Log Field- Final 21-Aug-20 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: 0 1 0 1 PTD: 1860280 E-Set: 34118 Received by the AOGCC 10/16/2020 10/20/2020 Abby Bell Originated:Delivered to:16-Oct-20 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 3B-13 50-029-21286-00 906617822 Kuparuk River Plug Setting Record Field- Final 22-Jul-20 0 1 2 3H-20 50-103-20093-00 906518944 Kuparuk River Leak Detect Log Field- Final 2-Jul-20 0 1 3 3N-07 50-029-21539-01 906614634 Kuparuk River Plug Setting Record Field- Final 23-Jul-20 4 3N-07 50-029-21539-01 906604302 Kuparuk River String Shot Record Field- Final 16-Jul-20 5 3N-07 50-029-21539-01 906659750 Kuparuk River Leak Detect Log Field- Final 21-Aug-20 6 2K-04 50-103-20099-00 906595531 Kuparuk River Multi Finger Caliper Field& Processed 9-Jul-20 7 2K-04 50-103-20099-00 906595531 Kuparuk River Plug Setting Record Field- Final 8-Jul-20 8 3A-17 50-029-22691-01 906634080 Kuparuk River Plug Setting Record Field- Final 2-Aug-20 0 1 9 3K-23 50-029-22771-00 906648363 Kuparuk River Tubing Punch Record Field- Final 10-Aug-20 0 1 10 3N-19 50-029-23056-00 906659750 Kuparuk River Leak Detect Log Field- Final 21-Aug-20 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: 0 1 0 1 Received by the AOGCC 10/16/2020 PTD: 1860280 E-Set: 34117 10/20/2020 Abby Bell Originated:Delivered to:16-Oct-20 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 3B-13 50-029-21286-00 906617822 Kuparuk River Plug Setting Record Field- Final 22-Jul-20 0 1 2 3H-20 50-103-20093-00 906518944 Kuparuk River Leak Detect Log Field- Final 2-Jul-20 0 1 3 3N-07 50-029-21539-01 906614634 Kuparuk River Plug Setting Record Field- Final 23-Jul-20 4 3N-07 50-029-21539-01 906604302 Kuparuk River String Shot Record Field- Final 16-Jul-20 5 3N-07 50-029-21539-01 906659750 Kuparuk River Leak Detect Log Field- Final 21-Aug-20 6 2K-04 50-103-20099-00 906595531 Kuparuk River Multi Finger Caliper Field& Processed 9-Jul-20 7 2K-04 50-103-20099-00 906595531 Kuparuk River Plug Setting Record Field- Final 8-Jul-20 8 3A-17 50-029-22691-01 906634080 Kuparuk River Plug Setting Record Field- Final 2-Aug-20 0 1 9 3K-23 50-029-22771-00 906648363 Kuparuk River Tubing Punch Record Field- Final 10-Aug-20 0 1 10 3N-19 50-029-23056-00 906659750 Kuparuk River Leak Detect Log Field- Final 21-Aug-20 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: 0 1 0 1 Received by the AOGCC 10/16/2020 PTD: 1860280 E-Set: 34116 10/20/2020 Abby Bell L \`l \' WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. August 6, 2012 Attn.: Howard Okland • 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Radial Cement Bond Log: 3N -07A Run Date: 8/5/2012 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 - 07A Data in LAS format, Digital Log Image files 1 CD Rom 50- 029 - 21539 -00 Cement Bond Log 1 Color Log 50- 029 - 21539 -00 SCANNED APR 2 4 2013 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton V6 ireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com Date: Signed: 7 7 • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a. Well Status: Oil 1 Gas ❑ SPLUG ❑ Other ❑ Abandoned"j • Suspended 1 b. Well Class: 20AAC 25.105 20AAC 25.110 Development Q • Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Service ❑ Stratigraphic Test 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. or Aband.: July 6, 2012 • • 186 - 028 / 312 - 113 00 � 3. Address: 6. Date Spudded: 18. API Number: 00 y yiVI- . P. O. Box 100360, Anchorage, AK 99510 -0360 March 1, 1986 50-029-21539X WI 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 1561' FSL, 304' FEL, Sec. 29, T13N, RO9E, UM • March 6, 1986 3N - 07 Top of Productive Horizon: 8. KB (ft above MSL): 61' RKB 15. Field /Pool(s): 1257' FNL, 821' FEL, Sec. 29, T13N, RO9E, UM GL (ft above MSL): 34' AMSL Kuparuk River Field• Total Depth: 9. Plug Back Depth (MD + TVD): 1015' FNL, 1004' FEL, Sec. 29, T13N, RO9E, UM 2415' MD / 2414' 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 518096 y 6013799 Zone 4 • 7793' MD / 6732' TVD ADL 25521 - TPI: x - 517567 y - 6016259 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 517391 y - 6016500 Zone 4 SSSV © 1817' MD / 1817' TVD 2557 18. Directional Survey: Yes ❑ No 0 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 2420' MD / 2419' 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 CBL 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 35' 115' 35' 115' 24" 235 sx CS II 9.625" 36# J -55 37' 3691' 37' 3634' 12.25" 1070 sx PF "E ", 280 sx Class G 7" 26.0# J -55 31' 7707' 31' 6669' 8.5" 310 sx Class G, 175 sx ASI 24. Open to production or injection? Yes ❑ No 0 If Yes, list each 25. TUBING RECORD Interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 2.875" 7156' 7045' MD / 6175' TVD and perfs plugged off: 7163' MD / 6263' TVD 7349' - 7356' MD 6402' - 6407' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7407 MD 6446 TVD % 4 2Ci,S, DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 7443' -7465' MD 6472' -6489' TVD s atiat) AP cement retainer @ 6900' MD 2 cement plugs from 2367' -3653' 132 sx Class G and 222 sx Class G 6034' - 7034' 200 sx Class G cement plug 6821' -7450' 94 sx Class G 2208' - 3354' 150 sx Class G 27. PRODUCTION TEST Date First Production Method of Operation (Flo w in_g,..gastift•ttc.) not applicable plugged Date of Test Hours Tested Production for OIL -BBL GAS -MCF WATER -BBL CHOKE SIZE GAS - OIL RATIO Test Period - -> Flow Tubing Casing Pressure Calculated OIL -BBL GAS -MCF WATER -BBL OIL GRAVITY - API (corr) Press. psi 24 -Hour Rate -> 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No El 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. RECEIVED NONE AUG 2 0 2012 RBDMS AUG 21 2011 6k,( AOGCC Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Submit original only y, ie l . „, ,/ 4.,..),. 28. GEOLOGIC MARKERS (List all formations and ills encountered): 29. • FORMATION TESTS NAME MD TVD Well tested? ❑ Yes 0 No If yes, list intervals and formations tested, Permafrost - Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Bottom 2420' 2419' needed, and submit detailed test information per 20 AAC 25.071. not applicable N/A Formation at total depth: Kuparuk 30. LIST OF ATTACHMENTS Summary of Daily Operations, schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: M. M. Myers © 265 - 6318 Printed Name ®® G. Alvord Title: Alaska Drilling Manager Signature ! C�.. Phone 265 - 6120 Date I 1 � Z O t Sharon Allsup -Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item la: Classification of Service wells: Gas injection, water injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 3N -07 Pre -Rig Well Work Summary DATE SUMMARY 3/1/12 WEATHER- DELAYED STARTIOULLED XXN PLUG @ 7128' RKB. MEA ED BHP @ 7300' RKB: 3637 PSI. IN PROGRESS. 3/2/12 WEATHER- DELAYED START. BRUSHED & FLUSHED TBG TO XN @ 7128' RKB. SET XXN PLUG @ 7088' SLM, 7128' RKB. COMPLETE. 3/8/12 WC MIT -OA (PASSED) 3/27/12 DRIFTED TBG WITH 2.25" x 15' BAILER TO XXN PLUG @ 7129' RKB. IN PROGRESS. 3/28/12 WEATHER DELAYED START. SET CATCHER @ 7092' SLM. PULLED OV @ 6383' RKB. ATTEMPTED SET DV @ 6383' RKB, UNSUCCESSFUL. PULLED GLVs @ 5454', 4235', & 2705' RKB. IN PROGRESS. 3/29/12 SET DVs © 2705', 4235', 5454', & 6383' RKB. MIT TBG & MIT IA 2500 PSI, PASSED. PULLED DV © 6973' RKB. IN PROGRESS. 3/30/12 PULLED DV © 2705' RKB. PULLED CATCHER © 7092' SLM. COMPLETE. 4/7/12 PUMPED .875 BALL CALIBRATED REEL VOLUME. CONDITIONED WELL TO SEAWATER. SET CEMENT RETAINER AT 6900' MD. FREEZE PROTECTED WELL FROM 2700' TVD. RESTART IN AM. JOB IN PROGRESS. 4/8/12 PUMPED CEMENT THROUGH RETAINER SET AT 6900' MD TO OPEN GLM AT 6973' MD UP THE IA TO 6591' BY VOLUME. STUNG OUT OF RETAINER AND LAYED IN 1 BBL CEMENT TO 6728' MD. WASHED DOWN TO TOC WITH BIO. FREEZE PROTECTED WELL TO 3000' TVD. JOB COMPLETE. COPY OF THE PUMP REPORT AND CEMENT TEST IN THE ATTACHMENTS. 4/11/12 TAGGED @ 6863' SLM. CMIT TO 1700 PSI, PASSED. GOOD DRAWDOWN TEST. SET SLIPSTOP CATCHER @ 5750' SLM. SET DV @ 2705' RKB. PULLED CATCHER. IN PROGRESS. 4/15/12 DUMP BAIL 5 GALLONS OF CEMENT @ 6865' SLM — 20' TBG VOLUME. IN PROGRESS. 4/17/12 DRIFTED TBG WITH 1.75" DD BAILER. TAGGED TOC @ 6860' SLM. JOB COMPLETE. 4/20/12 CUT TUBING ATA DEPTH OF 6015' IN THE MIDDLE OF A JOINT USING 2.125" JRC JET CUTTER. NO PRESSURE DIFFERENCE WAS SEEN ON TUBING AND IA DUE TO GAS CAP. RIG WILL COMFIRM CUT. 4/21/12 (MISC) : REPLACE BENT LDS, IC PPPOT PASSED, TORQUED LDS TO 450 LBS. 4/22/12 Attempt to circulate down tubing through jet cut at 6015' RKB. Tubing pressured up to 2000 psi after 1.5 bbls with IA at 0 psi after 5 min. Attempt to circulate down IA. IA pressured up to 1800 psi with tubing at 480 psi after 5 min. Unable to circulate. 4/29/12 SET CATCHER @ 5700' SLM. PULLED DV @ 2705' RKB. CONFIRMED TBG x IA COMMUNICATION. SET NEW DV. PULLED DV @ 5454' RKB. CONFIRMED TBG x IA COMMUNICATION. SET NEW DV. PULLED CATCHER. READY FOR E /L. 5/5/12 PERFORMED RCBL NO CEMENT OBSERVED AT OR ABOVE 6015'. PERFORMED TUBING CUT AT 5985', CCL TO CUTTER OFFSET 5', CCL STOP AT 5980', POSITIVE INDICATION FROM TUBING X IA COMMUNICATION AFTER CUT. • • Time Log & Summary ConocoI Wellview Web Reporting Report Well Name: 3N - 07 Rig Name: DOYON 141 Job Type: DRILLING SIDETRACK Rig Accept: 6/14/2012 9:30:00 PM Rig Release: 7/20/2012 11:59:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06/14/2012 24 hr Summary Waiting on trucks to move to 3N -07A 21:30 00:00 2.50 MIRU WELLPF OTHR T Wait on trucks to mob. rig out. 06/15/2012 Trucks arrived 0630 hrs moved complexes,sub, pipe sheds, rock washer t/ 3N- 07,spot up over well, hook up service lines, wait on trucks for mud, wait on highline personnel to move camp to 3N -07. (Rig Camp should be moving this morning at 07:30 hrs from 1R Pad to 3N Pad.) 00:00 06:30 6.50 MIRU WELLPF OTHR T Continue to wait on trucks. 06:30 07:00 0.50 MIRU WELLPF SFTY P Pre job safety meeting w/ peak drives on moving rig t/ 3N -07 07:00 12:30 5.50 MIRU WELLPF MOB P Hook up pipe sheds spot out of way, Move complexes to 3N -07. 12:30 20:30 8.00 MIRU WELLPF MOB P Move sub off well, pipesheds & rock washer, move t/ 3N -07, spot sub over well, spot complexes. 20:30 00:00 3.50 MIRU WELLPF MOB P Hook up service lines, spot rock washer, finish containment, take on rig fuel, H2O. Wait on highline personel to move camp f/ 1 R -14 to 3N -07. Wait on trucks to deliver mud to rig ETA 2400 hrs. 06/16/2012 Continue rigging up, rig accepted @ 0100 hrs, take on 11.2 ppg mud, R/U surface line f/ displacement, berm tiger tank, test lines t/ 2500 psi, R/U & pull BPV, Displace well t/ 11.2 ppg mud @ 126 gpm 300 psi, cbserve well, blow down lines, Set BPV test from direction of flow t/ 1000 psi f/ 10 min. mark orientaion of tree, N/D tree, install blanking plug & adaptor flange, N/U BOP stack, R/U t/ test bops, test Bope blanking plug leaking change out, resume testing. Test waived By AOGCC Jeff Jones 00:00 01:00 1.00 0 0 MIRU MOVE MOB P Work on rig acceptance. (Rig accepted @ 01:00 June 16, 2012) 01:00 02:00 1.00 0 0 MIRU MOVE OTHR P Take on 11.2 ppg 450 bbls LSND mud into pits. 02:00 07:00 5.00 0 0 SLOT MOVE OTHR P Mobilize tiger tank and berm, SIMOPS, Install scaffolding around well head. Test cement and circulating lines to Tiger tank to 2500 psi 07:00 08:00 1.00 0 0 SLOT WELLPF OTHR P Rig up and Pull BPV 08:00 08:15 0.25 0 0 SLOT WELLPF SFTY P PJSM, on circulating mud through TBG down cut at 6015' 08:15 10:00 1.75 0 0 SLOT WELLPF CIRC P Circulate well with 240 bbls of 11.2 ppg LSND mud @ 3 bpm with 700 psi. 10:00 10:30 0.50 0 0 SLOT WELLPF OWFF P Monitor well, Static, Blow down lines. 10:30 11:00 0.50 0 0 SLOT WELLPF OTHR P Set BPV, Test BPV from bottom to 1000 psi for 10 min, Mark orientation of tree. Page 1 of 38 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 11:15 0.25 0 0 SLOT WELLPF SFTY P PJSM, on N/D tree 11:15 12:00 0.75 0 0 SLOT WELLPF NUND P N/D tree 12:00 12:15 0.25 0 0 SLOT WELLPF SFTY P PJSM with new crew on tour moving out tree. 12:15 12:30 0.25 0 0 SLOT WELLPF NUND P Remove tree from cellar area. 12:30 13:30 1.00 0 0 SLOT WELLPF NUND P Dress TBG spool and install blanking plug as per FMC, install adapter flange. 13:30 13:45 0.25 0 0 SLOT WELLPF SFTY P PJSM on N/U of BOPE 13:45 16:30 2.75 0 0 SLOT WELLPF NUND P Nipple up BOPE 16:30 16:45 0.25 0 0 SLOT WELLPF SFTY P PJSM, on R/U and testing BOP. 16:45 18:30 1.75 0 0 SLOT WELLPF BOPE P M/U 2 -7/8" test joint to X -over run and change out top rams to 2 -7/8" X 5" VBR. 18:30 19:30 1.00 0 0 SLOT WELLPF BOPE P Rig up test equipment. AOGCC waived witness of BOPE test Jeff Jones 19:30 20:30 1.00 0 0 SLOT WELLPF BOPE P After several attempts to test, verified balanking plug leaking, pull test joint and C /O/ ball in blanking plug, reinstall same. 20:30 00:00 3.50 0 0 SLOT WELLPF BOPE P Test BOP, upper 2 -7/6" X 5" VBR, Choke valves 1, 12, 13 & 14. Manual choke kill. (Service valves 13 and 14 retest Good) # 2 Test, upper IBOP, choke valves 9 & 11, (Serviced valve 11 & retest Good) serviced HCR kill valve. X6/17/2012 Pulled hanger and UD 6015' of 2 -7/8" TBG, R/U and Test lower pipe rams 250 low 3500 high,R/D test equip. ✓ P/U BHA #1, RIH with BHA # 1 with casing scraper to 700'. 00:00 04:45 4.75 0 0 SLOT WELLPF BOPE P Test Bope, Test choke valves 1 -14, upper & lower rams and blinds, upper & lower IBOP, man. & her choke and kill, 4" demco TIW & DART, acc. test, pvt & gas alarms. Witness waived by Jeff Jones AOGCC. 04:45 05:30 0.75 0 0 SLOT WELLPF RURD P R/D test equip. pull blanking plug, blow down lines. 05:30 06:00 0.50 0 0 SLOT WELLPF OTHR P Pull BPV 06:00 06:45 0.75 0 0 SLOT WELLPF RURD P R/U t/ pull 2.875 tubing 06:45 07:30 0.75 0 5,975 SLOT WELLPF OTHR P BOLDS pull hanger to floor, 125K t/ break over PUW 75K. 07:30 08:00 0.50 5,975 5,975 SLOT WELLPF PULD P UD Hanger & landing jt. 08:00 08:15 0.25 5,975 5,975 SLOT WELLPF RURD P R/U t/ circ. 08:15 09:00 0.75 5,975 5,975 SLOT WELLPF CIRC P Circ. Bottoms up stage pumps t/ 168 gpm 640 psi. 09:00 09:30 0.50 5,975 5,975 SLOT WELLPF OWFF P Monitor well and R/D circulatuing lines 09:30 09:45 0.25 5,975 5,975 SLOT WELLPF SFTY P PJSM, Pulling TBG Page 2 of 38 s Time Logs Date From To Dur. S. Depth E. Depth Phase Code Subcode T Comment - 09:45 12:00 2.25 5,975 5,042 SLOT RPEQPI PULL P Pull & UD 2.875" TBG, P /U= 65K, Pulling wet UD 33 jts, 4 pups, 1 DSnipple, Calc. displacement = 3.25 bbls, Actual = 3.62 bbls 12:00 12:30 0.50 4,917 4,917 SLOT RPEQP1CIRC P Pump dry job, 19 bbl 11.8 ppg slug 12:30 12:45 0.25 4,917 4,917 SLOT RPEQPI SFTY P PJSM, Pulling TBG 12:45 18:00 5.25 4,917 0 SLOT RPEQPI PULL P Cont. UD TBG F 4916' Total of 187 jts, 3 GLM's, 10' pup, 1 X- nipple and cut joint. Length of cut joint= Fill for trip, Act.= 11.5 bbls calc = 11.15 bbls 18:00 19:30 1.50 0 0 SLOT RPEQP1OTHR P Rig down 2 -7/8" handling equipment, Clear rig floor. 19:30 20:15 0.75 0 0 SLOT WELLPF BOPE P Rig to test lower pipe ram 20:15 20:30 0.25 0 0 SLOT WELLPF BOPE P tEST LOWER PIPE RAMS 2 -7/8" x 5" VBR with 4" test joint to 250 / 3500 psi for 5 min each and charted same. 20:30 21:00 0.50 0 0 SLOT WELLPF BOPE P Rig down test equipment 21:00 21:45 0.75 0 0 SLOT WELLPF OTHR P Install Wear Bushing 21:45 22:00 0.25 0 0 SLOT WELLPFSFTY P PJSM, on M/U BHA# 1, scraper assembly 22:00 00:00 2.00 0 700 SLOT WELLPF PULD P P/U BHA # 1, scraper assembly and single with 4" dp from pipe shed, drift pipe with 2.24 drift to 700' MD. Trip in displacement, Actual= 2.68 bbls, calculated = 2.87 bbls 36/18/2012 C I BP « 3 Single in the hole w/ scraper t/ 4157' circ hole clean, POOH UD scraper assy. M/U cemem retainer, RIH W/ Bridge plug set @ 4100' test t/ 1500 psi f/ 5 min. displace t/ heated seawater, POOH UD running tool RIH w/ Multi string cutter cut casing @ 4000' attempt to circ. pressure up t/ 500 psi. Pull up t/ 3600' cut casing, attempt U circ. • ressure up to 1400 psi, No returns. POOH t/ 1140' 00:00 03:15 3.25 700 4,157 SLOT WELLPF TRIP P Continue RIH w/ 4" DP f/ 700' t/ 4157' PUW 90K SOW 83K 03:15 04:00 0.75 4,157 4,157 SLOT WELLPFCIRC P Break Circ. stage pumps t/ 399 gpm 880 psi 12 RPM 1K tq, Circ. Surface to surface shakers cleaned up, 04:00 04:15 0.25 4,157 4,157 SLOT WELLPF OWFF P Obswerve well for flow Static 04:15 07:00 2.75 4,157 0 SLOT WELLPF TRIP P POOH f/ 4157' t/ surface 07:00 07:30 0.50 0 0 SLOT WELLPF PULD P Lay down BHA #1 scraper, clear floor 07:30 07:45 0.25 0 0 SLOT WELLPF PULD P PJSM, on cast iron bridge plug 07:45 10:30 2.75 0 4,100 SLOT WELLPF PULD P M/U BHA # 2 with Bridge Plug and '/ RIH to 4100, P/U = 91 K, S/O = 83K 10:30 10:45 0.25 4,100 4,066 SLOT WELLPF OTHR P Set Bridge plug per Baker Rep. Release from plug and pull up to 4066' MD 10:45 11:15 0.50 4,066 4,066 SLOT WELLPF OTHR P Test bridge plug to 1500 psi for 5 min and chart same. 11:15 13:00 1.75 4,066 4,066 SLOT WELLPF OTHR P Clean pit 5, take on 130° seawater 13:00 14:00 1.00 4,066 4,066 SLOT WELLPF CIRC P Break Circ. 168 gpm 300 psi, pump 25 bbl high vis spacer, displace well t/ 125° heated sea water. Page 3 of 38 • . Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:00. 14:15 0.25 4,066 4,066 SLOT WELLPF OWFF P Observe well for flow, static. 14:15 14:45 0.50 4,066 4,066 SLOT WELLPF SFTY P Pre job safety meeting on tripping out of hole. 14:45 16:00 1.25 4,066 7 SLOT WELLPF TRIP P POOH w/ BHA # 2 Bridge plug running tool. 16:00 16:15 0.25 7 0 SLOT WELLPF PULD P Lay down BHA # 2 clear floor of tools. 16:15 16:30 0.25 0 0 SLOT WELLPF SFTY P Per job safety meeting on M/U BHA tY and Tripping in hole 16:30 19:00 2.50 0 3,970 SLOT WELLPF TRIP P Trip in hole w/ BHA # 3 Multi string cutting tool t/ 3970'. 19:00 19:30 0.50 3,970 3,995 SLOT WELLPF OTHR P M/U top drive EST. parameters, PUW 90K SOW 88K ROT WT 90 K, Break Circ. 105 gpm 200 psi, Slack off locate Collar @ 4006', Pull t/ 3995' Make cut w/ 70 RPM, 189 'gpm, Observe Pressure drop indication of cut, Verify cut as per baker Rep. 19:30 19:45 0.25 3,995 3,995 SLOT WELLPF CIRC P Line up to OA and tiger tank, Attempt to circ. pressure up t/ 500 psi no returns, R/D equipment. 19:45 20:30 0.75 3,995 3,593 SLOT WELLPF TRIP P POOH f/ 3995' t/ 3593' 20:30 21:15 0.75 3,593 3,587 SLOT WELLPF OTHR P P/U & M/U single, establish perameters, PUW 85K SOW 83K, break Circ. 84 gpm 200 psi, Locate collar @ 3590' P/U t/ 3587', make cut w/ 70 rpm 189 gpm 500 psi, drop in pressure verify cut as per Baker rep. 21:15 21:30 0.25 3,587 3,587 SLOT WELLPF CIRC P Close ann. attempt t/ circ. through OA pressure up t/ 14 psi no returns. 21:30 21:45 0.25 3,587 3,587 SLOT WELLPF OWFF P Observe well for flow, static 21:45 22:00 0.25 3,587 3,587 SLOT WELLPF SFTY P Pre job safety meeting on tripping out of hole 22:00 22:30 0.50 3,587 3,587 SLOT WELLPF OTHR P Attempt to slack off through cut to lay down single, take wt. 4k. 22:30 00:00 1.50 3,587 0 SLOT WELLPF TRIP P POOH w/ multi string cutter 36/19/2012 Made casing cuts at 3995', 3587' and 2930' could not circ through the OA, POOH N/D stack pulled packoff, reset slips with 15K over string wt. removed TBG spool installed drilling spool, N/U stack, Test BOP against formation to 1000 psi, Rig u • E -Line and run CET. 00:00 00:15 0.25 0 0 SLOT WELLPF SFTY P Pre job safety meeting on UD BHA 00:15 00:45 0.50 0 0 SLOT WELLPF PULD P Change out cutters on Multi string cutting tool 00:45 02:30 1.75 0 3,596 SLOT WELLPF TRIP P RIH t/ 3596' LID single, P/U = 83 K, S/O = 80 K, Actual = 21.75 bbls. 02:30 02:45 0.25 3,596 3,587 SLOT WELLPF OTHR P Break Circ. Locate cut @ 3587' 2.4 bpm w/ 200 psi 02:45 03:00 0.25 3,587 2,935 SLOT WELLPF TRIP P POOH T/ 2935' Calcuated = 3.78 bbls, Actual = 4.49 bbls. Page 4 of 38 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:00 04:30 1.50 2,935 2,930 SLOT WELLPF OTHR P Break Circ. 101 gpm 200 psi, Locate collars @ 2889' & 2933', Pick up t/ 2930', make cut 70 RPM 201 gpm 500 psi, verify cut pump pressure dropped t/ 150 psi. 04:30 04:45 0.25 2,930 2,930 SLOT WELLPF SFTY P PJSM, on POOH to 2653' while monitoring well 04:45 05:30 0.75 2,653 2,653 SLOT WELLPF TRIP P POOH to 2653' MD, Cal = 1.62 bbls, actual = 1.75 bbls. 05:30 06:00 0.50 2,653 2,653 SLOT WELLPF CIRC P Attempt t/ displace annulus to tiger tank, pressure up to 1400 psi, No returns, slight bleed off in pressure, attempt to pump down annulus, pressure up to 1000 psi, no returns 06:00 07:30 1.50 2,653 0 SLOT WELLPFTRIP P Cont. POOH F/ 2653.0 to surface, (Note cutters had cement on blades) Cal. = 15.1 bbls, Actual = 15.87 bbls 07:30 07:45 0.25 0 0 SLOT WELLPF OTHR P Clean and clear rig floor 07:45 08:00 0.25 0 0 SLOT WELLPF SFTY P PJSM, C/O lower rams 08:00 09:30 1.50 0 0 SLOT WELLPF OTHR P Change lower set of rams to 7" 09:30 09:45 0.25 0 0 SLOT WELLPF SFTY P PJSM, N/D BOP 09:45 12:00 2.25 0 0 SLOT WELLPF NUND P N/D BOPE double studded adapter flange and TBG spool, casing grow installed with all threads bolts, (Casing growth was 6.750 ") 12:00 13:30 1.50 0 0 SLOT WELLPF OTHR X Wait on Hydra tight, SIMOPS spot DSA in cellar, Cont. N/D stack and adapter spool, strip and prep TBG spool for hydra tight. 13:30 14:45 1.25 0 0 SLOT WELLPF OTHR P Pulled wear bushing and serviced rig 14:45 15:00 0.25 0 0 SLOT WELLPF OTHR P PJSM, on hydra tight tool 15:00 15:15 0.25 0 0 SLOT WELLPF OTHR P R/U Hyra Tight tool 15:15 16:15 1.00 0 0 SLOT WELLPF OTHR P Start hydra Tight process, casing grew 6.750 ", R/D tool 16:15 17:15 1.00 0 0 SLOT WELLPF OTHR P Remove TBG spool and packoff, SIMOPS AAR for Hydra Tight tool. 17:15 17:30 0.25 0 0 SLOT .WELLPF SFTY P PJSM, on M/U Spear BHA. 17:30 18:45 1.25 0 0 SLOT WELLPF OTHR P M/U spear assembly and single to top drive 18:45 19:15 0.50 0 0 SLOT WELLPF OTHR P Engage CSG stub with spear, P/U to 125 K, (15 K over csg string wt.) Reset slips, S/O and release spear, L/D same. 19:15 20:00 0.75 0 0 SLOT WELLPF OTHR P Clean, prep and weld slips in place to 7" casing. 20:00 20:15 0.25 0 0 SLOT WELLPF SFTY P PJSM, on N/U BOPE 20:15 22:30 2.25 0 SLOT WELLPF NUND P N/U BOPE 22:30 23:15 0.75 0 0 SLOT WELLPF BOPE P Test BOP agianst the formation with binds close to 1000 psi and check for leaks (Good) 23:15 00:00 0.75 0 0 SLOT WELLPF NUND P N/U Riser on BOP's Page 5 of 38 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06/20/2012 24 hr summary { R/U ELine CBL log f/ 4000' TOC 2050', M/U Multi string cutter cut casing @ 2025', POOH, P/U spear, Spear `� casing, Casing free w/ 75K, Displace artic pack to tiger tank, UD 7" Casing, Change 7" rams to 2 7/8 X 5 G yd VBR, test breaks in stack, 250 low 3000 high 3 (p q 00:00 00:15 0.25 0 0 SLOT WELLPF SFTY P PJSM R/U ELine. 00:15 01:00 0.75 0 0 SLOT WELCTL RURD P R/U Eline, Spot truck, Han to P 9 P sheave. 01:00 03:30 2.50 0 0 SLOT WELLPF ELOG P RIH w/ Cement Bond Log, t/ 4000', log out of hole, TOC @ 2050'. 03:30 04:00 0.50 0 0 SLOT WELLPF RURD P R/D Eline. 04:00 04:30 0.50 0 0 SLOT WELLPF PULD P M/U Spear, Engage 7" casing stub pull up to 200K 10" pipe stretch, Disengage spear lay down. 04:30 04:45 0.25 0 0 SLOT WELLPF SFTY P Pre Job safety meeting on M/U BHA running in hole. 04:45 05:00 0.25 0 0 SLOT WELLPF PULD P M/U BHA Multi string cutting tool. 05:00 06:30 1.50 0 2,032 SLOT WELLPF TRIP P RIH W/ BHA t/ 2032'. 06:30 07:00 0.50 2,032 2,025 SLOT WELLPF OTHR P Pick up to 2025' Make cut in 7" casing, verify cut pressure dropped off. 07:00 07:45 0.75 2,025 2,025 SLOT WELLPF OTHR P Close Rams R/U on OA let well U tube t/ tiger tank. 07:45 08:15 0.50 2,025 2,025 SLOT WELLPF CIRC P CBU t/ tiger tank, artic pack @ 84 gpm 150 psi. 08:15 08:45 0.50 2,025 2,025 SLOT WELLPF OWFF P Observe well for flow, static, Blow down lies to tiger tank. 08:45 10:00 1.25 2,025 0 SLOT WELLPF TRIP P POOH f/ 2025' t/ surface. 10:00 10:30 0.50 0 0 SLOT WELLPF PULD P UD Multi string cutter, M/U spear. 10:30 10:45 0.25 0 0 SLOT WELLPF SFTY P Pre job safety meeting on displacing artic pack. 10:45 12:45 2.00 0 2,025 SLOT WELLPF OTHR P Engauge 7" casing, R/U Hot Oil test lines t/ 1500 psi, P/U on casing free @ 75k, Line up to tiger tank, Pump 25 bbls heated diesel 130° @ 1.5 bpm 200 psi, pump spacer, chase w/ heated sea water, increase t/ 126 gpm 300 psi. 12:45 13:00 0.25 2,025 2,025 SLOT WELLPF OWFF P Observe well for flow, Static 13:00 13:15 0.25 2,025 2,025 SLOT WELLPF CIRC P Circ. Bottoms up 210 P @ gpm 150 psi, simops R/U casinfg equip. 13:15 13:30 0.25 2,025 2,025 SLOT WELLPF OWFF P Observe well for flow static. 13:30 13:45 0.25 2,025 2,025 SLOT WELLPF SFTY P Pre job safey meeting on UD casing & spear assy. 13:45 15:00 1.25 2,025 2,025 SLOT WELLPF PULD P Pull Casing to floor UD spear assy. & casing stub. 15:00 17:15 2.25 2,025 0 SLOT WELLPF PULL P Pooh & UD 7" 26# J -55. 17:15 19:00 1.75 0 0 SLOT WELLPF RURD P R/D caaing equipment, clear floor. 19:00 19:15 0.25 0 0 SLOT WELLPF SFTY P Pre job safety meeting on changing rams. 19:15 20:15 1.00 0 0 SLOT WELLPF SEQP P Change out lower rams f/ 7" to 2 7/8 x5VBR. Page 6 of 38 1 Time Logs Date From To Dur S, Depth E. Depth Phase Code Subcode . T Comment 20:15 20:45 0.50 0 0 SLOT WELLPF RURD P R/U test equipment. 20:45 21:30 0.75 0 0 SLOT WELLPF BOPE P Attempt to test lower rams, test plug leaking, pull test plug, clean lubricate, reseat. 21:30 22:00 0.50 0 0 SLOT WELLPF BOPE P Test lower rams, casing spool & dsa flange 250 low 3000 high. 22:00 22:30 0.50 0 0 SLOT WELLPF RURD P R/D test equipment set wear ring. 22:30 00:00 1.50 0 0 SLOT WELLPF PULD P P/U BHA components f/ next run. 06/21/2012 Wash and ream down to 2137 MD, POOH and found the 7" casing inside the wash over pipe, held PJSM, wait on casing cutter, cut and laid down 87.88' of 7" casing from washpipe, P/U wash pipe and TIH. 00:00 02:30 2.50 0 347 SLOT WELLPF PULD P M/U Wash Pipe Assy. 02:30 04:00 1.50 347 1,983 SLOT WELLPF TRIP P RIH f/ 347' t/ 1983' 04:00 04:30 0.50 1,983 2,030 SLOT WELLPF REAM P Wash f/ 1983' t/ 2030' w/ 210 gpm 240 psi 50 rpm, tag casing collar 04:30 05:45 1.25 2,030 2,031 SLOT WELLPF MILL P Mill on casing collar 210 gpm 220 psi 70 rpm tq 4K, 3K WOB, break through 05:45 08:30 2.75 2,031 2,072 SLOT WELLPF REAM P Wash & Ream f/ 2031' t/ 2072' w/210 gpm 220 psi 70 rpm, tag collar 08:30 10:00 1.50 2,072 2,073 SLOT WELLPF MILL P Mill on casing collar f/ 2072' t/ 2073' 7K WOB 210 gpm 230 psi 10:00 12:00 2.00 2,073 2,096 SLOT WELLPF REAM P Wash & ream F/2073' T/2096' WOB 2 -10K, 294 GPM, 70 RPM, TQ 2 -10 K. 12:00 14:45 2.75 2,096 2,137 SLOT WELLPF MILL P Mill on casing collar F/2096' T/2137' MD, WOB 2 -10K, 294 GPM, 70 RPM, TQ 3 -7 K. 14:45 15:15 0.50 2,137 2,137 SLOT WELLPF CIRC P CBU @ 9 BPM, with 250 psi / 15:15 15:30 0.25 2,137 2,137 SLOT WELLPF OWFF P Monitor well (Static) V 15:30 16:00 0.50 2,137 1,385 SLOT WELLPFTRIP P Work through tight spot @ 1970' MD with 15 - 50 K over pull, work untill free (3X) Line up on TT and cont. pulling to 1385" MD, Incorrect fill (started to swab) Act= 2.75 bbls, Calc.= 3.24 bbls 16:00 16:15 0.25 1,385 1,385 SLOT WELLPF CIRC P M/U to Top Drive and circ 9 bpm with 175 psi 16:15 16:30 0.25 1,385 1,385 SLOT WELLPF OWFF P Monitor well (Static) 16:30 17:15 0.75 1,385 347 SLOT WELLPFTRIP P Cont. to POOH to Wash over BHA F/1385' T/347' 17:15 17:30 0.25 347 347 SLOT WELLPF OWFF P Monitor well, (static) 17:30 18:45 1.25 347 0 SLOT WELLPF PULD X Rach back DCs in derrick, pull stand of wash pipe, made break and found Fish in the stand of wash pipe, safely install dogcollar clamp. Act.= 17.1 bbls, Calc.= 16.71 bbls 18:45 19:00 0.25 0 0 SLOT WELLPF SFTY X PJSM, on UD fish, ordered W.A..C..H cutter to location 19:00 21:00 2.00 0 0 SLOT WELLPF OTHR X W/O /Cutter coming to location, called FMC hand out to location Page 7 of 38 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode - T Comment 21:00 00:00 3.00 0 0 SLOT WELLPF OTHR X R/U W.A.C.H. and cut 7" and lay down lower 7" casing, Break down stand of wash pipe with fish in it in the mouse hole. 06/22/2012 Ran in with wash pipe assembly and washed and reamed down to 2239' MD over 7" casing. POOH with same. 00:00 01:30 1.50 0 0 SLOT WELLPF PULD X Continue UD Fish, R/U W.A.C.H.S. cutter, cut casing, UD 87.88' of 7" casing. 01:30 02:30 1.00 0 0 SLOT WELLPF OTHR P Clean & Clear rig floor R/D WACHS cutter, Clear BHA comp. from floor. 02:30 02:45 0.25 0 0 SLOT WELLPF SFTY P PJSM on M/U BHA #9 02:45 04:00 1.25 0 375 SLOT WELLPF PULD P M/U BHA #9 04:00 05:15 1.25 375 2,074 SLOT WELLPF TRIP P RIH w/ wash pipe t/ 2074' 05:15 06:15 1.00 2,074 2,136 SLOT WELLPF REAM P Wash f/ 2074' t/ 2113' w/ 168 gpm 200 psi, Tag 7" casing stump, Establish Rotation 20 rpm, locate wash pipe Wash f/ 2013' t/ 2136', increase pumps t/ 210 gpm 200 psi, 70 rpm 4K tq. 06:15 12:00 5.75 2,136 2,165 SLOT WELLPF MILL P Mill f/ 2136' t/2165' MD, with 3 bpm 325 psi, Tq on= 2 -8K, Pump sweeps after each collar milled, sweep @ ) 8:30 hrs 75% increase in cuttings, next sweep @ 10:00 hrs had 75% increase cuttings also. 12:00 00:00 12.00 2,165 2,239 SLOT WELLPF MILL P Cont. to mil over 7" casing F/2165' T/2239' MD with 3 to6 bpm and 150 to 350 psi, Pumped super sweeps after each collar, P/U wt= 79K, S/O wt= 77K, Rot wt= 80K 06/23/2012 POOH with washing & milling BHA had 7" casing come up with wash pipe, Length 82.93' layed down same and RIH with spear No- Go, POOH and P/U multi -cutter and make cut @ 2239' MD, POOH and RIH with spear recovered fish Length 41.45' R/U and test BOPE. 00:00 02:15 2.25 2,239 2,237 SLOT WELLPF MILL P Cont. Mill over casing @ 2239', Attempt to wash over, P/U on string tq spike @ 2236 t/ 2237', unable to work past 2237' 02:15 02:30 0.25 2,237 2,237 SLOT WELLPF OWFF P Observe well for flow Static 02:30 03:00 0.50 2,237 1,700 SLOT WELLPF TRIP P Pooh f/ 2237' t/ 1700' hole fill incorrect, 03:00 03:30 0.50 1,700 1,700 SLOT WELLPF CIRC P Circ. surface to surface 210 gpm 250 psi, no notible difference on bottoms up 03:30 04:00 0.50 1,700 1,415 SLOT WELLPF TRIP P Pooh f/ 1700' t/ 1415' 04:00 05:00 1.00 1,415 375 SLOT WELLPF OTHR P Pump out of the hole f/ 1415 t/ 375' 05:00 05:15 0.25 375 375 SLOT WELLPF SFTY P PJSM on Laying down BHA & casing 05:15 09:00 3.75 375 0 SLOT WELLPF PULD P Stand back collars, UD BHA as per baker hand, 82.93' of 7" casing in wash pipe, UD casing, float shoe, missing crown on cutters. Clear floor Page 8 of 38 • ail Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:00 09:15 0.25 0 0 SLOT WELLPF SFTY P Pre job safety meeting on P/U BHA 09:15 10:45 1.50 0 214 SLOT WELLPF PULD P P/U BHA # 10 Spear 10:45 12:00 1.25 214 2,195 SLOT WELLPF TRIP P RIH W/ spear f/ 214' t/ 2195' MD, Act= 17.5 bbls, Calc= 17.49 bbls 12:00 12:15 0.25 2,195 2,195 SLOT WELLPF OTHR P M/U Top Drive, P/U wt= 75K, S /0= 77K, Break circ with 5 bpm & 100 psi, Engage casing stub @ 2197' MD, set down wt= 5K, observed pressure increase from No -Go, shut down pumps, P/U to 50K over string wt. and fire jars, P/U w/ 125K, release spear. 12:15 13:00 0.75 2,195 214 SLOT WELLPF TRIP P POOH with spear assembly F/ 2100' to/214' 13:00 13:15 0.25 214 214 SLOT WELLPF OWFF P Monitor well, (Static) 13:15 14:00 0.75 214 0 SLOT WELLPF PULD P Rack back DC's and UD spear, Act= 18.6 bbls, calc= 17.49 bbls. 14:00 14:15 0.25 0 0 SLOT WELLPF SFTY P PJSM, on picking up BHA 14:15 14:45 0.50 0 0 SLOT WELLPF PULD P M/U Multi -cutter assemnbly. 14:45 15:30 0.75 0 2,180 SLOT WELLPF TRIP P RIH to 2180' Act= 13.9 bbls, Calc= 13.2 bbls. 15:30 16:30 1.00 2,180 2,239 SLOT WELLPFOWFF P M/U Top Drive, P/U wt= 64K, S /0= 65K, stabonto stump, Break circ with 3 bpm with 300 psi, locate collar and make cut @ 2239' with 60 rpm, 4 bpm 500 psi, Tq= 1K 16:30 16:45 0.25 2,239 2,239 SLOT WELLPF SFTY P PJSM on POOH 16:45 17:30 0.75 2,239 0 SLOT WELLPF TRIP P POOH with Multi cutter F/ 2239' to ✓ surface, Act =13.7 bbls, Calc= 1266 17:30 18:00 0.50 0 0 SLOT WELLPF OTHR P Clear and clean rig floor 18:00 18:15 0.25 0 0 SLOT WELLPF SFTY P PJSM, on P/U spear assembly 18:15 18:45 0.50 0 214 SLOT WELLPF PULD P P/U spear assembly 18:45 20:15 1.50 214 2,132 SLOT WELLPF TRIP P RIH F/214' T/2132' Act= 17.7 bbls, Calc= 17.49 bbls. 20:15 20:30 0.25 2,132 2,197 SLOT WELLPF OTHR P M/U Top Drive, P/U wt= 75K. S/O wt= 77K, Circ @ 5bpm 100 psi, engage Fish @ 2197' set down 15K 20:30 20:45 0.25 2,197 2,197 SLOT WELLPFSFTY P PJSM, on POOH 20:45 21:30 0.75 2,197 214 SLOT WELLPF TRIP P POOH with Fish F/2100' T/214' 21:30 21:45 0.25 214 214 SLOT WELLPF OWFF P Monitor well at DC's, (Static) 21:45 22:30 0.75 214 0 SLOT WELLPF PULD P Rack back DC's and UD fish and spear, Length of Fish= 41.45' Act= 15 bbls, Calc= 14.24 bbls. 22:30 23:15 0.75 0 0 SLOT WELLPF OTHR P Drain stack and pull wear ring. 23:15 00:00 0.75 0 0 SLOT WELLPF OTHR P P/U single, stack washer and flush out stack Page 9 of 38 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subc ode T Comment 06/24/2012 24 hr Summary M/U 8.75 Junk mill RIH t/ 660' tag hard spot unable to work by, Pooh UD Mill, P/U 8.5 junk mill, RIH t/ 660' tag up unable to work through, Pooh UD Mill wait on swedge f/ Baker, M/U Swedge & Stab, RIH t/ 591' work through ttight spot no drag, RIH U 2239', Pooh, UD swedge P/U 8.75 mill RIH t/ 660' unable to work through. Pooh UD mill, P/U 8.75 watermelon mill, RIH t/ 660 work through tight spot, RIH t/ 2239', CBU, POOH 00:00 00:15 0.25 0 0 SLOT WELLPF SFTY P Pre Job safety meeting on flushing stack. 00:15 00:45 0.50 0 0 SLOT WELLPF OTHR P Flush stack, function annular, & rams. 00:45 01:00 0.25 0 0 SLOT WELLPF SFTY P Pre Job safety meeting on testing BOP 01:00 02:00 1.00 0 0 SLOT WELLPF RURD P R/U t/ test BOP's 02:00 05:30 3.50 0 0 SLOT WELLPF BOPE P Test BOP's, 250 low 3000 high ( due to 11" 3K flange on stack Per E Mail from Guy Schwartz AOGCC), choke valves 1 -14, top bottom & blind rams, HCR & man. choke & kill, 4" demco, auto & man. IBOP, test ann. to 250 low 2500 high , acc. test. (Test witnessed by State Rep. Chuck Scheve) 05:30 06:30 1.00 0 0 SLOT WELLPF RURD P R/D test equipment, install wear ring, blow down lines. 06:30 06:45 0.25 0 0 SLOT WELLPF SFTY P Pre job safety meeting on P/U BHA 06:45 08:15 1.50 0 0 SLOT WELLPF PULD T P/U BHA 8.75 junk mill RIH to 660'. Mill would not pass. POOH and lay down 8.75" mill. 08:15 10:00 1.75 0 660 SLOT WELLPF TRIP T Made up 8.5" Junk Mill and RIH w/ Junk mill t/ 660' tag hard spot, establish rotation & circ. 60 rpm 700 Ibs unable to break through. Pump 5 ✓ bpm with 50 psi, 40 rpm, P /U= 55K, S /O= 55K, TQ= 2K, Stalled out took 20K overpull to free up. 10:00 10:30 0.50 660 211 SLOT WELLPF TRIP T POOH F/660' T/211' Act= 9.1 bbls, Calc= 9.15 bbls 10:30 12:00 1.50 211 0 SLOT WELLPF PULD T Rack back two stds DCs, UD bit sub and 8 -1/2" junk mill. Clean and clear rig floor 12:00 13:00 1.00 0 0 SLOT WELLPF OTHR T Wait on tools from Baker, SIMOPS Service Top Drive and Drawworks and PJSM. 13:00 14:15 1.25 0 660 SLOT WELLPF PULD T M/U Swedge and stabilizer assembly, RIH to 660' P /U= 52K, S /O= 55K, hammer on tight spot with 20K, After sevral attemps picked up 5' and rotated with 40 RPM, S/O and Ream through tight spot with minimal Tq. work tight spot with no drag. 14:15 15:15 1.00 660 2,239 SLOT WELLPF TRIP T Cont. RIH to 2239', P /U= 75K, S /0= 77K, set on stump with 25K. 15:15 15:30 0.25 2,239 2,239 SLOT WELLPF SFTY T PJSM, POOH 15:30 16:15 0.75 2,239 215 SLOT WELLPF TRIP T POOH with swedge assembly F/ 2239' T/215' Page 10 of 38 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:15 16:45 0.50 215 0 SLOT WELLPF OWFF T Monitor well @ DCs, (Static) Rack back DCs and UD swedge assembly 16:45 17:15 0.50 0 0 SLOT WELLPF OTHR T Clear and clean rig floor 17:15 17:30 0.25 0 0 SLOT WELLPF SFTY T PJSM, Milling BHA 17:30 18:45 1.25 0 660 SLOT WELLPF PULD T M/U 8 -3/4" junk milling assembly and RIH to 660' MD, took weight P /U= 52K, 5/0= 55K, P/U 5' and set down with 15K, P/U 5' rotated @ 40 RPM, Attemp to drill / mill with 3 -7 Torque, No success.(Discussed with Engineer in town) 18:45 19:00 0.25 660 211 SLOT WELLPF TRIP T POOH F/660' T/211' 19:00 19:15 0.25 211 211 SLOT WELLPF OWFF T Monitor well @ DCs (Static) 19:15 19:30 0.25 211 0 SLOT WELLPF PULD T Rack back DCs and LID mill assembly 19:30 20:00 0.50 0 0 SLOT WELLPF PULD T Clear rig floor and P/U 8 -3/4" watermelon mill and mule shoe. 20:00 20:15 0.25 0 0 SLOT WELLPF SFTY T PJSM, on M/U BHA 20:15 20:45 0.50 0 215 SLOT WELLPF PULD T M/U BHA t/ 215' 20:45 21:00 0.25 215 592 SLOT WELLPF TRIP T RIH f/ 215' t/ 592' 21:00 21:30 0.50 592 665 SLOT WELLPF OTHR T M/U t/ TD & establish circ. 210 gpm 50 psi, 60 rpm 1K tq, S/O throught tight spot several times 2K - 5K tq, shut down rot. pumps, no drag. 21:30 22:15 0.75 665 2,239 SLOT WELLPF TRIP T RIH f/ 665' t/ 2239', set down on casing stub w/ 5K 22:15 23:00 0.75 2,239 2,239 SLOT WELLPF CIRC T Circ. Bottoms up 504 gpm 450 psi 23:00 23:15 0.25 2,239 2,239 SLOT WELLPF OWFF P Observe well for flow static 23:15 00:00 0.75 2,239 SLOT WELLPF TRIP T Pooh f/ 2197' t/ 1725' 36/25/2012 RIH with Junk Mill and milled down 3' and POOH and P/U Pilot Mill, RIH and mill 7" casing down to 2308' Hole packing off and found flowline packed off, clean out same, Back ream out to clean up metal cuttings in well bore. 00:00 00:15 0.25 1,725 1,725 SLOT WELLPFSFTY T PJSM, POOH 00:15 00:30 0.25 1,725 215 SLOT WELLPF TRIP T POOH F/ 1725' T/ 215' Act= 19.68 bbls, Calc= 18.26 bbls. 00:30 00:45 0.25 215 0 SLOT WELLPF PULD T Rack back DCs, Lay down BHA as per -Baker 00:45 01:00 0.25 0 0 SLOT WELLPF SFTY T PJSM, on P/U BHA 01:00 01:30 0.50 0 211 SLOT WELLPF PULD T M/U 8.750" Junk Mill BHA 01:30 02:15 0.75 211 2,238 SLOT WELLPF TRIP T TIH with BHA F/ 211' T/2238' Act =17.85 bbls, Calc= 17.79 bbls, Parameters P /U =77K, 5/0= 76K, Rot= 78K, 6 bpm with125 psi. 02:15 08:15 6.00 2,238 2,241 SLOT WELLPF MILL T Mill F/ 2238' T/ 2241' @ 3bpm 50 psi, 80 RPM, TQ= 1K. 08:15 08:30 0.25 2,241 2,241 SLOT WELLPF OWFF T Monitor well (Static) 08:30 09:30 1.00 2,241 211 SLOT WELLPF TRIP T POOH F/ 2241' T/ 211' Act =18.9 bbls, Calc= 17.79 bbls, Page 11 of 38 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:30 10:00 0.50 211 0 SLOT WELLPF PULD T Rack Back DCs and lay down BHA, clear rig floor. 10:00 10:15 0.25 0 0 SLOT WELLPF SFTY T PJSM, P/U pilot mill 10:15 11:00 0.75 0 201 SLOT WELLPF PULD T M/U Pilot Mill BHA 11:00 12:00 1.00 201 2,239 SLOT WELLPF TRIP T RIH with Pilot Mill F/201' T/2241' Act= 17.5 bbls, Calc= 17.49 bbls. 12:00 23:00 11.00 2,239 2,308 SLOT WELLPF MILL T Mill F/ 2239' T/ 2308' MD, with 50 to 110 RPM, 5 -7 bpm, 100 -175 psi, P /U= 75K, S /O= 77K, Rot= 76K, Tq= .5K, (Pumped two Super Sweeps during milling) 23:00 00:00 1.00 2,308 2,308 SLOT WELLPF OTHR T Observed No metal coming back, attempt to circ metal out @ 12 bpm 500psi, Observed metal in n BOP stack and found flow line packed off. ( Discussed with town engineer) 06/26/2012 Clean metal out of BOPE and flowline. POOH w/ pump and UD BHA. M/U BHA, 7" pilot mill and RIH t/ 2277' MD. Reverse circulate to clean out obstruction in drill string. Ream to bottom @ 2308' and CBU. Mill 7" casing t/ 2325' MD worked though tight spot @ 2293' MD. The flow line packed off the metal cuttings twice while milling. 00:00 03:15 3.25 2,308 2,308 SLOT CSGRC' OTHR T PJSM- pump down kill line to attempt to clean metal out of the flow line and stack. Cleaned metal out of the stack, but the flow line was still 100 % packed with metal. Break flow line apart and clean out metal shavings. 03:15 03:30 0.25 2,308 2,308 SLOT CSGRC' PRTS T Fill hole and inspect flow line for leaks. 03:30 05:15 1.75 2,308 672 SLOT CSGRC' TRIP T POOH f/ 2277' MD t/ 672' MD w/ pump @ 8 BPM, 120 PSI, 80 RPM,TQ= 0. 05:15 06:00 0.75 672 672 SLOT CSGRC' SFTY T Held H2S drill, all rig personal evacuated to the safe briefing area. Donned SCBA's and secured well. 06:00 06:30 0.50 672 201 SLOT CSGRC' TRIP T POOH f/ 672' MD t/ 201' MD w/ pump @ 8 BPM, 100 PSI, 80 RPM,TQ= 0. Actual displacement for trip= 21.7 bbls, Calculated displacement= 17.49 bbls. 06:30 06:45 0.25 201 0 SLOT CSGRC' PULD T Rack back 2 stands of drill collars and UD BHA 06:45 07:00 0.25 0 0 SLOT CSGRC' OTHR P Clean and clear floor. 07:00 08:00 1.00 0 0 SLOT WHDBO OTHR P Flush stack X 4. Function annular and rams to clear metal cuttings out of BOPE. 08:00 08:15 0.25 0 0 SLOT CSGRC' SFTY P Hold PJSM on M/U BHA and RIH. 08:15 08:45 0.50 0 201 SLOT CSGRC' PULD P M/U BHA # 19, 7" pilot mill as per Baker. 08:45 10:00 1.25 201 2,277 SLOT CSGRC' TRIP P RIH f/ 201' MD t/ 2277' MD. Attempt to establish parameters, drill pipe pugged off. Actual displacement= 17.4 bbls, Calculated displacement= 18.03 bbls. Page 12 of 38 4 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:00 10:15 0.25 2,277 2,182 SLOT CSGRC' TRIP P POOH f/ 2277' MD t/ 2182' MD. 10:15 10:30 0.25 2,182 2,182 SLOT CSGRC' RURD P R/U to reverse circulate. 10:30 11:30 1.00 2,182 2,088 SLOT CSGRC' CIRC P Reverse circulate attempting to unplug drill string. The pipe unplugged after two attempts. 11:30 12:00 0.50 2,088 2,182 SLOT CSGRC' REAM P Wash and ream f/ 2088' MD t/ 2182' MD @ 7 BPM, 150 PSI, 80 RPM w/ OK TQ. 12:00 13:00 1.00 2,182 2,308 SLOT CSGRC' REAM P Cont. to wash and ream f/ 2180' MD t/ casing stub @ 2308' MD. Ream @ 7.5 BPM =200 PSI, 80 RPM. CBU while rot & recip, P/U wt. =76K, S/O wt. =79K, Rot wt.= 78K. 13:00 13:30 0.50 2,308 2,308 SLOT CSGRC' CIRC P Pump 29 bbl HiVis sweep w/ Super Sweep Fibers @ 7.5 BPM =200 PSI rot & recip string. 13:30 16:15 2.75 2,308 2,320 SLOT CSGRC' MILL P Mill 7" casing w/ 80 -100 RPM, TQ= 1-4K @ 6 BPM =400 PSI. Milled f/ 2308' MD t/ 2320' MD. 16:15 17:00 0.75 2,320 2,320 SLOT CSGRC' CIRC P Pump HiVis sweep w/ Super Sweep Fibers @ 8.5 BPM =400 PSI, jet stack through IA, rot & recip string. 17:00 19:00 2.00 2,320 2,320 SLOT CSGRC' OTHR T Observed flow line packed off. Held PJSM, disassembled, cleaned out and reassembled. 19:00 19:30 0.50 2,320 2,320 SLOT CSGRC' PRTS T Fill hole and check for leaks. Observed a crack in flow line, drain and clean for welder. 19:30 20:30 1.00 2,320 2,320 SLOT CSGRC' SVRG T Service rig, SIMOPS- weld crack in flow line. 20:30 21:00 0.50 2,320 2,320 SLOT CSGRC' REAM P Fill hole and check for leaks. (good) Bring pump rate up t/ 12 BPM =500 PSI, wash and ream to bottom w/ 120 RPM. Observed 10' of fill. 21:00 21:15 0.25 2,320 2,320 SLOT CSGRC' CIRC P Tag stub @ 2320' MD. P/U and CBU while rot & recip string. Work through tight spot @ 2293' MD several times pulling 5 K over. 21:15 22:00 0.75 2,320 2,321 SLOT CSGRC' MILL P Wash down and mill f/ 2320' MD t/ 2321' MD. 22:00 23:00 1.00 2,321 2,293 SLOT CSGRC' REAM T Mill packing off. P/U and work though tight spot again @ 2293' MD w/ pump @ 15 BPM =650 PSI several times pulling 5 K over. Back ream out to 2225' MD and wash back to bottom, no fill. 23:00 00:00 1.00 2,293 2,325 SLOT CSGRC' MILL P Mill 7" casing f/ 2321' MD t/ 2325' MD © 6 BPM =150 PSI, 80 -110 RPM w/ 1-4K TQ. 06/27/2012 Milled t/ 2326' MD, packing off. Work pipe thought tight spot @ 2293' MD. Displace t/ 10.2 ppg LSND mud. Attempt t/ mill, packing off. POOH w/ pump. Clean out metal shavings from wellhead and BOPE using Baker rope spear and magnets. M/U junk mill and RIH t/ to make a clean out run. Page 13 of 38 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:00 1.00 2,325 2,293 SLOT CSGRC' REAM T PJSM- hole packing off @ 2293' MD- 2297' MD. Work pipe several times through spot. Pulled 15K over. Pumped HiVis weighted sweep, small amount of cuttings observed at shakers. Decision made t/ change fluid over to LSND mud system. 01:00 02:00 1.00 2,293 2,290 SLOT CSGRC' OTHR T Shut down, clean and inspect flow line before fluid swap. 02:00 02:15 0.25 2,290 2,290 SLOT CSGRC' SFTY T Hold PJSM on displacement. 02:15 03:00 0.75 2,290 2,290 SLOT CSGRC' COND T Prep pits f/ fluid displacement 03:00 03:15 0.25 2,290 2,290 SLOT CSGRC' DISP T Displace 8.5 ppg viscosified brine over to 10.2 ppg LSND mud @ 16 BPM =425 PSI, 80 RPM w/ OK TQ. 03:15 03:45 0.50 2,290 2,326 SLOT CSGRC' MILL P Mill 7" casing f/ 2325' MD t/ 2326' MD @ 10 BPM, 110 RPM w/ 3K TQ, WOB= 10K. Hole packing off. Decision made t/ circulate hole clean, no cuttings observed at shakers. Decision made to POOH. 03:45 04:30 0.75 2,326 2,268 SLOT CSGRC' CIRC P Circulate and condition mud until _ mud weight is even in /out 10.2 ppg. 04:30 04:45 0.25 2,268 3,368 SLOT CSGRC' OWFF P Monitor well. (static) 04:45 07:00 2.25 2,280 201 SLOT CSGRC' TRIP P POOH w/ pump @ 6 BPM =175 PSI f/ 2268' MD t/ 201' MD. Actual displacement= 18.03, Calculated displacement= 19.6 bbls. 07:00 07:45 0.75 201 0 SLOT CSGRC' PULD P Rack back 2 stands of 6 3/4" drill collars and UD BHA. Stack full of wadded up metal cuttings. Mix and pump HiVis sweep to clean out metal shavings. 07:45 08:00 0.25 0 0 SLOT CSGRC' OTHR P Clean and clear rig floor. 08:00 09:30 1.50 0 0 SLOT WHDBO CIRC P Mix HiVis sweep. SIMOPS, hook up mud pump through wellhead and attempt to clean metal out of wellhead and BOPE. 09:30 10:00 0.50 0 0 SLOT WHDBO CIRC P Pump HiVis sweep and pump @ 8.5 BPM through wellhead. Observed very little returns. Observed stack full of wadded up metal shavings. 10:00 10:15 0.25 0 0 SLOT WHDBO OTHR P Blow down lines and drain stack. 10:15 10:30 0.25 0 0 SLOT CSGRC' SFTY T Hold PJSM on P/U tools and M/U BHA. 10:30 10:45 0.25 0 0 SLOT CSGRC' PULD T P/U Baker tools from beaver slide. 10:45 11:00 0.25 0 40 SLOT CSGRC' PULD T M/U Baker rope spear as per Baker rep. 11:00 12:00 1.00 40 20 SLOT WHDBO CIRC T Attempt to fish out metal cuttings from stack. Only the magnets had metal on them. Decision made to puck up 5" magnets and fish out more metal. Page 14 of 38 i Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 17:00 5.00 20 20 SLOT WHDBO CIRC T PJSM- M/U Magnet assy, make multiple passes through stack. Fill hole and circulate through IA @ 9 BPM =800 PSI. Continue to reciprocate magnets. Drain stack, function rams halfway then continue to reciprocate magnets until) stack was clear of metal. Approximately 400 Ibs of metal recovered. 17:00 17:45 0.75 20 0 SLOT WHDBO OTHR T Clean floor, P/U and UD subs via beaver slide. 17:45 19:00 1.25 0 0 SLOT WHDBO CIRC T Flush stack with stack washer and magnets @ 20 BPM =150 PSI. Clean magnets and flush stack again @ 20 BPM =150 PSI until returns cleaned up. 19:00 20:30 1.50 0 227 SLOT CSGRC' PULD P PJSM- P/U junk mill assy, BHA # 22. RIH t/ 227' MD, took 5 -10K @ 180' MD. Actual displacement= 5.7 bbls, Calculated displacement= 7.41 bbls. 20:30 00:00 3.50 227 1,734 SLOT CSGRC' REAM P Wash and ream @ 14 BPM =300 PSI, 60 RPM f/ 227' MD t/ 1734' MD. P/U wt.= 70K, S/O wt.= 70K, ROT wt.= 70K. Actual displacement= 16.7 bbls, Calculated displacement= 16.1 bbls. 06/28/2012 Ream to bottom w/ junk mill and clean out 2' of fill. Circulate hole clean and POOH. M/U BHA, pilot mill and RIH. Mill 7" casing f/ 2326' MD t/ 2380" MD. 00:00 01:15 1.25 1,734 2,326 SLOT CSGRC' REAM P PJSM- wash and ream f/1734' MD t/ 2326' MD @ 14 BPM =300 PSI, 60 ✓ RPM w/ OK TQ. Observed 2' of fill on bottom. 01:15 01:30 0.25 2,326 2,326 SLOT CSGRC' MILL P Set down 5K @ 2326' MD, let mill off @ reaming rate. 01:30 02:00 0.50 2,326 2,300 SLOT CSGRC' CIRC P CBU X 3 @ 16 BPM =725 PSI, 50 RPM w/ 0 TQ. Cement and metal shavings observed at shakers. 02:00 02:15 0.25 2,300 2,300 SLOT CSGRC' OWFF T UD single. Monitor well. (static) 02:15 03:15 1.00 2,300 227 SLOT CSGRC' TRIP T POOH on elevators f/ 2300' MD t/ 227' MD. Actual displacement= 19.6 bbls, Calculated displacement= 19.29 bbls. 03:15 04:00 0.75 227 0 SLOT CSGRC' PULD T Rack back 2 stands of drill collars and UD BHA # 22 as per Baker rep. 04:00 04:15 0.25 0 0 SLOT CSGRC' OTHR T Clean and clear rig floor. 04:15 05:00 0.75 0 0 SLOT CSGRC' CIRC T Flush stack to clean out metal shaving. 05:00 05:45 0.75 0 201 SLOT CSGRC' PULD P PJSM- M/U BHA # 23, pilot mill as per Baker rep. 05:45 07:00 1.25 201 2,326 SLOT CSGRC' TRIP P RIH f/ 201' MD t/ 2326' MD. Actual displacement= 18.2 bbls, Calculated displacement= 18.12 bbls. Page 15 of 38 • Time Logs Date From ` To Dur S. Deoth E. Depth Phase Code Subcode T Comment 07:00 12:00 5.00 2,326 2,345 SLOT CSGRC' MILL P Mill f/ 2326' MD t/ 2345' MD @ 10 BPM =375 PSI, 115 RPM w/ 4 -6K TQ. P/U wt.= 77K, S/O wt.= 75K, ROT wt.= 77K. 12:00 22:00 10.00 2,345 2,373 SLOT CSGRC' MILL P Mill f/ 2345' MD t/ 2373' MD @ 10 BPM =350 PSI, 115 RPM w/ 4-6K TQ, 5 -7K WOB. Pumping 15 bbls HiVis sweeps every 5' @ 17 BPM= 750 PSI, recip string B/U X 2. Observing 20 % to 50 % increase in cuttings with sweeps. 22:00 00:00 2.00 2,373 2,380 SLOT CSGRC' MILL P P/U and M/U single to allow room to work pipe. Cont t/ milling f/ 2373' MD to 2380' MD @ 10 BPM =350 PSI, 115 RPM w/ 4 -6K TQ, 5 -7K WOB. Pumping 15 bbls HiVis sweeps every 5' @ 17 BPM= 750 PSI, recip string B/U X 2. Observing 20 % to 50 % increase in cuttings with sweeps. P/U wt. =72K, S/O wt.= 76K, ROT wt.= 75K. 06/29/2012 Milled 7" casing f/ 2380' MD t/ 2415' MD. Shut down and cleaned metal shavings from stack. Cont. milling f/ 2415' MD t/ 2454' MD 00:00 10:45 10.75 2,380 2,415 SLOT CSGRC' MILL P PJSM- Mill f/ 2380' MD t/ 2415' MD @ 10 BPM =400 PSI, 115 RPM w/ 1 -4K TQ. Pumping 10 bbls sweeps every 5', bring pump rate up t/ 17.5 BPM and work pipe until sweep return. Observing a 20% to 50% increase in mill cuttings with sweeps and increased pump rate. 10:45 12:00 1.25 2,415 2,415 SLOT CSGRC' CIRC P Observed an increase in pump pressure and flow decreased. Shut down and drain stack. Observed stack full of metal mill cuttings. Decision made to pump through wellhead annulus. No change in the amount of metal. Decision made to mix 30 bbls HiVis sweep. 12:00 13:00 1.00 2,415 2,415 SLOT CSGRC' CIRC P Pump 30 bbls HiVis sweep @ 19 BPM =825 PSI, 115 RPM w/ OK TQ. Observed a 20% increase in cuttings. Circualted until wellhead was clear on metal mill cuttings. 13:00 00:00 11.00 2,415 2,454 SLOT CSGRC' MILL P Mill f/ 2415' MD t/ 2454' MD@ 10 BPM =370 PSI, 115 RPM w/ 1 -4K TQ. Pumping 10 bbls sweeps every 5', bring pump rate up t/ 17.5 BPM =950 PSI and work pipe until sweep return. Observing a 20% to 50% increase in mill cuttings with sweeps and increased pump rate. P/U wt. 74 K, S/O 75K, ROT wt.= 75K, WOB 7 -8K. 06/30/2012 Milled 7" casing f/ 2454' MD t/ 2535' MD. Pumping 10 bbls HiVis every 5' @ 800 GPM, sweeps returning 20% more cuttings. Page 16 of 38 . . Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 12:00 12.00 2,454 2,488 SLOT CSGRC' MILL P PJSM- Cont. t/ mill f/ 2454' MD t/ 2488' MD. Pump @ 420 GPM =370 PSI, 115 RPM w/ 1-4K TQ, P/U wt.= 74K, S/O wt.= 75K, ROT wt.= 75K, WOB= 7 -8K, Flow out = 49 %. Pump 10 bbls HiVis sweeps every 5' © 800 GPM =950 PSI. Observing a 20% increase in mill cuttings with sweeps. Shut down pumps © 2465' MD to precautionary inspect stack for metal cuttings, flush metal cuttings out of stack by pumping a 30 bbls HiVis sweep. 12:00 00:00 12.00 2,488 2,535 SLOT CSGRC' MILL P PSJM- Cont. t/ mill f/ 2488' MD t/ 2535' MD. Pump @ 420 GPM =380 PSI, 115 RPM w/ 2 -5K, P/U wt.= 74K, S/O wt.= 75K, ROT wt.= 76K, WOB= 7 -9K, Flow out = 49 %. Pump 10 bbls HiVis sweeps every 5' @ 800 GPM =950 PSI. Observing a 20% increase in mill cuttings with sweeps. 07/01/2012 Milled 7" casing f/ 2535' MD t/ 2595' MD. Pumping 10 bbls HiVis every 5' @ 800 GPM. CBU and POOH. R/U and test BOPE. 00:00 12:00 12.00 2,535 2,578 SLOT CSGRC' MILL P PJSM- Cont. t/ mill f/ 2535' MD t/ 2578' MD. Pump @ 420 GPM =400 PSI, 115 RPM w/ 1-4K TQ. Pumping 10 bbl HiVis sweeps every 5' @ 820 GPM= 1025 PSI. Observing a 25% increase in cuttings with sweeps. P/U wt.= 74K, S/O wt.= 75K, ROT wt.= 76K. Observed flow line building ✓ up cuttings. Shut down and drain stack to clean cuttings out of stack, pump 30 bbl HiVis sweep. 12:00 17:45 5.75 2,578 2,595 SLOT CSGRC' MILL P PJSM- Cont. t/ mill f/ 2578' MD t/ 2595' MD. Pump @ 420 GPM =400 PSI, 115 RPM w/ 1 -4K TQ. Pumping 10 bbl HiVis sweeps every 5' @ 820 GPM= 1025 PSI. Observing a 25% increase in cuttings with sweeps. P/U wt.= 74K, S/O wt.= 75K, ROT wt.= 76K. 17:45 18:45 1.00 2,595 201 SLOT CSGRC' TRIP P CBU. PJSM- POOH f/ 2595' MD t/ 201' MD. Actual displacement= 21.42 bbls, Calculated displacement= 20.37 bbls. 18:45 19:30 0.75 201 0 SLOT CSGRC' PULD P UD BHA as per Baker rep. 19:30 20:15 0.75 0 0 SLOT CSGRC' CIRC P PJSM - R/U and flush stack. 20:15 21:00 0.75 0 0 SLOT WHDBO RURD P Pull wear bushing and flush stack again. 21:00 21:30 0.50 0 0 SLOT WHDBO RURD P PJSM - R/U to test BOPE. 21:30 22:00 0.50 0 0 SLOT WHDBO BOPE P Test annular preventor t/ 250/3000 PSI f/ 5 min w/ 5" test joint. Page 17 of 38 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:00 00:00 2.00 0 0 SLOT WHDBO BOPE P PJSM- open rams doors on stack and clean out metal mill cuttings f/ ram cavitys. 07/02/2012 Cont U test BOPE to 250 PSI low, 3000 PSI high. Witness of BOP test waived by Lou Grimaldi. Slip and cutting drilling line, service rig. M/U pilot mill and mill f/ 2595' MD t/ 2621' MD. Circulate hole clean and POOH. 00:00 00:15 0.25 0 0 SLOT WHDBO SFTY P PJSM- Fill out hazard recognition checklist and hazard recognition worksheet. 00:15 03:00 2.75 0 0 SLOT WHDBO BOPE P Open rams doors and clean metal out. 03:00 03:30 0.50 0 0 SLOT WHDBO BOPE P M/U floor valves and finish rigging up to test BOPE. 03:30 08:00 4.50 0 0 SLOT WHDBO BOPE P Cont. to test BOPE t/ 250 PSI low 3000 PSI high w/ 5" test joint. Test #1= Top pipe rams, CV 1,12,13,14 and manual kill line valve. Test # 2= Upper IBOP, HCR kill, CV 9 & 11. Test #3= Lower IBOP, CV 5,8 & 10. Test #4= Dart valve, CV 4,6,& 7. Test #5= Floor valve & CV 2. Test #6= HCR choke, & 4" kill line demco. Test #7= Manual choke valve & HCR kill. Test #8= annular preventer. Test #9= lower pipe rams. Test #10= blind rams. Test # 11= annular preventer w/ 4" test joint t/ 250 PSI low 2500 PSI high. Test # 12= top pipe rams w/ 4" test joint. Test # 13= lower pipe rams w/ 4" test joint. Accumulator test= system pressure, 3000 PSI, pressure after closing= 1800 PSI, 38 seconds t/ obtain 200 PSI. Full pressure obtained after 176 seconds. Five bottle nitrogen average= 2000 PSI. AGOCC rep Lou Grimaldi waved witness of the BOP test. 08:00 08:30 0.50 0 0 SLOT WHDBO RURD P R/D test equipment, blow down choke, choke line and kill line. 08:30 08:45 0.25 0 0 SLOT WHDBO RURD P Install 9" wear bushing. 08:45 09:00 0.25 0 0 SLOT RIGMNT SFTY P PJSM- Fill out hazard recognition checklist and hazard recognition worksheet on slip and cut drilling line. 09:00 10:00 1.00 0 0 SLOT RIGMNT SLPC P Slip and cut drilling line. 10:00 10:30 0.50 0 0 SLOT RIGMNT SVRG P Service rig and top drive. 10:30 10:45 0.25 0 0 SLOT CSGRC' SFTY P PJSM- Fill out hazard recognition checklist and hazard recognition worksheet on M/U BHA. 10:45 12:00 1.25 0 204 SLOT CSGRC' PULD P M/U BHA # 24, pilot mill as per Baker rep. Page 18 of 38 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 13:15 1.25 204 2,595 SLOT CSGRC' TRIP P PJSM- Cont t/ RIH w/ pilot mill f/ 204' MD t/ 2595' MD. Establish circulation, pump @ 440 GPM =445 PSI, P/U wt.= 78K, S/O wt.= 81K, ROT wt.= 80K. 13:15 20:30 7.25 2,595 2,621 SLOT CSGRC' MILL P Mill f/ 2595' MD t/ 2621' MD @ 420 GPM= 445 PSI. Pump 10 bbls HiVis every 5' @ 780 GPM =1000 PSI. 115 RPM w/ 2 -5K TQ, WOB= 7 -9K. ROP =5 FPH. 20:30 21:00 0.50 2,621 2,620 SLOT CSGRC' CIRC P Pump 30 bbl HiVis sweep @ 780 GPM, Circulate hole clean. 21:00 22:00 1.00 2,620 204 SLOT CSGRC' TRIP P POOH f/ 2620' MD t/ 204' MD. Actual displacement= 20.91 bbls, Calculated displacement= 19.74 bbls 22:00 22:45 0.75 204 0 SLOT CSGRC' PULD P UD BHA as per Baker rep. 22:45 23:30 0.75 0 0 SLOT CSGRC'CIRC P R/U and flush stack. 23:30 00:00 0.50 0 0 SLOT CSGRC' RURD P Clear and clean floor. R/U to run 2 -7/8" tubing. 07/03/2012 P/U 2 -7/8" tbg and RIH on 4" DP. Unable to enter 7" casing stump @ 2621' MD. POOH and M/U mule shoe on 2 -7/8 tbg and RIH on 4 " DP t/ 3653' MD. Unable to go past 3653' MD. Pump 23 bbls of 17.0 ppg cement, POOH above cement and circulate. WOC. 00:00 00:15 0.25 0 0 SLOT CEMEN" RURD P R/U tongs, elevators and dog collar. 00:15 00:30 0.25 0 0 SLOT CEMEN" SFTY P PJSM on running 2.875" tubing for cement stinger. 00:30 01:15 0.75 0 720 SLOT CEMEN" PUTB P RIH w/ 2.875" tubing f/ cement t/ 720' MD. 01:15 01:30 0.25 720 720 SLOT CEMEN "RURD P R/D tongs, break apart safety valve and change elevators. ✓ 01:30 02:00 0.50 720 2,621 SLOT CEMEN" TRIP P RIH w/ 4" drill pipe f/ 2607' MD. Actual displacement= 12.9 bbls, Calculated displacement= 12.43 bbls. 02:00 03:15 1.25 2,621 2,621 SLOT CEMEN "TRIP P Tag up on 7" casing stump @ 2621' MD, attempt to enter stump. Tried rotating @ 5 RPM while pumping @ 10 BPM =450 PSI. Slowed pumps t/ 3 BPM and attempted to enter again. Setting down 2 -5K multiple times, turn 1/4 turn at a time. ROT @ 5,10,15 RPM, no go. POOH t/ pick up mule shoe. 03:15 04:00 0.75 2,621 720 SLOT CEMEN' TRIP P PJSM, POOH f/ 2621' MD t/ 720 ' MD. Actual displacement= 14.79 bbls, Calcualted displacement= 12.43 bbls. 04:00 04:45 0.75 720 0 SLOT CEMEN" TRIP P C/O elevators and R/U power tongs. Cont. t/ POOH standing back 2 -7/8" tbg in the derrick f/ 720' MD to surface. 04:45 05:15 0.50 0 726 SLOT CEMEN" PULD P Inspect all joints, good. M/U 5.3' Mule shoe. RIH w/ 2 -7/8" tbg t/ 726' MD. 05:15 05:30 0.25 726 726 SLOT CEMEN" RURD P PJSM, C/O elevators and R/U power tongs. Page 19 of 38 • Time Logs Date From To : Dur S. Depth E. Depth Phase Code Subcode T Comment 05:30 - 08:00 2.50 726 3,653 SLOT CEMEN" TRIP P RIH f/ 726' MD t/ 2621' MD. Tag up @ 2621' MD, turn 1/4 turn to the right two times before dropping in the 7" stump. Cont. RIH tagging up @ 3653' MD. Pump @ 4 BPM =300 PSI, ROT 10 RPM w/ Tq limiter set @ 1 K, stalling out. Unable to get past 3653' MD. P/U wt.= 76K, S/O wt.= 77K. Actual displacement= 17.64 bbls, Calculated displacement= 17.83 08:00 08:30 0.50 3,653 3,653 SLOT CEMEN" OTHR P Call town, decision was made to set cement plug @ 3653' MD. 08:30 09:00 0.50 3,653 3,653 SLOT CEMEN" RURD P PJSM, R/U to pump cement. 09:00 10:15 1.25 3,653 3,653 SLOT CEMEN "CIRC P Circulate @ 4.5 BPM =500 PSI while batching up cement. 10:15 10:45 0.50 3,653 3,653 SLOT CEMEN" CMNT P Pressure test lines t/ 2750 PSI. (good) Pump 23.3 bbls of 17.0 ppg cement as per Schlumberger. Displaced cement with rig pumps, chased with w/ 22.7 bbls of 9.8 ppg LSND © 6 BPM =160 PSI. 10:45 11:00 0.25 3,653 2,991 SLOT CEMEN "RURD P R/D cement equipment, POOH f/ 3653' MD t/ 2991' MD (collars hanging up) Actual displacement= 4.76, Calculated displacement= 3.78 bbls. 11:00 11:15 0.25 2,991 2,991 SLOT CEMEN" RURD P R/U cement hose to reverse circulate. 11:15 12:00 0.75 2,991 2,991 SLOT CEMEN" CIRC P Reverse circulate surface to surface @ 10 BPM =800 PSI @ 2991' MD. 12:00 12:15 0.25 2,991 2,991 SLOT CEMEN "CIRC P PJSM, Cont. to reverse circulate @ 10 BPM =795 PSI. 12:15 12:45 0.50 2,991 2,991 SLOT CEMEN" CIRC P R/U to circulate the long way, CBU X 2 @ 10 BPM =975 PSI. 12:45 00:00 11.25 2,991 2,991 SLOT CEMEN WOC P WOC. SIMOPS, work on MP2's, scrub and paint rig. Clean out boilers. X7/04/2012 RIH, locate TOC @ 3100' MD. Pump 2nd cement plug f/ 3100' MD U 2350' MD. P/U and stand back 5" drill pipe while WOC. RIH t/ 2367' MD locate TOC, set down 4K. POOH and M/U clean out BHA. 00:00 00:30 0.50 2,991 2,991 SLOT CEMEN" SFTY P Pre -job safety meeting on rigging up cement equipment 00:30 00:45 0.25 2,991 3,100 SLOT CEMEN "TRIP P RIH from 2991' MD to 3100' MD circulating at 1 bpm @ 150 psi. Saw pressure increase from 150 psi to 190 psi indicating TOC 00:45 01:30 0.75 3,100 3,100 SLOT CEMEN P CBU @ 7 bpm @ 400 psi. Observed cement in returns on BU. Circulate hole clean 01:30 01:45 0.25 3,100 3,086 SLOT CEMEN "TRIP P POOH to 3086' 01:45 02:00 0.25 3,086 3,086 SLOT CEMEN" RURD P Rig up to circulate and pump cement 02:00 03:45 1.75 3,086 3,086 SLOT CEMEN" CIRC P Circulate and condidtion mud at 5 bpm, 375 psi, P/U = 71k, S/O = 65k. Hold safety meeting on cement job and batch up cement Page 20 of 38 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 03:45 04:15 0.50 3,086 3,086 SLOT CEMEN' DISP P Pressure test cement lines to 2500 psi. Pump 11 bbl 12.5 ppg Mudpush, 39.5 bbl 17.0 ppg cement, and 2 bbl 12.5 ppg Mudpush. 04:15 05:00 0.75 3,086 2,235 SLOT CEMEN' TRIP P POOH from 3086' to 2235'. 05:00 06:00 1.00 2,235 2,235 SLOT CEMEN' CIRC P Rig up and reverse circulate at 10 bpm, 700 psi. Rid down circulating head and circulate the longway from 2 BU @ 10 bpm @ 400 psi. Blow down top drive 06:00 12:00 6.00 2,235 2,235 SLOT DRILL PULD P Pick up 6 stand of 5" HWDP and 30 stands 5" drillpipe and rack back. Clean cement valves and clean under shakers. 12:00 15:30 3.50 2,235 2,235 SLOT DRILL PULD P PJSM, Continue to pick up and stand back 5" drill pipe. 15:30 16:00 0.50 2,235 2,235 SLOT DRILL OTHR P LID tread protectors and pick up saver sub from beaver slide. 16:00 16:15 0.25 2,235 2,235 SLOT RIGMNT SFTY P Hold PJSM on changing out saver sub to 4 -1/2" IF. 16:15 18:30 2.25 2,235 2,235 SLOT RIGMNT SVRG P Change saver sub, bell guide and grabber dies on top drive. 18:30 19:00 0.50 2,235 2,235 SLOT CEMEN' RURD P Put tools away and change elevators to 5 ". 19:00 20:30 1.50 2,235 2,235 SLOT CEMEN" CIRC P RIH f/ 2238' MD, pumping @ 1 BPM =130 PSI. P /U= 59K, S /O= 61 K. Observed a 30 PSI pump pressure increase @ 2366' MD along with a 2K bobble on weight indicator. P/U 1' and CBU @ 10 BPM =480 PSI. Observed hard cement at the shakers at bottoms up. Slowed pumps back to 1 BPM and RIH. Tagged up @ 2367' MD and set down 4K on TOC. Decision made to POOH. 20:30 21:30 1.00 2,235 726 SLOT CEMEN' TRIP P PJSM, POOH f/ 2367' MD t/ 726' MD. 21:30 22:00 0.50 726 726 SLOT CEMEN' RURD P R/U tongs, elevators and slips to 2 -7/8" tbg. 22:00 23:00 1.00 726 0 SLOT CEMEN' PULD P UD 2 -7/8" tbg f/ 726' MD t/ surface. 23:00 23:30 0.50 0 0 SLOT CEMEN' OTHR P Clean and clear rig floor. 23:30 00:00 0.50 0 0 SLOT CEMEN' PULD P Pick up tools from beaver slide. 07/05/2012 RIH w/ clean out BHA. Drill cement f/ 2367' MD to/ 2620' MD. CBU and R/U to test casing. Attempt to test 9 -5/8" casing to 1500 PSI. Pressure bled off @ 720 PSI. POOH. P/U packer and RIH t/ isolate hole in 9 -5/8" casing. Found damaged area in casing f/ 2412' MD t/ 2533' MD. 00:00 00:15 0.25 0 0 SLOT CEMEN' PULD P PJSM, P/U tools from the beaver slide. 00:15 00:30 0.25 0 0 SLOT WHDBO RURD P R/U to test 5" floor valves. 00:30 01:00 0.50 0 0 SLOT WHDBO BOPE P Test floor valves to 250 PSI low and 3000 PSI high. 01:00 01:15 0.25 0 0 SLOT WHDBO RURD P R/D testing equipment and floor valves. Change elevators to 5 ". Page 21 of 38 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:15 01:45 0.50 0 0 SLOT CEMEN' SFTY P PJSM, fill out hazard recognition card and hazard recognition worksheet on M/U clean out BHA. 01:45 03:00 1.25 0 584 SLOT CEMEN' PULD P M/U BHA # 26 as per Halliburton and Baker reps. Clean out BHA w/ 8 -3/4 mill tooth bit. 03:00 03:15 0.25 584 584 SLOT CEMEN' SRVY P Pluse test MWD @ 375 GPM =800 PSI. 03:15 04:15 1.00 584 2,340 SLOT CEMEN'TRIP P RIH w/ drill pipe f/ 584' MD t/ 2340' MD. Establish parameters, 420 GPM= 1050 PSI, 80 RPM w/ OK TQ, P /U= 90K, S /O= 88K, ROT= 92K. Actual displacement= 26.07 bbls, Calculated displacement= 26.24 bbls. 04:15 05:00 0.75 2,340 2,367 SLOT CEMEN' WASH P Wash and ream f/ 2340' MD t/ 2367' MD © 420 GPM= 1050 PSI, 80 RPM. Washing past cement stringers. 05:00 12:00 7.00 2,367 2,620 SLOT CEMEN' DRLG P Tag cement @ 2367' MD. Drill cement f/ 2367' MD t/ 2620' MD @ 420 GPM =1100 PSI, 100 RPM w/ 1K TQ, WOB= 5 -10K. 12:00 13:30 1.50 2,620 2,620 SLOT CEMEN' SRVY P PJSM, ream stand. Shoot surveys for MWD, orientation station f/ 2620' MD t/ 2498' MD. Pump 400 GPM =980 PSI, P /U= 94K, S/O 95K, ROT= 95K. 13:30 14:00 0.50 2,620 2,618 SLOT CEMEN' CIRC P CBU @ 420 GPM =1100 PSI. 14:00 14:45 0.75 2,618 2,618 SLOT CEMEN' PRTS P Rig up to test 9 -5/8" casing, pressure up and attempt to test t/ 1500 PSI. Pumped 1 BPM up to 725 PSI, pressure broke over and began injecting mud. Injection rate @ 1 BPM =700 PSI. Decision made to POOH. 14:45 15:00 0.25 2,618 2,618 SLOT CEMEN' OWFF P Monitor well. 15:00 15:45 0.75 2,618 580 SLOT CEMEN' TRIP P PJSM, POOH f/ 2620' MD U 580' MD. Actual displacement= 28.71 bbls, Calculated displacement= 28.5 bbls. 15:45 16:15 0.50 580 0 SLOT CEMEN' PULD P UD BHA. 16:15 16:30 0.25 0 0 SLOT CEMEN' OTHR P Clean and clean rig floor. 16:30 19:15 2.75 0 0 SLOT CEMEN' OTHR P Scrub and paint rig while waiting on test packer. 19:15 19:45 0.50 0 0 SLOT RIGMN1SVRG P Service rig. 19:45 20:00 0.25 0 0 SLOT CEMEN' SFTY P Hold PJSM on picking up packer. 20:00 21:45 1.75 0 1,298 SLOT CEMEN' PRTS P RIH w/ retrievable packer t/ 1298' MD. Attempt to pressure up below packer to 1500 PSI, bleeding off @ 720 PSI. Pressure broke over and began injecting © 1 BPM= 680 PSI. Bled off pressure, test above packer to 1500 PSI f/ 15 min, good test. Page 22 of 38 . • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:45 23:15 1.50 1,298 2,608 SLOT CEMEN" PRTS P RIH t/ 2608' MD. R/U and pressure test below packer to 1500 PSI f/ 15 min, good test. Attempt to pressure up above packer to 1500 PSI, bleeding off @ 700 PSI. Pressure broke over and began injecting @ 1 BPM= 680 PSI. Actual displacement= 27.97, Calculated displacement= 30.48. P /U= 104K, S/0= 105K. 23:15 00:00 0.75 2,608 2,505 SLOT CEMEN" PRTS P R/D test equipment and stand back one stand. 37/06/2012 Isolate leak in 9 5/8" casing between 2412' MD to 2533' MD. POOH. RIH w/ cement retainer t/ 2415' MD. AGOCC confirmed that a cement job was not needed. POOH. RIH w/ whipstock and mill window, TOW @ 2599' MD BOW © 2616' MD 00:00 03:00 3.00 2,505 2,412 SLOT CEMEN' PRTS P PJSM, set packer @ 2501' MD, Attempt to test IA t/ 1500 PSI, observed fluid circulating around packer (no test). POOH t/ 2412' MD. Test IA t/ 1500 PSI f/ 15min, good test. Pump down pipe @ 2412' MD, pressure broke over @ 690 PSI and began injecting fluid. RIH t/ 2564' MD, test down pipe t/ 1500 PSI f/ 5 min, good test. POOH t/ 2533' MD, test down pipe t/ 1500 PSI, good test. POOH t/ 2412' MD and perform injectivty test, 1 BPM= 690 PSI, 2 BPM= 730 PSI, 3 BPM= 800 PSI, 4 BPM= 850 PSI, 5 BPM= 875 PSI. Injected a total of 23.8 bbls. Shut down and bleed pressure off. Test IA t/ 1500 PSI f/ 10 min, good test. Confirmed damaged casing f/ 2412' MD t/ 2533' MD. 03:00 03:15 0.25 2,412 2,412 SLOT CEMEN' RURD P Rig down test equipment and line up to trip tank. 03:15 04:00 0.75 2,412 745 SLOT CEMEN "TRIP P POOH f/ 2412' MD t/ 745' MD. Actual displacement= 29.41 Calculated displacement= 29.26 bbls 04:00 04:30 0.50 745 0 SLOT CEMEN" PULD P Rack back 6 stands of HWDP and 2 collars. UD BHA as per Baker rep. 04:30 05:00 0.50 0 0 SLOT CEMEN" OTHR P Blow down top drive, kill line and cement line. 05:00 05:15 0.25 0 0 SLOT CEMEN" SFTY P Hold PJSM on M/U cement retainer. 05:15 05:30 0.25 0 7 SLOT CEMEN' PULD P M/U cement retainer as per Baker rep. 05:30 06:45 1.25 7 2,415 SLOT CEMEN" TRIP P RIH f/ 7't/ 2415' MD. Actual displacement= 23.25 bbls, Calculated displacement= 20.3 bbls. 06:45 07:00 0.25 2,415 2,415 SLOT RIGMNT SFTY P Hold PJSM on servicing rig. 07:00 07:30 0.50 2,415 2,415 SLOT RIGMN1SVRG P Service rig. Page 23 of 38 • • Time Logs Date From To Dur S. Depth E. Depth Phase _Code Subcode T Comment 07:30 10:30 3.00 2,415 2,415 SLOT CEMEN" OTHR P Wait on orders from town. Approval was given by the state to not squeeze the damaged 9 -5/8" casing f/ 2412' MD t/ 2533' MD 10:30 11:45 1.25 2,415 0 SLOT CEMEN" TRIP P PJSM, POOH f/ 2415' MD t/ surface. Actual displacement= 22.78 bbls, Calculated displacement= 20.04 bbls. 11:45 12:00 0.25 0 0 SLOT CEMEN" OTHR P Clean and clear rig floor. 12:00 12:15 0.25 0 0 SLOT STK PULD P P/U Baker tools from the beaver slide. 12:15 14:30 2.25 0 20 SLOT STK PULD P PJSM, M/U Whipstock as per Baker rep. 14:30 15:15 0.75 20 225 SLOT STK SRVY P RIH t/ 225' MD and shallow hole test MWD tools, good test. 15:15 17:00 1.75 225 2,620 SLOT STK WPST P Cont t/ RIH w/ whipstock t/ 2620' MD. Actual displacement= 29.7 bbls, Calculated displacement= 29.9 bbls. 17:00 18:00 1.00 2,620 2,599 SLOT STK WPST P Make up top drive on stand # 19, pump @ 450 GPM= 975 PSI. Orient t/ 16 left, shut down pumps and make a connection. RIH and tag @ 2621' MD, set down 4K. P/U off bottom and pump @ 450 GPM to verify 16 left. Shut down pumps, come back down to set anchor. Slowly slacked off and observed anchor and shear bolt sheared @ P • 18K. Pick up 5' ; no overpull was observed, verifying shear bolt was not _ - attached. 18:00 20:15 2.25 2,599 2,606 SLOT STK WPST P Start milling window @ 2599 ( TOW) t/ 2606' MD, Pump @ 400 GPM =825 V PSI, 80 RPM w/ 1 -5K TQ, WOB= 5 -7K, P /U= 105K, S /O= 108K. 20:15 20:30 0.25 2,606 2,606 SLOT RIGMNT SVRG T Swivel packing leaking, lubricate swivel packing. 20:30 22:15 1.75 2,606 2,611 SLOT STK WPST P Cont. t/ mill window from f/ 2606' MD t/ 2611' MD, Pump © 400 GPM =825 PSI, 80 RPM w/ 1 -5K TQ, WOB= 5 -7K, P /U= 105K, S /0= 108K. Slow pump rates @ 2590' MD, MP#1 20 SPM= 80 PSI, 30 SPM= 120 PSI. MP #2, 20 SPM= 90 PSI, 30 SPM= 130 PSI. 22:15 23:30 1.25 2,611 2,580 SLOT RIGMNT SVRG T PJSM, change out leaking swivel packing. 23:30 00:00 0.50 2,580 2,580 SLOT RIGMNT SVRG T R/D top drive landing and test top drive for leak after changing swivel packing. 07/07/2012 Continued to mill window t/ 2638' MD. Work though window and CBU X 2. Perform LOT t/ 13.5 ppg EWM. POOH. M/U kick off BHA and RIH. Time drill f/ 2638' t/ 2653' MD. Drill ahead. Page 24of38 1 • • Schwartz, Guy L (DOA) From: Myers, Monty M <Monty.M.Myers @conocophillips.com> Sent Tuesday, July 03, 2012 8:36 AM To: Schwartz, Guy L (DOA) Subject: 3N -07A cement plug PH> b'4 —o y Guy, As per our discussion, We ran in hole with our tubing to place a cement plug inside the 7" casing from - 4000' to inside the 9 -5/8" casing at 2400'. The top of our 7" fish is at 2620'. On the way in, we encountered some trash and are unable to get past 3650'. We have 3 cuts in our casing, one at 3995', one at 3587' and one at 2900'. The cut at 3995' has good cement behind pipe according to the CBL. The cut at 3587' does not have cement behind pipe, but will be covered by our plug. As will the cut at 2900'. I am asking for approval to place the cement plug from -3650' to approx 2400'. The cement plugs will be pumped in 2 stages. Thank you! Enjoy the holiday! Monty M Myers Drilling Engineer ConocoPhillips Alaska 907.265.6318 office 907.538.9 968 cell t • • Schwartz, Guy t (DOA) From: Myers, Monty M <Monty.M.Myers @conocophillips.com> Sent Friday, June 29, 2012 3:13 PM To: Schwartz, Guy L (DOA) Subject: RE: Revised Permit and new directional plan for 3N -07A (PTD 18. - ° Z S) Thanks Guy' will get a copy to you soon. Monty M Myers Drilling Engineer ConocoPhillips Alaska 907.265.6318 office 907.538.1168 cell From: Schwartz, Guy L (DOA) jmaiItc yu ,schwarfz.,daiaska.gov] Sent: Friday, June 29, 2012 11:36 AM To: Myers, Monty M Subject: (EXTERNAL]RE: Revised Permit and new directional plan for 3N -07A (PTD Monty, You have verbal approval to proceed as outlined in our revised PTD application. The major changes as stated are exiting the 9 5/8" surface casing at about 2600' and vs the original plan pulling the 7" casing below the surface shoe and kicking off at about 3800' and in OH. The changes are due to the unexpected presence of cement in the 7" X 9 5/8" annulus around the casing shoe area. Please submit a hard copy of the revise PTD to the Commission as soon as possible. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Myers, Monty M [mailtp: onty.hi _Myers;a,conocophillips.rom] Sent: Friday, June 29, 2012 10:43 AM To: Schwartz, Guy L (DOA) Subject: Revised Permit and new directional plan for 3N -07A Guy, Please find the new permit for 3N -07A attached, and let me know if you have any questions! Have a great weekend and good days off next week. Monty M Myers 1 • • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, June 28, 2012 11:34 AM To: Myers, Monty M Subject: RE: 3N -07A change of plans ( PTD 182 -028 & 212 -052) Monty, As we discussed submit a revised 10 -401 application with the changes ... ( new directional, casing plan, etc,). Also send me an email outlining your plan with the new steps and I will discuss with commissioners to get verbal approval so you can operate over the weekend. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Myers, Monty M [mal to: Monty. d, 1 ,N3yersconocaphiliir Sent: Thursday, June 28, 2012 10:58 AM To: Schwartz, Guy L (DOA) Subject: 3N -07A change of plans ( PTD 182 -028 & 212 -052) Guy, Attached is a CBL from the intermediate hole on 3N -07A. I want to discuss some options with you going forward on this well. Our original plan was to sidetrack from below, the 9 -5/8" surface casing shoe that is at (3691'), and re -drill an 8 -3/4" hole and re -run 7 ". With the information we have gathered now with the attached CBL and the issues we have encountered, we might very possibly need to sidetrack this well from inside the 9 -5/8" surface casing, from 2550 - 2600'. We have cuts in the 7" (from bottom to top) at 3995, 3587' and 2930'. After we ran the CBL we cut the fish off at 2025' and recovered the 7" casing and have been working to get the 7" out of the hole since then. With the way we are currently progressing, it may still take a few days to get down to 2550' or deeper to sidetrack out of the 9 -5/8' casing. At this depth, our Anti - collision concerns with the surrounding wells, 3N -05, 3N-06 and 3N -08, go away. The plan would be to cement the inside of the 7" casing from at least 3630' to above our 7" fish (say 2600' if we get that deep), set a 9 -5/8 whipstock and drill our 8 -3/4 hole from here and re-run 7" and continue our plan from there. Let me know what you think. Thanks! Monty M Myers Drilling Engineer ConocoPhillips Alaska 907.265.6318 office 907. 538.1168 cell 1 IS 60,28 WELL LOG TRANSMITTAL erveg To: Alaska Oil and Gas Conservation Comm. June 26, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 SCANNED RE: Cement Bond Log: 3N-07 Run Date: 6/20/2012 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-07 Digital Data in LAS format, Digital Log Image file a 1 CD Rom 50-029-21539-00 Cement Bond Log 1 Color Log ' 50-029-21539-00 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 2 Signed: _ �� • t`64,- a2�S Zt55�) WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. May 9, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Radial Cement Bond Log/Jet Cut Record: 3N -07 Run Date: 5/5/2012 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 -07 Data in LAS format, Digital Log Image files 1 CD Rom 50- 029 - 21539 -00 Cement Bond Log 1 Color Log 50- 029 - 21539 -00 KAMM APR 242013 PLEASE ACKNOWLEDGE RECEIPT BY .SIG MIG. 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 5 \% A4464 Date: f �Z Signed: 6-es4 VSG -027S • • S WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. April 23, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 HED X42 U14 RE: Jet Cut Record: 3N -07 Run Date: 4/20/2012 The technical data listed below is being submitted herewith PleassAd Tess any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3N -07 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 21539 -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 ate: 5 keg 111— Signed: /_ i • • SEAN PARNELL, , GOVERNOR 1�ey adkO n�m r ® c 11.E LIMED 11 D .r� �t riC J 333 W. 7th AVENUE, SUITE 100 CIDMI aRTEIMOR y � �L.® c�c�`01:1 D y ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276-7542 John Peirce Wells Engineer 0 2' ConocoPhillips Alaska, Inc. ( P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3N -07 Sundry Number: 312 -113 Dear Mr. Peirce: SAME APR 2LUIZ 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, Cathy . Foerster Chair DATED this may. day of March, 2012. Encl. • ' STATE OF ALASKA 0 ° ALIA OIL AND GAS CONSERVATION COMMI•N Wvv Z ....)) 9 ! 2 APPLICATION FOR SUNDRY APPROVALS l ,z 20 AAC 25.280 1. Type of Request: Abandon * ; Plug for Redrill 17 • Perforate New Pool r Repair well r Change Approved Program r Suspend r Rug Perforations r Perforate r Pull Tubing r Time Extension J` Operational Shutdow n r Re -enter Susp. Well r Stimulate Alter casing 9 r Other: r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 17 Exploratory r 186 - 028 • 3. Address: Stratigraphic r Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 21539 - 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 Iii 3N -07 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25521 - 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): 7793 - 6733 - 7624' 6606' 7129' 7516' Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 115' 115' SURFACE 3654 9.625 3691' 3634' PRODUCTION 7675 7 7707' 6669' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7349' 7356', 7407' 7427', 7443' - 7465' 6402' 6407', 6446 6 6472' - 6489' 2.875 J - 55 7156 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER 'FHL' PACKER MD= 7045 TVD= 6175 RECEIVED PACKER - BROWN 'HB' HYDRAULIC PACKER MD= 7163 TVD= 6263 A NIPPLE - HES 'X' NIPPLE MD =500 TVD =500 MAR 2 3 201? 12. Attachments: Description Summary of Roposal P 13. Well Class after proposed wo ���� (�ii Detailed Operations Program E BOP Sketch r Explor r i�e nTdf� nr#* SSI i 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 3/25/2012 Oil E Gas r WDSPL r Suspended 17 � rZ 16. Verbal Approval: Date: VVINJ r GINJ r WAG r Abandoned • Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Peirce @ 265 -6471 Printed Name John Peirce Title: Wells Engineer Signature > / Z - i„/ z ' — Phone: 265 -6471 Date 3/z2/12 / Commission Use Only Sundry Number:31 Z. 1 13 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity K BOP Test r Mech Integrity Test F Location Clearance r i�e`f') ., pc cam"r 45 C ••• .!! 3 _.'a) b p &)( / • es t Subsequent Form Required: ` y 6 7 / / Q APPROVED BY _/ Approved by: COMMISSIONER THE COMMISSION Date: 3 _ ` Z r, . ; �� " A �"e A ric U 4 1011 J3 � � ORIGINAL �/r Submit in Duplicate /-7,. _( v. ' • • 3N -07 Pre -ST P &A Proposal The objective of 3N -07 P &A of is to prepare for a Rotary Sidetrack to be followed by Coil Tubing drilled laterals to new bottom -hole locations. The Rig -ST is currently scheduled for May 2012. A 1/24/05 Video verified collapsed 7" casing exists at 7356' RKB. 3N -07 has been SI since June 2009. On 3/12/11, rocks & sand were tagged at 7353' RKB indicating almost all the perforations were covered by fill. A SBHP on 3/1/12 at 7300' RKB = 3637 psi; EMW = 11.0 ppg. Per this outline, a Pre -Rig ST P&A is proposed to isolate the A & C sand perf intervals below a XXN Plug currently set in a 2.25" XN Nipple at 7129' RKB to secure the well. Injectivity to the perforations below the XXN Plug has not been verified. It is proposed that a Cement P&A be performed by placing a 15 bbl cement plug in the tubing and IA above the XXN Plug. 20 AAC 25.112 (c) (1) (E) governs this P &A plan. Variances are requested as follows: - -- 1) The section stipulates using a Bridge Plug. We request a variance to use a combination of a v production packer set at 7045' RKB and an XXN Plug set in the XN Nipple at 7129' RKB. 2) The section stipulates that the bridge plug must be set no more than 50 feet above the perforated interval. We request a variance since our production packer is 304 feet above the top of the perforations and our XXN Plug is 220 feet above the top of the Gerforations. Cowcvr. k'Cll had keen r'y 45.4 o/PC/,'.,e pr,v- T 0 Proposed P &A: p,n /4 r � . 4 200 9 ' 4 (f01P r 4401 o1rn� fi i /so tat..0 p va ar9 r eC41f• re. than Do .'r ZT if l� k�l wtl/ wDu,G� �� >�c Cos n � ,� // Jam► Slickline: Colkireo caf�+� «*q • - ej' S AV/eel - Tj Co�nA94I "1 i fi' {� / NN fi � / 54 track tiv ert, n j hr„ r 4,06,4 4/ jhe C✓defir eV / Per r vl //� e �� � ally* 1 Fool% 6F, T f�f� a 1) RIH with 2.20" (min run OD) x 14' OAL dummy drift to 6900' RKB to verify that a 2.125" run OD x 14.6' OAL Cement Retainer will drift to target set depth. � 2) Set Catcher Sub on XXN Rug at 7129' RKB. Pull GLV's from GLM #1 (2705' RKB), GLM #2 (4235' RKB), GLM #3 5454' RKB, and pull OV from GLM #4 (6383' RKB). Install DV's in GLM's #1, 2, 3, and 4 to dummy off tubing for MIT's. 3) MITT to 2500 psi to verify tubing & XXN Plug integrity. Perform MITIA to 2500 psi. ✓' 4) Pull DV from GLM #5 at 6973' RKB. Leave pocket open to enable circulating cement to IA. If DV in GLM #5 cannot be pulled, perform E -line tubing punch at 7005' RKB at middle of a full joint. Pull DV from GLM #1 (2705' RKB) and leave pocket open to circulate from IA to Tbg x CT annulus during cement P &A. Pull Catcher Sub. Coil Tubing: 5) Notify AOGCC Inspector (659 -2714; pager 659 -3607) of date & time for cement P&A. RU CTU & PT equipment. Mix —16 bbls ( -75 sxs) of 15.8 ppg Class G Cement with additives to pump 15 bbls of cement down coil tubing. Cement volume for P &A: (XXN Plug 7129' - TOC in Tbg 6727')(0009714)(2.441 = 2.4 bbls in Tbg. (Packer 7045' - TOC in IA 6629')(0009714)(6.276 - 2.875 = 12.6 bbls in IA. Total cement needed is 15 bbls. Pump cement total = 15.0 bbls. • Leave 7" x 2 -7/8" IA SI during job. Line up for returns from Tbg x CT annulus to tanks. RIH with 2 -1/8" Inflatable Cement Retainer on CT while displacing CT and 2 -7/8" tubing to Seawater. Set Cement Retainer in 2 -7/8" tubin,gat 6900' RKB. With Cement Retainer set, circulate Seawater through Retainer to 7" x 2 -7/8" IA through open GLM pocket at 6973' RKB, then up IA to open GLM pocket at 2706' RKB to Tbg x CT annulus to tanks. Circulate until clean Seawater is seen at return tank. Swap to pumping 15 bbls of 15.8 ppg Class G cement at 1.0 - 1.5 bpm down coil while /- taking returns from Tbg x CT annulus, followed by Continued pumping of 5 bbls of Seawater spacer at 1.0 - 1.5 bpm down coil while r continuing to take returns from the Tbg x CT annulus, followed by -45 bbls of Biozan Gel, while taking returns from Tbg x CT annulus. Pump 14 bbls of cement at -1.0 bpm through the Cement Retainer while continuing to ,- take 1:1 returns from the Tbg x CT annulus to spot cement on top of the XXN Plug at 7129' RKB, and into the 7" x 2 -7/8" IA. Do not over - displace cement to IA to avoid displacing cement too high up the IA. With 14 bbls of cement through the Cement Retainer, PU CT off Retainer to pump the last barrel of cement on top of the Retainer to - 6727' RKB while POOH with CT and taking returns from Tbg x CT annulus. Continue pumping the 5 bbls of Seawater Spacer out the coil while taking returns from CT x Tbg annulus to tanks, followed by POOH while pumping the 45 bbls of Biozan followed by 16 bbls of Diesel for FP of 2 -7/8" tubing plus 1 additional CT volume of Diesel to FP CT, followed by Shutdown. RD CTU. Final estimated TOC top of cement should be -6629' RKB in the IA and -6727' RKB in the tubing. If any need arises after cementing to confirm TOC in the IA, a CBL can be run to find TOC since we plan to leave TOC -100' deeper in the tubing than in the IA. Slickline: 6) WOC 24 hours. Notify AOGCC Inspector (659 -2714; 659 -3607 pager) of the timing of the post- cement plug iag and PT. RIH & drift tubing to PBTD (TOC). Perform CMIT (GLM #1 at 2706' RKB has open pocket) to 1700 psi to PT cement plug in tubing and IA, and hold for 30 minutes. Record test results. Perform a drawdown test by bleeding down the tubing and IA pressure to open top tank. Tubing & IA should bleed down to 0 psi to verify good cement P &A integrity. Record test results. Set DV in GLM #1 at 2706' RKB. This will enable circulating only through the tubing cut after E -line cuts the tubing (step #7) to verify indication of a good cut. E -line: 7) RIH with tubing cutter for 2 -7/8" tubing. Cut tubing at +/- 6000' RKB near the middle of a full joint. This cut location is -2000' below planned sidetrack KOP of -4000' RKB. POOH with tubing cutter. • • Pump diesel down the tubing while taking returns from the IA noting rates and pressures to verify indication of a successful cut. 8) Set BPV. Pull well house and prepare site for the rig. D141 Rig Operations continued below. D141 Rig Operations: 1. Move Doyon 141 on 3N -07A and rig up. 2. Pull BPV. Record tubing, IA, and OA pressures. Circulate out freeze protect through tubing cut and monitor well for pressure. 3. Set BPV and nipple down tree. M/U blanking plug in tubing hanger and nipple up BOPE. • Notify AOGCC field inspector 24 hours prior to BOPE test. • Test BOPE to 250 psi low / 3,500 psi high as per drilling permit 4. Pull blanking plug & BPV. Pump -90 bbls of 11.0 ppg mud pill down the tubing through the tubing cut at -6000' MD while taking returns from 7" x 2 -7/8" annulus to displace Seawater from tubing and 7" x 2 -78" annulus below -4200', then PU tubing hanger & lay down 2 -7/8" tubing from above -6000' MD tubing cut. The 90 bbls of mud pumped will remain to occupy 7" casing from TOC (-6727' MD in tubing stub, and -6629' MD in IA behind tubing stub) up to -4400' MD. 5. Run 7" casing scraper to - 4,400' MD. 4 65 3,1 6. Set 7" bridge plug bottom at approximately 4,400' MD. ----�' 7. Cut 7 "casing at =4,300" and pull 7" packoff. 8. Lay down 7" casing. 9. RIH to 4,300' with DP and pump 80 bbls of Class G cement plus additives at 15.8 ppg for kick off plug. 10. POOH and WOC minimum of 12 hrs ( 11. While WOC prep directional tools and PU bit, motor and MWD tools and perform housekeeping. 1� 12. Pick up DC's and HWDP and DP and run in hole to 3,000' and displace hole. 13. Stage in hole to top of cement plug and dress it off to =3,900'. 14. Orient MWD and motor and begin time drilling off of cement kick off plug. 15. Perform LOT with rig pump as per CPAI procedure to 16 ppg EMW. Minimum acceptable leak off is 12.5 ppg EMW. 16. Drill 8 -1/2" hole from 4,000' MD to 7,106' MD (above C Sand). KUP 3N -07 � �' �� � F 1 W Well 5 bore Attributes P U WI KUd Name RIVER UNIT Max Angle Act G OMCrfPh6 l � Well Status In 4l 47.27 5,700.00 7,79 MD (5,700 Ad Bt,7 7,793.0 ' ( ` ;PROD j 47.2 I 3.0 ....................................... ............................... " Comment H2S (ppm) Date Annotation End Dab KB-Ord (R) Rig Releue Date °° Well Conks - 3N --07 , 3/22r2012 8:10 37 AM SSSV: NIPPLE 100 12/21/2008 Last WO: 12/12/2003 38.49 3/7/1986 Schematic Annotation Depth (RKB) End Date Annotation Last Mod By End Date Last Tag: SLM 7,346.0 3/12/2011 Rev Reason: REVISE PACKER ninam 3/22/2012 Casing Strings .4 J t :, i ,, 5µs I Casing Description String 0... String ID ... Top (RKB) Set Depth (f._ Set Depth (VD)... String Wt... String ... String Top Thrd HANGER, 32 ' .. CONDUCTOR 16 15.062 35.0 115.0 115.0 62.50 1i Welded L 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 37.0 3,691.4 3,633.9 36.00 J - 55 BT&C Casing Description String 0... String ID ... Top (RKB) Set Depth (f._ Set Depth (ND)... String Wt... String ... String Top Thrd PRODUCTION 7 6.276 31.3 7,706.6 6,668.9 26.00 J-55 BTBC Tubing Strings'r: Tubing Description String 0... String ID ... Top (MB) Set Depth (f... Set Depth (ND)... String Wt... Sting ....String Top Thrd B TUBING 2 7/8 2.441 32.5 I 7,156.3 6,257.7 6.50 I L -80 I ABM -EUE CONDUCTOR, Comple tion Details , - ' 38115 Top Depth (ND) Top Intl Nora.. NIPPLE, 500 IT Top (RKB) IMO) ( °) Item Description Comment ID (in) 32.5 32.5 H FMC TUBING HANGE 2.875 500.0 500.0 0.53 NIPPLE HES'X' NIPPLE 2.313 1. II GAS LIFT, 7,031.5 6,164.5 41 0.23 .82 PBR B AKER 80 -00 PBR/SBR 2.441 2,706 7,045.1 6,174.7 41.79 PACKER BAKER 'FHL' PACKER 2.950 I 7,128.9 6,237.1 41.65 NIPPLE HES'XN' NIPPLE W /4:303 _ e 3 -2.- 1 .250 , y,,, i'aa XI) 7,141.2 6,246.4 41.63 SEAL ASSY BAKER SEAL ASS ' 0 LY, STABBED INTO ORIGINAL COMPLETIO ( 2.500 PBR @ 7151' Tubing Description String 0... String ID... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE, TUBING Original 27/8 2.441 7,151.3 7,234.3 6,315.9 6.50 1 J - 55 EUE8rdABMOD 37 -3,691 Completion Details, ,,,,Ii„ `fi , - - Top Depth GAS LIFT, I- (ND) Top Ind Nomi... 4,235 Top (RKB) (RKB) (°) Item Description Comment ID (In) 1 7,151.3 6,253.9 41.61 PBR BROWN PBR 2.500 1 7,162.9 6,262.6 41.59 PACKER BROWN 'HB' HYDRAULIC PACKER 2.500 GAS LIFT, 3 �i 7,200.8 6,290.8 41.37 NIPPLE CAMCO NIPPLE NO GO 4 IP }..2 {uy � 5,454 7,233.6 6,315.4 41.40 SOS (SHEAROUTSUB 2.438 $ Other In Hole (Wireline retrievable plugs, valves; pumps; fish, etc.) Top Depth (TVD) Top Inel GAS LIFT, El,- _ Top (ftKB) (MB) (°) Description [ Comment Run Data ID (In) 6,383 7,129 6,2372 41.65 PLUG HES 2.31" XXN PLUG (OAL =49") 3/2/2012 0.000 II II 7,356 6,407.2 41.53 Collapsed Shows location of tagged collapsed Production CSC; bottom 11/21/2009 1.000 Casing depth not known III 7,516 6,526.7 41.81 FISH 1 1/2" DMY 8 1 5/8" JDS Lost in Rathole 4/12/1987 GAS LIFT, I 6,973 t Perforations.& Slots , , ;_ - II Shot Top (ND) Btm (ND) Dens II Top (fIKB) Btm (8103) (RKB) (RKB) Zone Date Oh- Type Comment 8 7,349 7,356 6,401.9 6,4072 C-4, 3N-07 10/18/1986 8.0 IPERF 2 1/8" EnerJet, 0 deg. ph LOCATOR 7,407 7,427 6,445.6 6,460.4 A -3, A -2, 3N-07 10/1811986 8.0 IPERF 2 1/8" EnerJet, 0 deg. ph SUB, 7,029 SPACE OUT, 7,420 7,420 6,455.2 6,455.2 A - 2, 3N - 07 4/25/1986 1.0 IPERF 4" HJ II Csg Gun; 90 deg. ph 7,030 PBR, 7,032 „ - ! 7,422 7,422 6,456.7 6,456.7 A - 2, 3N - 07 425/1988 1.0 IPERF 4" HJ II Csg Gun; 90 deg. ph _ PACKER, 7,04$ 7,443 7,465 6,472.3 6,488.7 A -1, 3N -07 4/25/1986 4.0 IPERF 4" HJ II Csg Gun, 90 deg. ph Notest, General &Safety a End Date Annotation I 1/24/1999 NOTE: WAIVERE° WELL: IA x OA COMMUNICATION .- .. 10/19/2004 NOTE: 2' HOLE IN CASING @ 7362' PER VIDEO NIPPLE, , 7 7,129 ,129 / s 12/3/2004 NOTE: POSSIBLE SPLIT /COLLAPSED CASING @ 7359', IMPASSABLE PLUG 1/24/2005 NOTE: KNOWN SEVERE CASING COLLAPSE PER VIDEO LOCATOR 5/23/2009 NOTE: View Schematic w/ Alaska Schematic9.0 SUB, 7,139 SPACE OUT, 11/21/2009 NOTE: TAGGED COLLAPSED PRODUCTION CASING @ 7356' 7,139 SEAL ASSV, 7.,4, ' De '2,003 IkW . - row, net., 1 - tt.7, ,. SP' '' e PER 7,151 J ""°" • 43 PACKER, 7,163 .j., NIPPLE, 7,201 B Ii SOS,7,234 A v.Ntr- 2.#l, Sic p 'a'k IPERF. = T� �ei ° -'° 3+a *A 2 i� 1 b 1� A / G ' + r'� a 7,4&7,356 c ouapaaa - " • CaaM. 7358 Mandrel Details Top Depth Top Port (TVD) Mel OD Valve Latch SIaa TRO Run 7,407PERF, Stn To MO (RKB) (") Make Model (In) Sue TYM Tyne PO (psi) Run Date Com... IPERF, 7,420 = IN 2,705.8 2,704.6 1112 CAMCO KBMG IIII GAS LIFT GLV ma 0.156 1,304.0 12/23/2003 - IPERF, 7,422 4 © 4,235.2 4,094.4 13/ CAMCO KBMG II GAS LIFT GLV I� 0.188 1,342.0 6/132009 11111 ' - 1 5,454.2 5,024.9 43.90 CAMCO KBMG III GAS LIFT GLV BK-5 0.250 1,446.0 1/26/2004 ■ IPERF, 6,383.4 5,685.2 42.90 CAMCO KBMG GAS LIFT OV BK -5 0.250 0.0 6/13/2009 7,4467, 466 5 6,973.4 6,120.9 41.60 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0.12/12/2003 FISH, 7,516 PRODUCTION, 3, -7,707 TD, 7,793 • • 3N -07 Pre -Rig Sidetrack Plug & Abandonment Current Completion Proposed Pre -Rig ST P &A 2 -7/8" L -80 Tbg to 7234' RKB 9 -5/8" J-55 Surf Csg Est. Rig ST KOP to 3691' RKB +/- 4000' RKB mil Tubing Cut at 5 GLM's 6000' RKB 15.8 ppg CI G Cmt; 15 bbl total: in IA: 6629 - 7045' RKB (416') i n Tbg: 6727 - 7129' RKB (402') MEM ;:;N Cement Retainer at 6900' RKB Baker 80 -40 PBR Baker FHL Packer 1111 7045' RKB 2.25" HES XN Nipple, with XXN Plug 7129' RKB Brown HB Hydr Packer -- 7162' RKB 2.25" Camco D Nipple 7201' RKB Rocks & Sand to 7353' RKB _ C & A Sand Perfs _ 7349 - 7465' RKB Collapsed 7" Csg at 7356' RKB — 7" J -55 Prod Csg •'''' ". .'' ` to 7706' RKB JWP 3 -22 -12 3N-A Slot Recovery III 16" 62.5# H40 4 conductor set at 115' 3 'A" TRMAXX -CMT SCSSV 2.813" ID @ 1800' MD /1800' TVD Cut A 9 -5/8" 36# J -55 ut &pull 7" Csg Surface set t • Wash over 7" to +/- 300' below • surface shoe @ 3,691' MD MD/ 3,6634 34 TVD ST +/- 300' below surface shoe Approx -3991' (wp07) GLM # TVD ft MD ft Valve Type Mandrel Type 1 2,500 2,500 Dummy 3 -1/2" x 1 -W NNG 2 3,700 3,766 Dummy 3 -1/2" x 1 -W NNG 3 4,600 4,863 Dummy 3 -1/2" x 1 - NNG Cut 7" Csg at 4300' MD 4 5,300 5,748 Dummy 3 -1/2" x 1 -'/" NNG 5 5,850 6,463 Dummy 3 -1/2" x 1 -'/" NNG Bridge Plug at -4400' MD �-� 6 6,141 6,860 SOV 3 -1/2" x 1 -W NNG 'SOV (annulus to tubing shear) SN - 3 - %2" 9.3 #, L 80,Design TBD, Surf - 6,900' 11 ppg Mud between MD mechanical plugs 114N111§111 . • :...::::, \\. • Tbg Cut at 6000' MD ,..:.:.0) 15 bbls of 15.8# CI G Cmt .::..: :,:\' .: • Above Pkr & XXN Plug • XXN Plug at 7129' MD 3 'h" HES "X" selective nipple w/ 2.813" ID @ 6,860' MD / 6,141' TVD :' V 0 .1 Baker 4 - % "X7" ZXP liner packer hanger @ -6,900' MD / 6,169 TVD' ::.:- ' - :\:,%., 7" casing set (topset) ‘,\‘,, @ 7,106' MD / 6,315' TVD _$Y 7" Cs collapsed --.41::: v r: — 9 P _ n l∎— w/ fill over perfs {� ' bs.... 4 -1/2" Liner set @ 7,494' MD / 6,589' TVD • • Page 1 of 1 Subject: FW: INTENT PLUG for RE -DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monday, February 08, 2010 10 :52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE -DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE -DRILL WELLS (IPBRD) Type Work Code in RBDMS 1. When a Form 10 -403 is submitted requesting approval to plug a well for redrill, the initial reviewer (Art or Steve D.) will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 L' form is checked. If the "Abandon" box is checked, we will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). 2. On the Form 10 -403 if "Abandon" is checked in Box 15 (Well Status after proposed work), Art or Steve D. will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). Instead, we will check the "Suspended" box. Guy and Winton will serve as quality control for steps 1 and 2. 3. When Steve McMains receives the Form 10 -403 with a check in the "Plug for Redrill" box, he will enter the existing code "IBPRD" into RBDMS. This code automatically generates a comment under the History tab stating "Intent: Plug for Redrill." 4. When Steve McMains receives any Form 10 -407, he will check the History tab in RBDMS for this comment. If he sees the "Intent: Plug for Redrill" code, and cannot find any evidence that a subsequent re -drill has been COMPLETED, he will assign a status of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10 -407. Steve will also change the status on the 10 -407 form to SUSPENDED, and will date and initial his change. If Steve does not see the "Intent: Plug for Redrill" comment or code, he will enter the status listed on the Form 10 -407 into RBDMS. 5. When the Form 10 -407 for the redrill is received, Steve M. will change the original well's status from suspended to abandoned. 6. The first week of every January and July, Steve M. and Steve D. will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, Steve M. and Steve D. will also review the list of suspended wells for accuracy. Thanks, Steve D. file: //F:\ Daily_ Document_ Record \Procedures_ Instructions \FW INTENT PLUG for RE -D... 3/23/2012 • Page 1 of 1 Regg, James B (DOA) r"~ i -C~2~ From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Thursday, November 12, 2009 10:02 AM '`C(~ ~i~7 ~~~ To: NSK Problem Well Supv; Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv; CPF3 DS Lead Techs; CPF3 Prod Engrs; Briese, Levi J Subject: 3N-07 (PTD# 186-028) Report Of TxIA Communication Attachments: 3N-07 Wellbore Schematic.pdf; 3N-07 TIO Plot.pdf Jim/Tom/Guy, /" Kuparuk gaslifted producer 3N-07 (PTD# 186-028) is suspected of having TxIA communication based upon a failed shut in TIFL on 11/09/09. A leaking gaslift valve is suspected so slicklirie will repair if possible. CPAI will add N-07 to e SCP Report and the well will be fixed or shut-in by 12/07/09. Attached area 90 day TIO plot and wellbore schematic. ~' Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 1 ~C~ ~~~ ~;~ ,~ ~ ~ k 11 /27/2009 Well Name 3N-07 Notes: End Date 12/1/2009 Days 120 Start Date 8'3'2009 Annular Communication Surveillance 2500 _. - ---- _-~ _ _ WHP _ -- -- ,.~ 80 IAP OAP 70 WHT 2000 60 50 1500 - 'y Q. LL 40y ~ 1000 30 20 500 - 10 0 0 Aug-09 Sep-09 Oct-09 Nov-09 ~DGI ~MGI -"'~PWI so `~SWI ~ ~BLPD ` iod - f • • T, ... ~`,,~ KUP Ct~°~acoPhilli~s ~~ `~ ... weu conea. -3N-o~ , - 5 h ma1i~ A fuel MANGER. 32 ~ ~ llI I ~- F CONDUCTOR. 35-115 NIPPLE, 500 ~. '' GAS LIFT, j .~ _ II z,7as -T SURFACE. 37-3,691 I GAS LIFT. r- _-7.7 4.235 _ ~_ GAS LIFT, ~ _ 5,454 ,~ GAS LIFT, - ~ ;~ Q363 1- .< GAS LIFT, ~ ~ 6,873 ,~ LOCATOR - " sub, 7.ozs SPACE OUT, 1. j 7,030 „J PBR, 7,032 PACKER, 7,045 U ~ } _-_J s NIPPLE, 7,129 ~ _~ CCC LOCATOR SUB, 7,139 JI SPACE OUT, 7,139 1. _! SEAL ASSY, - 7,141 PBR, 7,151 PACKER, 7,163 NIPPLE, 7,201 SOS, 7,234 IPERF, 7,349-7,356 IPERF, 7,407-7,427 IPERF, 7,420 IPERF. 7.422 IPERF, 7,443-7,465 FISH, ],516 a 3N-07 - - D _ ax An le & M WPII Attributes TD _ _ _ ibore APliUWI Field Name Wed Status I:,c. (°) >00292153900 KUPARUK RIVER UNIT PRODUCING 47.27 _ MD (ftKe) 5,700.00 Act edn (RKB) 7,793.0 i C meat H2S (ppm) Date SSSV: NIPPLE 100 12/21/2006 Annotahon End Dafe Last WO. 12/12/2003 KB•Grd (ft) 38.49 Rlg Release Date 3/7/1986 A ota[ion Depth (kKB) Last Tag RKB 7.356.0 End Date Annofad n 8/23/2009 Rev Reason: ADD NOTE. TAG FILL RKB Last Mod By triplwj_ End Date 8/29/2009 Casing Strngs Casing Descnption String 0... String ID ... Top (RKB) Set Depth (t... Set Depth (ND) ... String Wt.., String ...'String Top Thrd CONDUCTOR 16 15.062 35.0 115.0 115.0 62.50 H-40 Welded Casing Description SURFACE String 0... 9 5/8 String ID .. 8.765 Top (kKB) 37.0 Set Depth ((... 3,691.4 Set Depth (ND) ... 3,633.9 String Wf... 36.00 String ... J 55 String Top Thrd BT&C Casing Description String 0... Stang ID ... Top (kKB) Set Depth (f... Set Depth (ND) ... String WL.. String ... String Top Thrd PRODUCTION 7 6 276 31.3 7 7116 6 6.668.9 26.00 J-55 BT&C Tubing Strings _--T - -- T b gDescrlpt on Str'ng 0... SIr gID ..Top (ttKBJ SetD pth (r. 1Set Depth (TVD). ISt nq WL.. Str ng String Top Thrd 32.5 7 156.3 I 6,257.7 I 6 50 L-60 I ABM-EUE TUBING 12 7I6 12 441 I _ _ _.__ Comple_ tion Details Top Depth (ND) Top Incl Top ftKB (ftKB) (°) Item Description Comment ID (in) 32.5 32.5 0.23 H ANGER FMC TUBING HANGER 2.875 500.0 500.0 0.53 N IPPLE HES 'X'NIPPLE 2.313 7,031.5 6,164.5 41.82 P BR BAKER 80-40 PBR/SBR 2.441 7,045.1 6,174.7 41.79 P ACKER BAKER'FHL' PACKER 2.950 7,128.9 6,237.1 41.65 N IPPLE HES'XN'NIPPLE 2.250 7,141.2 6,246.4 41.63 S EAL ASSY BAKER SEAL ASSEMBLY, STABBED INTO ORIGINAL COMPLETION PBR @ 7157' 2.500 Tuhing Description String 0... String ID ... Top (ftKB) Set Depth (f... Sat Depth (ND) ... String Wt... String ... String Top Thrd TUBING Original 27/8 2.441 7,151.3 7,234.3 6,315.9 6.50 J-55 EUE6rdABMOD Completion Details Top Depth (ND) Top Incl Top (ftKB) (ftKB) (°J Item Description Comment ID (in) 7,151.3 6,253.9 41.61 P BR BROWN PBR 2.500 7,162.9 6,262.6 41.59 P ACKER BROWN'B'HYDRAULIC PACKER 2.500 7,200.8 6,290.8 41.37 N IPPLE CAMCO'D' NIPPLE NO GO 2250 7,233.6 6,315.4 41.40 S OS SHEAROUT SUB 2.438 Other In Hole Wireline retrievable plugs, valves, pumps fish etc. _ Top Depth (ND) Top Incl Top (kKB) (ftKB) (°) Description Comment Run Date D (in) 7,516 6,526.7 41.81 F ISH 1 1/2" DMY & 1 5/8" JDS Lost in Rathole 4/12/1987 jPerforations & Slots ___ _______ _ ____ I _ Top (kKB) ... -- Btm (ftKB) Top (ND) (kKB) T ,__ Btm (ND) (TtKB) ~ .. Zone Date Shot Dens (sh... Type Comment 7,349 7,356 6,401.9 6,407.2 C -4, 3N-07 10/18/1986 8.0 IPERF 2 1/8" EnerJet, 0 deg. ph 7,407 7,427 6,445.6 6,460.4 A -3, A-2, 3N-07 10/18/1986 8.0 IPERF 2 1/8" EnerJet, 0 deg. ph 7,420 7,420 6,455.2 6,455.2 A -2, 3N-07 4/25/1986 1.0 IPERF 4" HJ II Csg Gun; 90 deg. ph 7,422 7,422 6,456.7 6,456.7 A -2, 3N-07 4/25/1986 1.0 IPERF 4" HJ II Csg Gun; 90 deg. ph 7,443 7,465 6,472.3 6,488.7 A -t, 3N-07 4/25/1986 4.0 IPERF 4" HJ II Csg Gun, 90 deg. ph iNotes: General 8 Safe __ ______ End Date Annotation 1/24/1999 NOTE: WAIVERED WELL: IA x OA COMMUNICATION 10/19/2004 NOTE: 2" HOLE IN CASING @ 7362' PER VIDEO 12/3/2004 NOTE: POSSIBLE SPLIT/COLLAPSED CASING @ 7539', IMPASSABLE 1/24/2005 NOTE: KNOWN SEVERE CASING COLLAPSE PER VIDEO 5/23/2009 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 Ma _ _- ~p Depth Tap Port (ND) Incl OD Valve Latch SKe TRO Run (ftKB) (°) Make Model Ilnl Sarv TYPe Type tin) (psi) Run Date Com... GAS LIFT i`~~ ~~~7~~i •~ ~Ze~~SI b-R~~ PRODUCTION, 31-7,707 Tp, ],793 • • ~~ . • ConocoPh~ll~ps Alaska P.0. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 23, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission r ~ ~ ~.., 333 West 7~' Avenue, Suite 100 b Anchorage, AK 99501 ~~ ~ Q 3~ Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRLn. Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped October 19, 2008 and the corrosion inhibitor/sealant, was pumped October 21, 2008..The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. ;. Sincerely, ;~ ~'~ ~. G~i ~` MJ La eland ConocoPhi~ips Well Integrity Projects Supervisor `~~ PVC ~' ~ a- 20~~` • ~ ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field n~+e 10/22/2008 .0 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 3N-01 185-313 32' 5.00 21" 10/19/2008 3.4 10/21/2008 3N-02A 186-032 66' 10.00 4"2" 10/19/2008 10.2 10/21/2008 3N-03 186-016 43' 6.00 22" 10/19/2008 5.1 10/21/2008 3N-04 186-017 83' 9.00 24" 10/19/2008 10.2 10/21/2008 3N-05 186-026 21" NA 21" NA 2.55 10/21/2008 N-07 186-028 20' 3.50 21" 10/19/2008 3.4 10/21/2008 3N-08A 186-068 8' 1.50 21" 10/19/2008 5.1 10/21/2008 3N-09 186-030 14' 2.50 21" 10/19/2008 4.25 10/21/2008 3N-10 186-072 97' 12.00 5'8" 10/19/2008 15.3 10/21/2008 3N-12 186-079 62' 9.50 4'7" 10/19/2008 17 10/21/2008 3N-13 186-081 17' 2.00 35" 10/19/2008 4.25 10/21/2008 3N-14A 207-119 21" NA 21" NA 3.4 10/21/2008 3N-15 186-090 64' 8.00 20" 10/19/2008 6.8 10/21/2008 3N-16 186-091 71' 8.50 30" 10/19/2008 3.75 10/21/2008 3N-17 186-092 59' 6.00 22" 10/19/2008 5.1 10/21/2008 3N-18 186-093 49' 6.40 28" 10/19/2008 5.95 10/21/2008 3N-19 201-225 16" NA 16" NA 3.4 10/21/2008 Schlumberger Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth -~o~ Well Job # / g !-(jsý 1A-01 'ß3:' 27C 3F-09 (~I. ~,-D2ß 3N-07 IC¡-~~ IIf D 1 G-13 10/] - Zo/q 3F-06 1<2-- ,...·!f 2W-03 0::;- U ..- I .(,( - I ~ - 3F-02 j ()) - 2 ~ If! ,/ 1 E-114 L 1 ;'<0 t¡ - II( I 10922488 10922490 10922491 10922487 10922489 10942791 10942790 10687709 Log Description Date 11/19/04 NO. 3267 \q}ø'f,OC:1J€fJ" Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk BL Color CD LEAK DETECTION LOG PRODUCTION PROFILE PRODUCTION PROFILE LEAK DETECTION LOG PRODUCTION PROFILE LEAK DETECTION LOG PROD PROFILE/DEFT USIT 11/08/04 11/10/04 11//11/04 11/07/04 11/09/04 10/30/04 10/29/04 10/07/04 1 1 1 1 1 1 1 1 ~ - Î í r-" )/;; j~ ) S~ED: / ¡£rAU . )(Iutt'Vd~ Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. SC,ANNED !=\PR 1 5 2005 DATE: /~þ /0 'i Mike Mooney Wells Group Team Leader Drilling & Wells P. O. Box 100360 Y Anchorage, AK 99510-0360 Conoco Ph ¡IIi pS Phone: 907-263-4574 January 7, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 3N-07 (APD # 186-028) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent workover operations on the Kuparuk well 3N-07. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, /Il~ ;Jl~ M. Mooney Wells Group Team leader CPAI Drilling and Wells MM/skad RECEIVED JAN 1 3 2004 Alaska Oil & Gas Cons. Commission Anchorage .-." ~NEDJAN 152004 0 R \ G\ NAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: 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 Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory D 186-028/ 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360, Anchoraqe, Alaska 99510 50-029-21539-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 67' 3N-07 8. Property Designation: 10. Field/Pool{s): ADL 25521, ALK 2557 Kuparuk Oil Field 1 Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 7793' feet true vertical 6733' feet Plugs (measured) Effective Depth measured 7465' feet Junk (measured) 7516' true vertical 6489' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 115' 16" 115' 115' SUR. CASING 3624' 9-5/8" 3691' 3634' PROD. CASING 7640' 7" 7707' 6669' Perforation depth: Measured depth: 7349'-7356',7407'-7427',7443'-7465' RECEIVED true vertical depth: 6402'-6407',6445'-6460',6472'-6489' - JAN 1 3 2004 Tubing (size, grade, and measured depth) 2-7/8", L-80 1 J-55, 7234' MD. " .. Alaska Oil & Gas Cons. CommiSSion Packers & SSSV (type & measured depth) pkr= Baker 'FHL', BAKER 'HB' pkr= 7045', 7163' Anchorage sssv= NIP sssv= 500' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/ A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casino Pressure Tubina Pressure Prior to well operation SI - Subsequent to operation 372 385 1038 - 169 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run - Exploratory 0 Development 0 Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: oil0 GasD WAGD GINJD WINJ 0 WDSPLD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Guy Schwartz @ 265-6958 Printed Name Mike ~ooney Title Wells Group Team Leader,) .' Signature JttA ¡ All.., Phone Date t¡ rZ/Ó4 ,.., I ~ '" I C/VV"V' \ Preoared bv Sharon Alls/o-Drak~ 21'!3-4612 _SfL ,.158' \G\NAL Form 10-404 Revised 2/2003. 0 R SUBMIT IN DUPLICATE ConocoPhillips Alaska Page 1 of 6 Operations Summary Report Legal Well Name: 3N-07 Common Well Name: 3N-07 Spud Date: 3/1/1986 Event Name: WORKOVER/RECOMP Start: 12/3/2003 End: Contractor Name: N3Scompanyman@connocophi Rig Release: 12/16/2003 Group: Rig Name: Nabors 38 Rig Number: Date From - To Hours Code Sub Phase Description of Operations Code 12/3/2003 18:00 - 00:00 6.00 MOVE RURD MOVE RD berms under rig on 1 Y -25. Scope down derrick, lower derrick to carrier, blow down steam/wt, disconnect pipe shed, unplug complexes. Ready camp for move. Pull matts flunder pits & pipe shed. Hook trucks to pits and pipe shed. Jack down rig, move off the well. Pick up containment. Remove cradle with BOP. stack out from behind well and hauled to 3N pad. Move camp from 1 Y to 3N pad and connected phone lines and generator. 12/4/2003 00:00 - 01 :30 1.50 MOVE RURD MOVE Cleaned location and finished hook up of trucks to modules for move. 01 :30 - 04:00 2.50 MOVE MOVE MOVE Move rig from 1Y pad to 3N pad. 04:00 - 09:00 5.00 MOVE RURD RIGUP Spot BOP cradle behind well. Place rig mats around well for rig. Spread Herculite for containment. and spot carrier over well. Jack up and level carrier. Spot pits and pipe shed. Hook up steam and water, fold down stairs and hand rails. Plug in pipe shed and turn on heat. 09:00 - 10:00 1.00 MOVE RURD RIGUP Pre-job safety meeting. Go over derrick raising procedures. Continue to turn on all heaters. Take on water and fuel. 10:00 - 12:00 2.00 MOVE RURD RIGUP Raise derrick. Begin prep to light boilers. Inspect all tie down lines. Install valves to assist pump schedual. 12:00 - 14:00 2.00 MOVE RURD RIGUP Accept Rig @ 13:00 12/4/03. Mud on location @ 13: 15. Load pits. Prepare to circulate at 1 BPM. 14:00 - 18:00 4.00 WELLSR NUND RIGUP Prepare to flange up casing valves to pump initial circulation. Pre-spud meeting with all persons of interest. 18:00 - 20:00 2.00 WELLSR NUND RIGUP Install casing flange for pump program. Begin test of super choke, and safety valves. 20:00 - 22:00 2.00 WELLSR CIRC RIGUP Pumped 1 bbl down tubing taking returns from IA. Pump press 900 psi, with returns to bleed tank. Good fluid movement to prove not frozen up. 22:00 - 00:00 2.00 WELLSF NUND RIG UP Blow down lines, attempted to bleed small amount of press off tree. Getting back small flow of Methenal, BPV leaking. Attempted to pull BPV and replace but bent the retrieving tool. BPV full of gel not sheared out oor dehydrated mud. Ordered out another retrieving tool. Opened bleeder on tubing side and continued to bleed off methenol until tubing and IA zero. 12/5/2003 00:00 - 03:00 3.00 WELCTL OTHR WRKOVR Test choke manifold & Floor valve while checking press. and waiting on retrieving tool for BPV. Pull tree cap rinse top of BPV w/water, RU FMC lubricator. Attemp three times to pull BPV with no luck getting inside fishing neck. 14 psi when popit open. 03:00 - 04:30 1.50 WELCTL OTHR WRKOVR Changed out from retrieving tool to the setting tool and run in and attempt to open popit and bleed press. off. Tattle tale showed tool didn't open popit. Trash in fishing neck on top of or beside pop it. 04:30 - 06:00 1.50 WELCTL OTHR WRKOVR Cont. to test choke, weight up 30 bbls mud from 13.6 ppg to 13.9 in pill pit. RU to circ. well. Bled OA press off from 450 psi. BPV leaking at 5 gal per hr. 06:00 - 12:30 6.50 WELCTL OTHR WRKOVR Weight up mud. Pump 13.9 PPG mud through tubing taking returns up IA. Mud wt back = 13.3 PPG heavy. Pump cavitating. Rebuild suction valves. Pull BPV with difficulity. Re-set new BPV and monitor for 30 min, bleeding off little pressure with popit. 12:30 - 13:00 0.50 WELCTL BOPE WRKOVR Nipple DWN tree. Monitor well. Installed blanking plug. Bring in Bop's. Count pipe and cross overs. Strap pipe in pipe shed. 13:00 - 17:00 4.00 WELCTL BOPE WRKOVR Remove stack from cradle and bring into cellar. Prep wellhead for BOPE. Install DSA & put BOPE onto DSA. Torque up BOPE, install turnbuckle. 17:00 - 18:00 1.00 WELCTL EaRP WRKOVR Held PJSM. Cut l' off of riser and installed. 18:00 - 22:30 4.50 WELCTL BOPE WRKOVR Test blinds, HCR choke and manual choke. Blow down & drain stack. Printed: 1/6/2004 3:06:11 PM ConocoPhillips Alaska Page 2 of 6 Operations Summary Report Legal Well Name: 3N-07 Common Well Name: 3N-07 Spud Date: 3/1/1986 Event Name: WORKOVER/RECOMP Start: 12/3/2003 End: Contractor Name: N3Scompanyman@connocophi Rig Release: 12/16/2003 Group: Rig Name: Nabors 3S Rig Number: Date From - To Hours Code Sub Phase Description of Operations Code 12/5/2003 18:00 - 22:30 4.50 WELCTL BOPE WRKOVR Pull blanking plug, set landing jt.& fill BOP w/ water, test pipe rams-HCR kill-manual kill - to 250/4000 psi. Annular to 3500 psi. Witnessing by State waived by Jeff Jones. 22:30 - 23:30 1.00 WELCTL OTHR WRKOVR Drain stack, blow down lines, PU T-Bar and offset po pet on BPV to check for press. NO press. 23:30 - 00:00 0.50 WELCTL OTHR WRKOVR Ran retrieving tool on T-bar and attempted to pull BPV. Could not get collet on retrieving tool to latch into BPV. 12/6/2003 00:00 - 01 :00 1.00 WELCTL OTHR WRKOVR Continued to try to pull BPV. After several attempts finally got retrieving tool to catch and pulled BPV. 01:00 - 02:15 1.25 WELLSF PULD DECOMP RU landing jt. wI floor valve- head pin- circulating line. BOLDS. Pulled hanger out of seat, Monitored to ensure well was dead. Pulled 90K # attempting to PBR free. Worked pipe up and down and pulled 90K and set brake. PBR not coming free. 02:15 - 05:00 2.75 FISH CPBO DECOMP Back out landing jt. Install pups to space out landing jt just above rig floor 3'. RU Schlumberger E-line. Flowline froozen up, clear out for circulation. 05:00 - 06:30 1.50 WELCTL OTHR DECOMP Schlumberger E-line to STBY for flow line thaw progress report. Thaw out stand pipe. 06:30 - 10:30 4.00 WELCTL COND DECOMP Circulate two hole volumes to bring weight up. 13.6 in 13.3 out. Weigh up light mud in pit 2. Call out vac truck to empty pit 2. Send 170 BBLS 13.6 PPG mud to MI plant in Deadhorse. 10:30 -13:30 3.00 LOG OTHR DECOMP Rig up E-line prep to make a gauge run prior to SS and Chem cut. Call for 2.625" drift from warehouse. Load 3.5" P11 0 pipe into pipe shed. 13:30 - 19:00 5.50 LOG ELOG DECOMP E-line unable to pass 7,040' with 2.1/8" drift. Prep for 1.75" Drift. Could not get past 7040' with 1.75" drift. 19:00 - 21: 15 2.25 LOG ELOG DECOMP E-line RIH with Single Strand String Shot, located tubing collar just at 7048' just above depth of two drift runs. Adjusted depth of SS and shot 10' above collar @7038'. This will be the preferred spot for chemical cut. No movement of pipe. POOH with E-line. 21:15 - 00:00 2.75 LOG ELOG DECOMP RU Schlumberger Chemical Cutter, RIH and confirm depth of 7038', 10' above collar on jt 227' and cut 2-7/8" tubing at this depth (7038'). 12/7/2003 00:00 - 05:00 5.00 LOG ELOG DECOMP POOH with e-line. Cuttter tools hanging up on collars coming out. Mud in pump-in sub frooze up, thawed out, hooked back up and established circulation with 100 psi. Raised pressure to try get anchors on the anchor sub of the chemical cutter to release by equalizing pressure. Worked cutter up hole past each collar from 2100' up to 930' and tools locked up here. 05:00 - 08:00 3.00 WELLSF CIRC WRKOVR Continued to circulate hole clean with tools stuck. 13.6 ppg mud in, 13.3 ppg returns. Pre-job planning on how to handel the chemical cutter on surface. Call out Haliburton for assistance with wireline. Prep to fish Schlumberger tools. 08:00 - 11 :30 3.50 WELLSF PULD WRKOVR Monitor well and prepare to pull out of robe socket for clean fish on wireline. Begin pulling, noticed that wire moved only one foot. Have roustabout thaw packoff assym for e-line. Pull e-line tools to surface battle xlo below TIW valve with Schlumberger centrilizers. Pull Schlumberger through X/O and rig dwn e-line. 11 :30 - 13:00 1.50 WELLSF PULD WRKOVR Pick up on production string. 45,000# up weight. Prep to pull production pipe to surface, wrapping up control line into Haliburton spooling device. Mud wt in 13.6# and 13.6 out. 13:00 - 18:00 5.00 WELLSF PULD WRKOVR Pump second dry job. Up wtA5K POOH wltubing spooling up control line for SSSV. LD SSSV and rigged down the spooling unit. 18:00 - 00:00 6.00 WELLSF PULD WRKOVR Continue to POOH laying down 2-7/8" tubing and 6 GLM's. 12/8/2003 00:00 - 01 :30 1.50 WELLSF PULD WRKOVR Finished POH laying down 2-7/8" tubing and 6 GLM's. Visually Printed: 1/6/2004 3:06: 11 PM ConocoPhillips Alaska Page 3 of 6 Operations Summary Report Legal Well Name: 3N-07 Common Well Name: 3N-07 Spud Date: 3/1/1986 Event Name: WORKOVER/RECOMP Start: 12/3/2003 End: Contractor Name: N3Scompanyman@connocophi Rig Release: 12/16/2003 Group: Rig Name: Nabors 3S Rig Number: Date From - To Hours Code Sub Phase Description of Operations Code 12/812003 00:00 - 01 :30 1.50 WELLSF PULD WRKOVR inspected chemical cut area for swollen or damaged 17' tubing stub. No damage, very clean cut. GLM's # 2 & 5 have broken kickover tools inside. 01 :30 - 04:00 2.50 FISH PULD DECOMP Clear rig floor of all 6 GLM. Change die's in both set of slips and tongs for running 3-1/2" P11 0 for workstring. 04:00 - 06:30 2.50 FISH PULD WRKOVR PJSM. PU Bottom Hole Assembly for fishing PBR. 06:30 - 14:45 8.25 FISH PULD WRKOVR PU 3-1/2" P110 tubing after BHA and RIH. 14:45 - 16:15 1.50 FISH JAR WRKOVR Begin jarring at 10K over string wt, work our weight to max in 10K increments. Unable to break free. Continue jarring. 78 jar licks at this time. Hole conditions are good. Moved fish 14'. 16: 15 - 16:45 0.50 RIGMNT RGRP WRKOVR Repair glycol leak on draw works. Drillers side. 16:45 - 20:00 3.25 FISH JAR WRKOVR Continue jarring operations. 20:00 - 22:00 2.00 FISH CIRC WRKOVR RU Head Pin and hoses. Est circ w/19 SPM (1/3 BPM) =950 psi. Move pipe up, press dropped to 800 psi. Worked pipe up and down and jarred at 90K over string wt. Plugged off, could not get circulation, pressuring up with pipe up or down. Moved fish 18' at this point. 22:00 - 22:15 0.25 FISH RURD WRKOVR Broke off hoses and head pin to keep from freezing up 22:15 - 00:00 1.75 FISH JAR WRKOVR Continued jarring on fish at 90k over string wt. making approximately 1/2" per stroke. 12/9/2003 00:00 - 00:15 0.25 FISH JAR WRKOVR Jarring on fish w/90K over string weight fish came free. Up wt = 90K dwn wt = 64K. 4K to 5K increase from pryor to engauging fish. Worked pipe up and down free would tag up back at last position before breaking free at 7003 00:15-01:00 0.75 FISH RURD WRKOVR Pulled 1jt of work string, layed down and picked up head pin. 01 :00 - 04:45 3.75 FISH CIRC WRKOVR Started pumping, established circ. immediately with 1.5 BPM @ 900 psi. Increase rate to 2.0 BPM after pumpiing 100 bbls. with 800 psi. Continue to circulate 13.6 ppg in getting 13.8 ppg back. Pumped 295 bbls before well cleaned up to 13.6 in 13.6 out. 04:45 - 06:00 1.25 WELCTL OBSV WRKOVR Shut down monitor well for flow. Inspect derrick for problems from jarring. Pump dry job. ND hose and head pin. Blow lines down. 06:00 - 11 :45 5.75 FISH PULD WRKOVR POOH with workstring and fish watching for drag and swabbing. 11 :45 - 15:00 3.25 FISH OTHR WRKOVR OOh. Break down jars, release Bowen overshot from 2 7/8" production pipe. Inspect fish. 11.95' of joint # 226. All of joint # 227. 8.4' of joint # 228. This leaves aprox 22' of pipe left on top of GLM # 7. The GLM is 8.3'. Below the GLM is one full joint and one pup totaling 35.23'. From top of fieh to top of PKR = 65.53'. Ordered out 70' of washover pipe 4.75" LD. 15:00 - 18:00 3.00 FISH OTHR WRKOVR Pick up Kelly and prep for power swivel. Washover pipe left Prudhoe @ 3PM. 18:00 - 00:00 6.00 FISH PULD WRKOVR Continued to Pick up the Kelly. Unloaded Wash Pipe Assy and tallied the same. Well is stabile and remained dead. 12/1 0/2003 00:00 - 02:00 2.00 FISH PULD WRKOVR Finished picking up and making up Kelly. Tested Kelly valves. Pick up & Make up Baker Wash-over Assembly 02:00 - 04:00 2.00 FISH TRIP WRKOVR Trip in the hole while making up Washover BHA. 04:00 - 06:00 2.00 FISH TRIP WRKOVR Continued tripping in the hole. Pump dry job. 06:00 - 11 :00 5.00 FISH TRIP WRKOVR Continue tripping in hole. Pump dry job. 11:00 -15:30 4.50 FISH CIRC WRKOVR Break circulation 13.6 in --13.7 heavy returnes after 30 BBL pumped. At 100 BBL 14 PPG for returns. Free wt = 60k dwn, 85K up. Pick up kelly. 15:30 - 17:30 2.00 FISH WASH WRKOVR Tag top of fish @ 7,052. Spin table and allow reactive torque to relax. Able to continue past top of fish to top of mandrel @ 7,074'. 17:30 - 18:15 0.75 FISH WASH WRKOVR Pressure test Kelly and floor to 1,500#. Free spin = 770 ft Ibs. 74K free wt while rotating. Begin washing over at the 7074'. Printed: 1/6/2004 3:06:11 PM ConocoPhillips Alaska Page 4 of 6 Operations Summary Report Legal Well Name: 3N-07 Common Well Name: 3N-07 Spud Date: 3/1/1986 Event Name: WORKOVERIRECOMP Start: 12/3/2003 End: Contractor Name: N3Scompanyman@connocophi Rig Release: 12/16/2003 Group: Rig Name: Nabors 3S Rig Number: Date From - To Hours Code Sub Phase Description of Operations Code 12/10/2003 18:15 -19:15 1.00 FISH WASH WRKOVR Burned over GLM, pump rate 3 BPM, 800 psi, Torque between 1900# and 2800# worked down to 7081' and had to add another joint of tbg. 19: 15 - 20: 15 1.00 FISH WASH WRKOVR Set back the Kelly and added joint of tbg. Resumed burning over GLM pump rate 3 BPM, 950 psi, torque between 1900# and 2500# cleared GLM @ 7083' worked on down with no resitance to 7113'. stop to add another joint of tbg. 20:15 - 20:45 0.50 FISH WASH WRKOVR Added a 17' tbg joint and washed on down to 7130' with no resitance. pump rate 3 BPM, 950 psi, torque between 1900# and 2500#. stop to add another joint of tbg. 20:45 - 21 :30 0.75 FISH WASH WRKOVR Added a 17' tbg joint and washed on down to 7140' took weight at this point. Rotated for app 10 mins then shut down rotary and began a surface to surface circulation. pump rate 3 BPM, 950 psi. 21 :30 - 00:00 2.50 FISH CIRC WRKOVR Circulated surface to surface to clean hole @ 3 BPM, 1000 psi. Prepared to trip out. Nothing really of note in returns other than metal shavings. 12/11/2003 00:00 - 06:30 6.50 FISH TRIP WRKOVR Trip out with washover assembly 06:30 - 07:30 1.00 FISH PULD WRKOVR DOH with washover assym. Wash-over shoe in good condition. Water courses clean, (no metal gouges), LD. has min wear. Bottom of wash-over shoe shows proof of tagging top of packer, (very little marks), no buttons missing. Prepare to RIH with fishing string. 07:30 - 08:30 1.00 FISH PULD WRKOVR Prepare to Rih with original fishing string. Bowen overshot, jars, bumper sub, six DC, Acc. Monitor displacement volumes. 08:30 - 12:30 4.00 FISH TRIP WRKOVR Rih with fishing string. Displacement normal. 12:30 - 13:30 1.00 FISH FISH WRKOVR Tag top of fish. Watch Bowen overshot guide fish into place and swallow 5'. PUH. Witnessed 15K overpull while seals were extracted from PBR. Begin to circulate bottoms up. Pump dry job to POOH. 13:30 - 20:30 7.00 FISH PULL WRKOVR Trip out. Bring Fish to surface. What was left of Jt # 228 above the GLM was pitted badly with numerous holes in the joint. Jt #229 directly below GLM was corkscrewed badly but had little corrosion. The 6' pup beneath Jt #229 was also corkscrewed badly. The seal assembly looked good with all seals in tact. 20:30 - 22:30 2.00 FISH PULD WRKOVR Lay down Fish and Fishing assembly. 22:30 - 00:00 1.50 WELLSF PULD WRKOVR Make up clean-out run assembly 12/12/2003 00:00 - 01:00 1.00 WELLSF PULD WRKOVR Finished making up clean-out BHA 01 :00 - 05:00 4.00 WELLSF TRIP WRKOVR Tripped in the hole with clean-out assembly 05:00 - 07:00 2.00 WELLSF CIRC WRKOVR Circulate bottoms up X 2. Prepare to POOH. 07:00 - 07:15 0.25 WELCTL BOPE WRKOVR State represenitive (Chuck) waived annual BOP test since our next step is the completion. 07:15 - 08:30 1.25 WELLSF CIRC WRKOVR Finished circ. Prepare to POOH laying down P-11 0 pipe in singles. 08:30 - 17:30 9.00 WELLSF TRIP WRKOVR POOH. Monitor fluid top. on surface. 17:30 - 22:30 5.00 WELLSF PULD WRKOVR Break dwn Kelly. Prep to pull drill collars out of hole, along with Baker scrapper tools. 22:30 - 23:30 1.00 CMPL TN PULD WRKOVR Prepare floor for completion run. 23:30 - 00:00 0.50 CMPL TN SFTY WRKOVR Held pre-job meeting on rig floor prior to start tripping completion. 12/13/2003 00:00 - 07:30 7.50 CMPL TN TRIP WRKOVR Run new completion 2-7/8" EUE 8rd Mod L-80 07:30 - 13:45 6.25 WAlTON WOW WRKOVR Field wide weather conditions went to phase 3. Set pipe into slips, add standing valve and monitor well until weather conditions improve. No!! Work to be performed during this time. 13:45 - 14:00 0.25 CMPL TN TRIP WRKOVR Continue to run new completion after phase three conditions were lifted on the main roads. Currently phase 2 conditions on main roads with phase three conditions on pads and access roads. 14:00 - 18:30 4.50 CMPL TN TRIP WRKOVR Finished tripping pipe in the hole tied head pin onto Jt #222 and prepped to pump. Printed: 1/6/2004 3:06:11 PM ConocoPhillips Alaska Page 5 of 6 Operations Summary Report Legal Well Name: 3N-07 Common Well Name: 3N-07 Spud Date: 3/1/1986 Event Name: WORKOVER/RECOMP Start: 12/3/2003 End: Contractor Name: N3Scompanyman @connocophi Rig Release: 12/16/2003 Group: Rig Name: Nabors 3S Rig Number: Date From - To Hours Code Sub Phase Description of Operations Code 12/1312003 18:30 - 19:15 0.75 CMPL TN CIRC WRKOVR Kicked on the pump @ 1/3 BPM/550 psi. Slowly lowered pipe in the hole tagged up @ 7149'. Saw no indication of pressure change. Raised pump rate to 1 BPMnOO psi. Slowly picked up pipe and at 7136' saw pump pressure drop indicating pulled out of sealbore. Shut pump off and re-tagged at 7149' marked pipe at neutral point. Pulled pipe back up to 7134' ( 2' above PBR and prepared to circulate in the corrosion inhibitied mud. 19:15 - 20:00 0.75 CMPL TN CIRC WRKOVR Lined up to pump corrosion inhibited mud. Circulated 10 bbls of 2% corrosion inhibited 13.6# mud down placing 9 bbls behind the tbg (up to 6836') and leaving 1 bbl in the tubing. 20:00 - 21 :00 1.00 CMPL TN PCKR WRKOVR Repostioned tubing seal assembly stinger 2' off of full insertion into PBR (nose @ 7147' Nabors 3s RKB). Dropped ball & rod ( note fishing neck on rod 1-3/8", length 7.16'). Allow 45 mins for rod to fall. 21:00-21:15 0.25 CMPL TN PCKR WRKOVR Brought pump on and pressured up tubing to 2500 psi and set packer. Held for 10 minutes to allow elements to conform. Beld tubing pressure to 0 psi. slacked off on the pipe and then pulled back to neutral. Brought pump back on and pressured tubing to 1500 psi. Pulled up on pipe to shear out of PBR. Sheared at 70k (24k over), bled tubing to 0 psi. Pulled all the way out of PBR then stroked back in. Prepare to space out. 21:15-00:00 2.75 CMPL TN SOHO WRKOVR Spaced out with 4 pups total of 27.82'. Picked up tubing hanger and Drained the BOP stack. Landed the hanger and RILDS. Prepare for pressure testing. 12/14/2003 00:00 - 00:30 0.50 CMPL TN DEaT WRKOVR Pressure tested the tubing to 2500 psi and charted test for 15 minutes. held good. Left IA valve open for test and Monitored the IA during the test, no returns from IA. Bled the tubing back down to 1500 psi. 00:30 - 01 :00 0.50 CMPL TN DEaT WRKOVR Pressure tested the IA to 2500 psi and charted test for 15 minutes. held good. 01:00 - 01:45 0.75 CMPL TN DEaT WRKOVR Had some problems with the pump manifold and unable to bled down the IA in current configuration. Bled both the tubing and IA down to 0 psi. Re-rigged the piping. Pressured up on the IA to 2250 psi and sheared DCK in lower GLM #5 at 6973'. established circulation and SID the pump. 01 :45 - 04:30 2.75 CMPL TN NUNO WRKOVR Left landing joint in hanger and washed out the stack. Moved tree over into the cellar. Pulled landing joint and prepared to install BPV and ND BOP 04:30 - 05:30 1.00 CMPL TN NUND WRKOVR Installed BPV in the and begin ND the BOP stack. 05:30 - 13:30 8.00 WAlTON WOW WRKOVR Stopped work due to Phase 3 weather. 13:30 - 00:00 10.50 CMPL TN NUND WRKOVR Phase 1 across the Kuparuk field. Continue with wash up and Nipple Down BOP. 12/15/2003 00:00 - 03:00 3.00 CMPL TN NUND WRKOVR NO BOP's 03:00 - 04:00 1.00 CMPL TN NUND WRKOVR NU Tree 04:00 - 04:15 0.25 CMPL TN SEaT WRKOVR Tested the packoffs to 5000 psi (good test) 04:15 - 04:45 0.50 CMPL TN SEaT WRKOVR Pulled back pressure valve and installed test plug for tree test. 04:45 - 05:45 1.00 CMPL TN SEaT WRKOVR Test tree to 250 psi (low test) and 5000 psi (high test) Good test. Remove test plug for upcoming seawater displacement. 05:45 - 07:30 1.75 CMPL TN RURD WRKOVR Set up equipment for seawater displacement. Rig crew also continuing to prep the rig for move. 07:30 - 08:30 1.00 CMPL TN CIRC WRKOVR Pre-job safety meet for mud swap. Hook up all line to circulate dwn the IA thru the tubing for mud swap. Kuparuk security called phase 3 weather conditions. 08:30 - 13:00 4.50 CMPL TN CIRC WRKOVR Pumped 200 BBLS of sea water, 200 BBLS of corrosion inhibted sea water and 95 BBLS of diesel. All equip on stby for heavy equip convoy. Printed: 1/6/2004 3:06: 11 PM ConocoPhillips Alaska Page 6 of 6 Operations Summary Report Legal Well Name: 3N-07 Common Well Name: 3N-07 Spud Date: 3/1/1986 Event Name: WORKOVER/RECOMP Start: 12/3/2003 End: Contractor Name: N3Scompanyman @connocophi Rig Release: 12/16/2003 Group: Rig Name: Nabors 3S Rig Number: Date From - To Hours Code Sub Phase Description of Operations Code 12/1512003 08:30 - 13:00 4.50 CMPL TN CIRC WRKOVR Allow diesel to U-tube freeze protecting both the tubing and IA down to 2500'. Well has 2350 psi on it. 13:00 - 00:00 11.00 WAlTON WOW WRKOVR Stby for weather concerns. Phase 3 conditions. 12/16/2003 00:00 - 02:00 2.00 WAlTON WOW WRKOVR Stood-by for Phase 3 weather. 02:00 - 03:00 1.00 WELCTL EaRP WRKOVR Installed BPV and bled tree to 0 psi. 03:00 - 03:30 0.50 CMPL TN OTHR WRKOVR Released Rig @ 03:30 03:30 - 00:00 20.50 MOVE DMOB WRKOVR Preparing rig for rig move over to nabors yard in deadhorse. Printed: 1/6/2004 3:06:11 PM ConocoPhillips Alaska, Inc. KRU 3N-O7 3N-o7 500292153900 PROD 7336 NIPPLE 3/7/1986 7793 12/12/2003 Size To Bottom TVD Wt Grade Thread 16.000 0 115 115 62.50 H-40 9.625 0 3691 3634 36.00 J-55 7.000 0 7707 6669 26.00 J-55 Bottom TVD Wt Grade Thread 7141 6246 6.50 L-80 EUE 8RD AB MOD 7234 6316 6.50 J-55 EUE 8RD AB MOD Zone Status Ft SPF Date T e C-4 7 8 10/18/1986 IPERF A-3 A-2 13 8 10/18/1986 IPERF A-2 0 9 10/18/1986 ¡PERF A-2 2 8 10/18/1986 IPERF A-2 0 9 10/18/1986 IPERF A-2 5 8 10/18/1986 IPERF A-1 22 4 4/25/1986 IPERF Man Type V Mfr VOD Descri tion ID HES 'X' NIPPLE SSSV set 12/12/2003 2.313 BAKER LOCATOR SUB set 12/12/2003 2.441 BAKER 80-40 PBRlSBR set 12/12/2003 2.441 BAKER 'FHL' PACKER set 12/12/2003 2.950 HES 'XN' NIPPLE set 12/12/2003 2.250 BAKER LOCATOR SUB set 12/12/2003 2.441 BAKER SEAL ASSEMBLY set 12/12/2003 2.500 Brown 2.500 Baker 'HB' 2.500 PBR Cameo 'D' Ni Ie NO GO 2.250 (7151-7152, Cameo 2.438 00:2.875) 2.438 PKR (7163-7164, 00:6.156) NIP (7201-7202, 00:2.875) Perf (7349-7356) Perf (7407-7427) Perf (7443-7465) ~ -- --, / 0<0 ... ud Ó = Memory Multi-Finger Caliper Log Results Summary Company: PHILLIPS ALASKA Well: 3N-O7 Log Date: August 2, 2002 Field: Kuparuk Log No. : 4781 State: Alaska ,~ Run No.: 1 API No.: 50-029-21539-00 Pipe1 Desc.: 2.875" 6.5 lb. J-55 Top Log IntvI1.: Surface Pipe1 Use: Tubing Bot. Log IntvI1.: 7,070 Ft. (MD) Inspection Type: Corrosive & Mechanical Damage Inspection - COMMENTS: This log was run to assess the condition of the tubing with respect to corrosive and mechanical damages. The caliper recordings indicate that the interval of 2.875" tubing logged is in good to fair condition with '-' respect to corrosive damage. Penetrations from 21 % and 38% are recorded in 3 joints throughout the interval logged. The damage appears in the form of General Corrosion with deeper Isolated Pitting. The remainder and majority of the tubing logged is in good condition with respect to corrosive damage. No ,~ significant areas of cross-sectional wall loss are recorded. The caliper recordings indicate slight buckling in joints 187 to 203 (5, 790' - 6,327'), moderate buckling in joints 204 to 216 (6,328' - 6,730'), and severe buckling in joints 217 to 227 (6, 731' - 7,070'). Severe buckling restricts the Minimum I.D. to 2.30" in joints 217,220, and 227. - Cross-sectional drawings of the most significant events recorded are included in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. MAXIMUM RECORDED WAll PENETRATIONS: ,- Isolated Pitting ( 38%) Jt. 207 @ 6,426 Ft. (MD) Corrosion (21%) Jt. 159 @ 4,917 Ft. (MD) Isolated Pitting ( 21%) Jt. 227 @ 7,068 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL lOSS: No areas of significant cross-sectional metal loss (> 8%) are recorded throughout the 2.875" tubing interval. MAXIMUM RECORDED ID RESTRICTIONS: -- Severe Buckling Minimum I.D. = 2.30" Jt. 227 @ 7,066 Ft. (MD) Severe Buckling Minimum I.D. = 2.30" Jt. 220 @ 6,839 Ft. (MD) Severe Buckling Minimum I.D. = 2.30" Jt. 217 @ 6,770 Ft. (MD) Moderate Buckling Minimum I.D. = 2.30" Jt. 209 @ 6,484 Ft. (MD) ,.- Moderate Buckling Minimum I.D. = 2.30" Jt. 204 @ 6,331 Ft. (MD) I Field Engineer: D. Cain Analyst: M. Lawrence Witness: M. Chaney I ,~ P'ro[lct¡'\ICl D;'-'g"no.'-'~l<I;'-' (~{Jlrv¡r':)C Y.!r,.c" i D (ì Onr),.' '1 '~[.':.\n. '.-.;'l";1)"('O.I'(.I-/'-/ ./T¡7iJ.(J") ,"I ..... ,(1 :;, L......... ,....L:>,--I.. / f "j. ',/" .}.'~'.,.J1'" d,' ,,'/" I" Phone: (281) or (888) 565-9085 Fax: (28i) 565-1369 c'r-nail; PDS(Uìrncmoryloq.cOIn Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (901) 6SC)'231/1 '"- 3N-O7 Survey Date: 2002 Field: Tool Type: No. 99628 ALASKA Tool 1.69 No. of Fingers: 24 Penetration and Damage Profile to over 10% 20% 85% 85% 0 Damage ( ) GLM 10 3 GLM4 0 isolated general line ring hole GLM 5 pittíng corrosion corrosion corrosion ible GLM6 8 0 0 Bottom of 227 ~ PDS Caliper Statisitical î.~:~. Evaluation Report Well: 3N-07 Survey Date: August 2,2002 Field: Kuparuk Tool: MFC 24 No. 99628 Company: PHILLIPS ALASKA Tool Size: 1.69 inches Country: USA Tubing 1.0.: 2.441 inches Percent Probability of Hole 10 20 50 100 - -- I"--;::::~'::"'F'C::-:C';:"FC .-.. - --i- -f------ Standard Deviation Maximum Probable ---- 0.2 of Penetration* 0.017 -- --- - 0.18 0.077 inches ---- (35.7 % Wall Thickness) -'-.-- -- _.---- ------ -_.-- -- --'------ ------ -- ---~-_.. - 0.16 - .. -- ¡ =-=...-----. .-------- -.-._. ---- .---.---. -- ---- '6 0.14 --------- P t P b b'l'ty f = --- ---- --- ----- - -- ------ ---- - ercen ro a I I 0 ¡ 0.12 "-'-cc;:~~=.~:-f'=--C-¿-=~n: --- , ',"" ...,--:. - ...m ....- æ~-= Recording a Hole' f 0.1 ~--~~;~~.{~)f.Sf~~~~.~~.........._:~......~. ~~~¡===-;}=f~~l!~ less than 10% ) ! ! "'1.... . . --:--- - ., I ¡I' I I I 0.08 =----=---_J_--==--L-_L___..L.L~_-- . ~-----~====~..----~~=~ . I ' : . -L- i \:.. '~~i~:~r=;:r:~~ 0 06 ~~-=:=:-=3-=::Y-=~L¡ l=£t::~~E~-=-:=;¡ ¡T; ._--=--¡- --,--,: . i "':"~Om2~ 0< . .: '. . - . , I I ' ~~~-----~--'--'--f----_..__._'---""-_u,_,,- ...- -----. I , . ----~_.__. .... . , I ;.....-- -: ..~. _: :...~:-. ¡.. ~.:ul__. .__.~ °2,...~._.~[._~._-j--~~::'-t~~.=.-=::.==:_:""_--_-=-::'-F--~=--~J----+ 0.04 ' . ~ ~ .' ". . 0.1 1 10 100 Average Rank mum Well: 3N-07 Survey Date: August 2, 2002 field: Tool: MFC 24 No- 99628 Company: PHilLIPS ALASKA Tool Size: .69 inches Country: USA Tubing 1.0.: 2.441 inches Minimum Measured Diameters 1.69 1.79 1.89 1.99 2.09 1 7 13 19 31 371 43 , 49 55 60 66 71.1 77 83 89 95 101 t 107 J::¡ IS 113 ::¡ Z .5 119 ~ 124 130 136 142 148 154 160 165 177 183 189 194 zoo 205 211 216 Pipe: ins 6.5 Wall thickness: 7 Upset 7ins Field: 2.441 Company: Country: USA Survey Date: : Penetration ¡Metal Projection Damage Profile N°'1 Upset Bd@Up Bod) iLo~: C~:~es B¡~~hes ID Comments (% inches inches inches % inches "0 10 0 0 .02 9 4 0 0 2.39 0 0 .01 6 1 0 0 2.40 0 0 .02 7 4 0 .~ 2.38 :"""""5 m 0 0 .02 8 5 0 2.38 0 0 .01 6 3 () 0 2.39 - ------ : 6 0 0 .02 10 0 .04 2.38 ----------------- .... -- ____m______------- ----------------- - - 7 0 0 .02 7 0 0 2,40 8 0 0 .02 7 0 .04 2.40 9 0 0 .02 8 4 ....._...0 0 2.37 10 0 0 .01 4 0 0 2,37 11 0 O ! .01 6 3 0 0 2.37 12 0 0 .02 9 4 0.. 0 '2.40 13 0 0 ':§~ 4 3 0 0 2,40 14:: 0 0 10 4 0 0 2.40 ----- --...--..-------------- - 15 : 0 0 .01 7 5 0 0 2.38 16 i 0 0 .02 9 3 0 0 2.40 ."'" g + § 3 0 _04 2.37 Lt- m.:' ............. 5 0 0 2.37 .. 0 1 2 0 0 2.38 0 3 0 0 2,40 ....................... : 21 0 0 _02 11 5 0 0 2.40 .............-. I 22 .Qm 0 .03 16 5 0 0 2.35 c;;; ,:2}...... 0 ... ;0 .01.. 4 2 0 --.-..- 0 2.39 24 0 .02 9 2 0 0 2.37 ¡25. 0 0 .01 6 3 g 0 ..... . ..2.39 '27"'" g 0 .02 10 3 0 2.38 0 .03 14 4 0 .04 2.38 pitting. Lt. ..... 28 0 0 .03 12 2 0 0 2.37 .~.~. 0 0 .02 11 5 0 .04 2.34 - ------------------- 0 0 _03 14 3 0 0 2.36 31 0 0 .01 6 2 0 0 2.39 32 0 0 .01 5 2 0 ....03 2.37.. ... 33 0 0 :g~ i3 ' 7 0 0 2.38 ................ 34 0 0 6 0 .04 2.37 35 0 0 .02 9 2 0 0 2.38 36 0 0 .02 9 7 0 0 2.38 ,37 0 0 .02 9 3 0 0 2.36 38 0 0 .03 12 8 0 .04 2.39 It J""r.oik : 39 ;..... 0 0 .02 10 ..... 2 0 0 2.37 0 6 .. 0 .. .04 2.38 0 0 .03 12 3 0 .04 42 ' 0 0 .02 9 4 0 0 2.37 43 0 0 -02 10 g 0.03 2.38 .... 44 0 ...,06 :g~ 15 D3 2,41 ';; . pitting. I 45 0 0 18 7 0 0 2.36 46 0 0 .03 14 5 0 0 2.36 47 0 0 .02 11 6 0 0 2.37 : 48 0 0 .04 18 7 0 0 2.38 '49 0 0 .02 9 8 0 0 2,40 I 50 0 0 .03 12 2 0 OJ 2.36 Pipe Tabulations page 1 = 0.217 ins Field: Company: PHILLIPS ALASKA Country: USA Survey Date: August 2, Comments -- --------------- Tabulations page 3N.07 Upset = 7 ALASKA Country: USA 2, IMetal Projection Damage Profile Noo Upset Bd@Up ILO~: C~:~es B~~hes Comments (% inches inches inches % inches -- --------------- ')( 1 0 0 Æ 12 3 0 03 2.36 0 0 003 12 7 0 03 238 - - -- ----------------- 101 0 0 .01 5 5 0 0 2.36 I 102 0 0 Æ 15 7 0 004 2.34 Lt- 103 0 0 _02 9 2 0 _03 2.37 104 0 ...-. 0 Æ 13 7 0 .03 2.36 105 0 0 Æ 12 6 0 004 2.35 .... 1)6 0 0 .02 10 4 0 .04 2.35 1 )7 0 ... 001 _02 cti 0 .00 2.36 1 )8 0 0 _02 0 0 2.33 ~ 1 )9 0 0 .03 il1 _05 234 I Shallow oittimL Lt 1 10 0 0 _02 0 .... â 2.37 111 0 0 .02 0 2.38 .. 1112 0 0 _02 9 4 0 0 238 1113 0 0 .02 7 2 0 .03 2.38 114 0 0 .03 13 3 0 _03 2.38 0 0 .03 14 5 0 0 238 16- 0 0 .0: 11 2 0 0 2.35 17 1 0 0 .0: ( 2 0 .04 2.37 1 18 0 0 _0: ( 5 0 0 2.37 19 0 0 .0 ( 4 0 0 2.37 1120 0 0 _01 7 3 0 0 2.37 J21 g 0 .01 .~. .~. g.. 6 2.37 1122 0 , .02 2.38 }~~ + g 0 10 2 0 ....... """':61 2.38...... 0 .03 12 2 0 236 124.1 0 0 0 0 0 0 0 N/A IGLM 2 (No 1125 0 0 .02 7 2 0 0 2.37 126 0 0 _02 8 3 0 0 2.37 127 0 0 .02 8 4 0 0 2.35 ..... .J28 0 0 _03 12 4 0 .04 2.37 -130 0 . 0 _02 JO 2 0........ .03 ..........2.37 0 .03 12 2 0 0 2.3' .. 131 0 0 .02 11 4 0 .03 2_3 132 0 0 _02 11 2 0 .04 23 133 0 0 _02 8 2 0 0 2.3' 134 '0 0 _02 11 2 0 0 2.37 135 . 0 0 .02 11 3 0 .04 2.36 136 1 0 0 ..... .02 ....9 3 0 0 2.36 137 0.. .02 å 2 0 0 2.37 138 . 0 0 _03 .3 0 .03 2. .139 0 0 ,02 9 3 0 ,04 2_: 1140 0 0 002 9 4 0 _04 2. 141 0 0 ,02 8 3 0 .04 2- 142 0 0 _01 4 1 0 0 2.37 . ~1~ 0 0 .02 10 ..~ .... .g 0_03. 2.37 0 ..... 0 _02 9 2.38 1145 0 0 -03 12 3 0 _03 2.36 ....... 1146 0 0 .02 9 2 0 0 I 2.37 117 0 0 -02 11 2 0 0 2_37 . Tabulations page 3 Field: ALASKA USA ¡Metal m.. ..... Damage Profile , No. 12--""" Bod) !Loss IC ~ì~~hes ID Comments (% i inches inches inches % "10 ¡nd~es inches 50 i 148 0 0 .02 11 2 0 .04 2.39 149 0 0 .02 10 3 0 .04 2.35 150 0 0 ,02 10 2 0 0 2.37 Hi.... 0 0 .02 11 2 0 .04 2.38 """'0 0 .01 4 0 0 2.37 .----------.----- 6 153 0 0 .02 9 1 0 .04 2.38 154 0 0 .02 8 3 0 0 2.37 ......... 155 0 0 .02 9 3 0 .04 2.38 i 156 0 0 .04 18 6 0 .04 2.31 It 157 0 0 .03 14 2 0 .05 2.34 Ii 158 0 .03 13 3 0 .05 234 Lt. J 0 .05 21 8 g .06 2.34 Lt ..... 160 '0 .... 0 .03 13 4 .05 2.34 Lt,..cc 161 0 0 .02 11 3 0 .04 2.34 . --_._---~------------ 162 0 ......g .02 11 6 0 .04 2.34 . ----- m.___.._.. ...------- 163 0 .03 12 4 0 0 2.35 164 0 0 .02 7 2 0 0 2.35 164.1 0 0 0 0 0 0 0 N/A ::JLM 3 2:00\ i 165 0 0 .02 9 2 0 .03 2.35 co;; 1166 0 0 .03 15 3 0 .03 iji mJ 0 0 .02 11 6 0 .04 2.36 1 0 0 .02 11 0 0 2j5 1 0 0 .02 1] g .03 2.36 . J 0 0 .01 5 3 .03 2.35 1 0 0 .03 12 2 0 0 .... 2.35 .... 172 0 0 .01 6 5 0 0 2.36 1 173 0 0 .01 6 2 0 .03 2.38 I 174 ! 0 0 ... .01 9 4 0 .04 2.36 175 : 0 0 5 2 0 .03 2.37 }~~....g 0 .02 7 3 0 0 2.37 0 .02 9 2 0 .04 2.37 178 0 0 .02 9 3 0 0 2.37 ................... 1179 0 0 .03 14 3 g 0 2.36 i 11,0 0 0 .02 8 2 .04 2.35 H } _0 0 .... ... :g~ 10 5 0 0 2.35 ......... 0 0 6 3 0 .05 2.35 It W3 ... 0 -... 0 .02 10 2 0 0 2.36 184 0 0 .02 8 2 0 0 2.33 185 I 0 0 .02 10 3 0 0 2.36 186 . 0 0 .02 9 0 , .04 ,. 2.35 .- 187 0 0 .02 9 . .....) 0 0 2.34 <; i~ ht 188 0 0 .03 12 0 .03 2 5 <; ig ~i ..... ..... ...... 189 0 0 .02 8 3 g .05 2 3 <: ¡~ Lt 1190 0 0.. .01.. 7 0 2. .5 'i~ ht .1'10,1 0 0 0 0 0 0 N.A ( vi 4 ( ¡tch @ 1 :00\ 1'!1 0 0 .01 6 5 0 .04 2.34 "i2 ht 11 12 0 0 ,03... ,1:4 2 0 .04 2.36 S ¡~ ht Shallow Ditting. 11 )3 0 0 c.. 6 5 0 .04 2.34 <; ¡~ ht .194 1 0 g .02 8 2 0 0 2.36 "if ht .... i I 195 1 0 .02 10 5 0 0 2,36 1 "if ht page Well: 3N-07 Field: PHILLIPS ALASKA penetration USA metal loss Survey Date: August 2, Damage Profile Comments (% Damage classification scheme I not exceed 1 * of circumference. 20% of circumference. of circumference. Pipe 5 fJ) ro N ~ ~ O,~ ~ 000 a " N N',," N ~ <f!- ro M II '" .S 11! bJj to 0.. if> if> 0 U t: 0 ~ W t: 11! 0- M N 0 Q.. :::J II I 0 I N'i' tiN i " ;::j ~ 0 OJ b1) IT! CL II "# "- 0 ~ Z M Qj ;$ 1 ¡ ) } } ~ I } f j ì } _I ì f J J } PDS REPORT JOINT TALLY SHEET Pipe: 2.875 ins 6.5 ppf J-55 Well: 3N-07 Wall thickness: Body = 0.217 ins Upset = 0.217 ins Reid: Kuparuk Nominal 10: 2.441 ins Company: PHILLIPS ALASKA Country: USA Survey Date: August 2, 2002 ,---------------- -----,--------r-----------,----- ---------------------- ------------- -------------------- -------------~----------------------- ----------------- ------------------- -------- ------------- Joint Depth Length Modal Mean Nominal Nominal Type Joint Depth Length Modal Mean Nominal Nominal Type No. 10 10 10 00 No. 10 10 10 00 feet feet inches inches inches inches feet feet inches inches inches inches =--1----- =---1--- ------------ f------- f-------------- ------ ---------- j---------=-=-- ------ --- 1 17.53 31.33 2.439 2.440 2.441 2.875 36 1098.58 30.83 2.439 2.438 2.441 2.875 f------- f----------'--=-- ---------f------- ---'-=-- ------ ------ ------------------- ----------r------------- --------- --------------- --------------------------------- -------- --------------- 2 48.86 31.05 2.448 2.447 2.441 2.875 37 1129.41 29.69 2.440 2.437 2.441 2.875 --- -------- -----1---- - - ------------ f---------- --------- ---------- ---------- ---------- ------ ----------- 3 79.91 31.12 2.448 2.446 2.441 2.875 38 1159.10 31.53 2.468 2.468 2.441 2.875 ------- c----------------- ---------- I--------'-\--------'--I---_---':~ ------------- -------------------- ----------f-------------------- --------'-- ------------=-- ------------=--- --------- ------b------ 4 111.03 31.3 7 2.444 2.439 2.441 2.875 39 1190.63 30.89 2.440 2.436 2.441 2.875 !------I-----------'-=-- - '--1---- ------------ ------ ------------------ -------"- ---------------"- ------------------------- --------- ------------------- 5 142.40 31.13 2.439 2.440 2.441 2.875 40 1221.52 30.69 2.441 2.438 2.441 2.875 J-~-==J i3~_~L j 1.!?Z ~~__~.4~1- -- 2-4~J-- _2.441= 2&Z:5~_~~-~~~~-~-~:~=-=<!I~::=~)5_~~J 1 j 1.9]-= -=-i~1-4~::-:~2.119_---- 2.41L ~8~.L --------- ) J--f-- 20~~~ 30.40 2.448 2.449 2.441 2.875______---- 42__-r-1283:~.1.. }0.7J___2.4_19_--.biJ.L 2.441 2.875______-- 8 235.45 31.41 2.454 2.456 2.441 2.875 43 1313.96 29.22 2.446 2.445 2.441 2.875 f------- 1------------- -------------- -- - ,-~ ------- -------------------- -----------t---------_c-'-- ------_C:- ------------- ----------------'-- ----------- ------- ---------- 9 266.86 30.08 2.447 2.446 2.441 2.875______- 44134~:!!L 31.~JL ___2.4_~2... __2.460 2.14L 2.875 10 296.94 31.46 2.446 2.446 2.441 2.875 45 13 74.38 30.67 2.426 2.425 2.441 2.875 1------- 1----------- ----- ------- ---"--'--'-- --------"-'-- ----------- ----------------- --------- -------------- ------- ---------- ----------- ----~-'-- -------- -------- 11.12~.4Q... 30.03 2.43Q- 2.429 2.441 2.875 ------------- --1Þ___L405.05 - 30.~JL 2.432 2.43~ 2.441 2.875 ----- 12 358.43 31.06 2.456 2.458 2.441 2.875 47 1435.93 31.38 2.454 2.455 2.441 2.875 1---- 1-----------"-"-- ----------=-- ----- ------ c.:-- ---------- --------------------- -------- ---'-- ----- ------------------- -------- ----- ---------- r----11- f--- 38~d2.....19.7~__2.441__- 2.446 2.441 2.875 ----- 48 1467.Jl..J0.~___b4~__2.~_~ 2.441 2.8~.L___- 14 419.27 30.84 2.443 2.444 2.441 2.875 49 1498.00 31.47 2.453 2.453 2.441 2.875 ------ ------ --------- ------ ------------ ----------------------- ----- ------ ------ ---------~ ------------""-- ------- ---------------------- 15 45QJl 29.35 2.434 2.43~- _2.41L__~-=-81.L_____----- -Í.Q___J529.47 30.70 2.443 2.1iCL~44L- 2.8~.L____--- 16- 479..:.1~ 30.66 2.461 2.461 2.441 2.875______--- 51 156QJL- 29.6~- ___2,41Þ- ___ld1~- 2.441 2.875 ------- 17 510.12 30.86 2.427 2.425 2.441 2.875______- -Í.~ 1589.79 30.4Q___2.4.19- __2.41~ 2.441 2.875 ----- .---1§_____540.98 - 111.1.._- 2.45JL 2.456 2.441 _2.87.L ----- 53 1620.19 30.90 2.436 2.434 2.441 2.875 19 572J_£.. 30.99 2.446 2.411- _2.44_L__2.~l.L___------- 54 1651.09 31.13 - 2.44~___2.41L 2.441 2.875__- 20 603_21.. 31.17 2.440 2.440 2.441 2.875 ------- 55 1682.22 31.71 2.450 2.447 2.441 2.875 ~-- -- 634.§!L 31.QLI---_.7.4.t?z.-1- 2.457 2.441 b-- 2.ß7_L ------------- _~6 _-f--1J13.~.L 31.0~- _~.43~ --- 2.4~L+_2.441 2.8?i.... ------ 22 665.90 30.73 2.426 2.425 2.441 2.875 -- 57 , 1744.99 29.71 2.437 2.436 2.441 2.875 _)3 __696&1.. 31.76 - 2.453_-1--- 2.452 2.441 2.875_____- ..2!..:lr--1774.70 11.62 - 2.3J)- _1.~liJ 2.313 2.875 sv 24 728.39 30.66 2.441 2.438 2.441 2.875 58 1786.32 29.61 2.436 2.435 2.441 2.875 25 - 759.05 31.04 ~.433 - ~.433 2.441 2.8~.L,-___--- ~--I--J 815.93 31.36 2.459 2.455 2.441 2.875 . 26 790.09 30.35 2.452 2.451 2.441 2.875 60 1847.29 30.50 2.444 2.441 2.441 2.875 . 27 82Q.d£ 31.28 2.440 2.438 2.441 2.875______--- 61 1877.79 31.46. 2.451 2.450 - 2.441 2.875 i ~ 851.72 28.76 i 2.441 2.438 2.441 I 2.875 62 I 1909.25 31.57 i 2.442 2.441 2.441: 2.875 ! 29 i 880.48 30.99--¡- 2.422 I 2.423 I 2.441 2.875 ----- 63 i 1940.82 I 30.99 i~41 2.441 t 2.441 : 2.875 I . 30 I 911.47 30.88 ¡ 2.427! 2.424 I 2.441 I 2.875 , I 64 . 1971.81 I 29.42 ( 2.443 I 2.439 I 2.441 ¡ 2.875 I 31 ! 942.35 31.09 i 2.445-L 2.445 I 2.441 I 2.875 ,-----=:J i 65 : 2001.23 131.36 i 2.436 L 2.435 I 2.441 ¡ 2.875 ! ! 32 . 973.44 31.92: 2.449 I 2.445: 2.441 I 2.875 I ~ ! 66 ! 2032.59 I 30.17 I 2.432 I 2.431! 2.441 I 2.875 I I 33 ! 1005.36 31.59 2.456! 2.456. 2.441 i 2.875 i ! (67 2062.76 I 31.11. 2.441, 2MOT2.441 2.875 i - 34 i 1036.95 30.79. 2.448: 2.446! 2.441 i 2.875! -----~ i 68 2093.87! 30.78 I. 2.434! 2.436! 2.441 ! 2.875 L 35 1067.74 ¡ 30.84 2.441! 2.437 2.441! 2.875! ' I 69 2124.65: 31.49! 2.443' 2.441 i 2.441 2.875: joint Tally page 1 ¡ ~ þ ¡ ¡ ¡ i I.} Þ I ¥ f ! PDS REPORT JOINT TALLY SHEET Pipe: 2.875 ins 6.5 ppf J-55 Well: 3N-07 Wall thickness: Body = 0.217 ins Upset = 0.217 ins Field: Kuparuk Nominal 10: 2.441 ins Company: PHILLIPS ALASKA Country: USA Survey Date: August 2, 2002 ------ ----- --------- ---- -------- ------- ------------ ---------------- ---------------- -------- ----------------- ------------- ------------------- -----------..------- ---------- Joint Depth length Modal Mean Nominal Nominal Type Joint Depth Length Modal Mean Nominal Nominal Type No. 10 10 10 00 No. 10 10 10 00 feet feet inches inches inches -- inche~ ---------- -------- ---~~ feet ___!!:!~-h~~- jnches inc~~L _jnc!!~s_- 70 2 1 5 6. 14 31 .31 2.45 1 2.449_..1-141 _..1&7... 5 ---------_____!9_':L__J_li~~1..1.. _11~1 ____f:..4:!? -_1.. 44 3__..1..~41L____~&Z~- ------------- 71 2187.45 30.96 2.436 2.436 2.441_l.8Z_L______--- JO~-- ---~~_Q~Q5 29.59 ).413- 2.4._13 _2.11L 2~?.Z..L ---- 71.1 2218.41 6.63 __N/A N A .1.41..1 2.875 Im____- 106 ..l~79þ4 - 30.9...9. 2.433 2.432 __..1..~4jl..__....b~7~_____--------- 72_- 2225.04_1117 __~~'Hl _..2.440 ____1:.41) _____2.8l..~____--------- ..lQ?.._---_J;tl..Q~.§3 30.20 --_....1..ð.4J__).441- __1_:.41L_____~~~1~_____---- 73 2256.41 31.13 2.432 2.433 2.441 2.875 108 3340.83 29.99 2.438 2.434 2.441 2.875 74__- 2287:54_]1.1~_- --_:?.4~~ 2.431 -=~~~iL=_l:.?.75 -=-==~=- ..lQ2~- ~-_J..EQ.82 31.20_2A..1~L 2.413=:1..J.11 ~---~ 2:..~J5- -==== .~ 75 2318.67 30.83 _.1.411 2.42Z 2.441 2.875 ------ 110 _1401:..92 29.91 2.432 2.431 2.4....41- _.-b!E5 - 7 6 -~ 4 9~~ 0 -- 3 1 . U_____2. 4 2 Q_7. 4 ~Q __1:.41L_____~-,-~lL______--------- IlL __~4 3 !~~ 3 30.4 3 __ldl~b:! 3 4 __.7_ð._1L____~~~1.L ---------- 77 2380.63 31.14 __1-.:..43Q _7.422 _2.11L 2.875 ----------- 112~462.36 30.07 __b441_2.438 2.441 2.875 78 2411.77 31.31 ___7...:.4_4_Q 2.437 2.441 __.1.8~L --______l!I- ____;t497-.:..43 _30.1& - 2.445 -- 2.441___.1-.:..441- ---~_&?L ------- 79 2443.08 28.57 ___2..447 2.443 ......1:.44..1 2.875 ---______111- -- 3522.59 30.63 2.432 2.430 2.44 L -_..b?J.2....- -------- 80 - 2471.§5 31.33 -_J.4:~Q 2.426_- 2.4:1) _2.87}_____-- 115 }553...:.~.L 30.23 2.437 2.436 -...1.::15..1..- __1:..?12- ------------- 81 2502.98 31.18 2.440 2.436 2.441 2.875 ------ 116 3583.45 31.20 2.440 2.434 2.441 __....1.8Z~- 82 2534.16 31.40..b_44.~_2.41::1- 2.441 -~Z.5 ---------- _1J_Z__~614.:65 30.33 2.443 _).437 ___2.44L___1..:.875 ------- 83 2565.56 31.19 2.431 2.428 2.441 2.875 118 3644.98 30.98 2.425 2.423 2.441 2.875 --------- ---- ------ 84 2596.75 30.11 2.434 2.432 2.441 2.875 ----- 119 3675.96 31.69 2.423 2.424 2.44.L____..1&Z~-------- 85 2626.86 31.57 2.434 2.430 2.441 2.875 120 3707.65 30.65 2.428 2.426 2.441 2.875 -- ------- --- ------ ---------- 86 2658.43 31.63 2.445 2.443 2.441 2.875 121 3738.30 31.48 2.435 2.432 2.441 2.875 ------ 87 2690.06 31:~§- ---_2..4:}~ 2.436 2.441 ___:?.&ZL______----- 122 3769.78 31.24 2.435 2.435 2.441 2.875 ----- 88 2721.42 31.64 2.437 2.438 2.441 2.875 123 3801.02 31.55 2.441 2.440 2.441 2.875 L!!2...... 2753.06 31.47 ).442- 2.440 ~411 __2.875 ----- 124 3832.57 31.57 2.442 2.437 2.441 2.875 ---- I 90 2784.53 29.95 2.417 2.415 2.441 2.875 124.1 3864.14 6.39 NAN A 2.441 2.875 1m ----- 91 2814.48 30.91 2.418 _2.416 2.441 2.875__- 125 3870.53 31.90 2.425 2.423 - 2.441 -- 2.875 I 92 2845.39 31.40 2.437 2.433' 2.441 2.875 126 3902.43 30.44 2.421 2.420 2.441 2.875 93 2876.79 31.27 I 2.442 2.439 2.441 2.875 127 3932.87 30.31 j 2.424 2.419 2.441 L..b875 --~ I I 94 : 2908.06 30.82 I 2.450 2.445 2.441 2.875 128 3963.18 30.9712.431 2.429 2.441 I 2.875 ..~ i 95 I 2938.88 1....lU3 i 2.450 2.448 2.441 2.875 ~ 129 I 3994.15 31.16 I. 2.435 I 2.431 2.441 .. - 2.875 --~ ¡ 96 ! 2970.41 I 30.56 I 2.445 2.442 i 2.441 2.875 130 1 4025.31 31.20 i 2.4~2.426 I 2.441 : 2.875 r , I .. "I I : 97 I 3000.97 ! 31.28, 2.444: 2.442! 2.441 2.875 1131 i 4056.51 I 30.24: 2.427: 2.425 I 2.444- 2.875 98 : 3032.25 1- 31.12 I' 2.431 I 2.429 i 2.441 I 2.875 1-- ~.132 I 4086.75 131.30 ! 2.430: 2.427 f 2.441 ; 2.875 99 3063.37 30.98: 2.426 i 2.422. 2.441 2.875 I ~ 133 . 4118.05 29.83 \ 2.431: 2.428 I 2.441 '¡ 2.875 ~ ,100 I 3094.35 ! 31.39. 2.449 1__2.446: 2.441 I 2.875 I ¡ 134 : 4147.88 127.81 I 2.438! 2.434 I 2.441 i 2.875 f-- : 101 : 3125.74 I 31.36' 2.429 I 2.428: 2.441 I 2.875 I i 135 4175.69 131.69: 2.421 I 2.417 I 2.441 ' 2.875 i 102 3157.10 i 30.79 2.431_1 2.428: 2.411J. 2.875 I 1.136 4207.38 i 30.46: 2.419: 2.416 I 2.441 : 2.875 \ -103 3187.89 I 30.22 2.434 i 2.430 2.441! 2.875 I m7 4237.84 i 30.84. 2.427 I 2.423 ¡ 2.441 2.875 ¡ --- Joint Tally page 2 \ ¡ ~ E ¡ ¡ j ¡ ¡ ] J } ¡ ~ § j ~ t PDS REPORT JOINT TALLY SHEET Pipe: 2.875 ins 6.5 ppf J-55 Well: 3N-07 Wall thickness: Body = 0.217 ins Upset = 0.217 ins Field: Kuparuk Nominal 10: 2.441 ins Company: PHILLIPS ALASKA Countty: USA Survey Date: August 2, 2002 -..--.--- .-.------ --------- ---.--.---- ------.-.--..-- --.---..--.---- -----.----- ------..--..-,.----.-.--.------.--.--.-.-.- -----_._---.----- -------------- ------- -------.---------- Joint Depth Length Modal Mean Nominal Nominal Type Joint Depth Length Modal Mean Nominal Nominal Type No. 10 10 10 00 No. 10 10 10 00 f------- feet feet inches inche~- _i!1ch~~ ..J!lche..s- ----- ------- ___..lee~_- - feet_- _!Ð..~he..s- _J..nch~~ _If!ch~ inches -- --------. 138 4268.68 32.47 2.421 2.416 2.441 2.875 172 5324.21 31.57 2.421 2.423 2.441 2.875 f---- -~ --'------ ----'--'-- ---..-=-=- ---------- ---------.-=--- ----._-------- ------_._---.-- ---.----------,- .--..--.- -----_._._- .-----'.---- -_.--------------_._---- 139 4301.15 30.86 2.429 2.423 2.441 2.875 173 5355.78 30.94 2.437 2.436 2.441 2.875 ----.---- -------- ------- --------_._c.- --'--'-- --'-- ....------ 140 4332.01 30.72 2.420 2.420 2.441 2.875 174 5386.72 30.03 2.423 2.424 2.441 2.875 =-=- --------_c_--,----- -- - - --- --------- ------ -------- ----'-- ---"-'-- --------- .---------- _.__._-------._-------- 141 4362.73 30.66 2.430 2.427 2.441 2.875 175 5416.75 31.59 2.422 2.419 2.441 2.875 -- . --.---=--- --=-- ------=- ----_.--_._-- -----.-------"-. ----------- ----..------- ---.-....--- --------_.------ -.---------.-.- -----------_.- -------"'-- ----'--'--- ._-------- ---.-------- 142 4393.39 30.49 2.427 2.429___2.41L__1.8~.L ---------- 176 5448.34 _lJ.3~-c--_2.1~ 2.420 - 2~11L-.b~2..... -------- \. 143 4423.88 30.58 2.436 2.430 2.441 2.875 177 5479.69 31.91 2.427 2.421 2.441 2.875 , . -- ----- ----- ~_._----- -------- ----- ------------ .----.-.--...- --------.---- --.--.--.--- 1----...-...- _.-----C_=--=- ------_._.- --------. --------------- - 144 4454.46 31.13 2.431 2.428 2.441 2.875 178 5511.6029.59 2.421 2.421 2.441 2.875 :- -------.:c-=--. ._----_...c....::...... .--.------- --.--..--.- ----- -----_C_-I------ ----- ---- -- -------- 145 4485.59 30.82 2.430 2.428 2.441 2.875 179 5541.19 31.30 2.420 2.415 2.441 2.875 ------- ----=--- ------ --------=-1----.--------:- ----------"-. .----.---..-.--- -------------------- ---------- ------'- ---------- ---------.--- ----- .---------'---'----- ---- .-------------.--- 146 4516.4L 30.91 2.421 2.419 2.44.L__2.8Zi...._I--__---- ~-- 5572'~f-~9]1_1-7.424 2.417 2.441 2.875 1----- 147 4547.32 31.12 2.420 2.417 2.441 2.875 181 5602.21 31.65 2.416 2.416 2.441 2.875 ._._- - ------- -----.---- '-----'---------f----------'--'-- -.--.---.- ------_._-- -------.------I-----=--- -----'--=--- ------'--'--- ------ ---------_.- 148 4578.44 29.89 2.436 2.432 2.441 2.{~z.Lf---____--- JJ!7 5633~~_30~_l§-1-- 2.42_~f--- 2.424 2.441 2.875 -------- 149 4608.33 31.18 2.417 2.417 2.441 2.875 183 5664.04 31.93 2.430 2.425 2.441 2.875 --'---.-- ---'--=----=---- :.-'----------'---- -------------=--- ---------------- -.------- ----- -------1-.- -.-"--- ------ -------- 150 4639.51 30.97 2.427 2.425 - 2.44L 2.875 -- 184 5695.97 30.21 2.429- _.2.4!L 2.44..L _.....b875 - -- 151 4670.48 29.59 2.435 2.433 2.441 2.875 185 5726.18 31.78 2.413 2.414 2.441 2.875 ------ -------1----'--1------- --.----- ----------- ---------"----- -----.----=-- -------'"- ------ --------'---1----_.- -------------- 152 4700.07 29.54 2.436 ..2.43~-1--_2A:iL_~..JE_5 ----- f-18§__.?757.96 31.86 2.420 2.418 2.441 2.875____- m___:l-72~.&L...JL~i....I--- 2.441 2.435 2.44L_- 2.812......>--____----- ,..187 5789.~L..JO.3! 2.394 2.398 2.441 2.875 ------- 154 4761.45 29.~LI---_~.431 2.42~f- 2.4_1L_____JJF5 --------- J!HL 5820.J_L3.1:.8?__- 2.40!- 2.405 2.441 2.875 155 4791.38 30.69 2.447 2.444 2.441 2.87.L -------- ~ 5851.96 30.75 2.4~ 2.422 2.441 2.875 156 4822.07 31.92 2.407 2.399 2.44_L. 2~875 -- 190 5882.71 30.54 2.411 2.411 2.441 2.875 157 4853.99 30.19 2.428 2.4_~~~2.4¡L---2.875 ----~~-= l2.Q~l 5913.25 6.97 N/A-- ----N/A----2.441 2.875 -'m--- 158 4884.18 30.03 2.411 2.409 __2.4:1L__2.872......__.__--- 191 5920.22 30.9Z:_1-_2.408 2.40_~ 2.441 _2.875 -------- 159 4914.21 32.50 2.445 2.444 2.441 2.875 -- 192 5951.19 32.77 2.428 2.422 2.441 2.875 160 4946.71 30.38 2.420 2.415 2.44_L 2.875 ----- J2.~- 5983.96 30.98 2.410 2.406 2.441 2.875 1161 4977.09 30.83 2.418 2.415 2.441 2.875 194 6014.94 29.60 2.417 2.414 2.441 2.875 162 5007.92 30.64 2.428 2.427 1- 2.441 2.875 195 6044.54 30.63 2.408 2.406 2.441 2.875 I ' ! 163 I 5038.56 30.95 2.400-2.402 ,--2.441 2.875--- 196 6075.17 31.04 2.418 2.415 2.441 I 2.875 l .~ i 164W069.51 31.25 2.437 2.434 I 2.441 2.875 --- 197 I 6106.21 31.06 2.410 2.408: 2.441 ! 2.875 ~ .. i 164.1 i 5100.76 7.87 I N/A N/A I 2.441 2.875 1m 198 ! 6137.27 130.70 i 2.414 2.419 I 2.441 : 2.875 , 1165 i 5108.63 30.75! 2.428 2.424 i 2.441 2.875 --.J i 199 1 6167.97 31.34 2.406 2.410 2.441! 2.875 i : 166 i 5139.38 i 31.04 I 2.435 2.431 ¡ 2.441 2.875 I 1200 i 6199.31 ! 29.13 2.428 2.4281 2.441 I 2.875 ! 1167 -¡ 5170.42 i 31.41. 2.421, 2.421: 2.441 2.875 i 1201: 6228.44 31.55! 2.405 I 2.403 I 2.441 I 2.875 I ¡ 168 . 5201.83 I 31.09: 2.441 I 2.413. 2.441 e-_2.875 I I i 202 " 6259.99 H-f58! 2.432 I 2.424 i 2.441 . 2.875 1- .169 ! 5232.92 28.87; 2.419! 2.413 2.441 2.875 i i :203. 6291.57 131.78, 2.43õl 2.425 i 2.441 2.875, ,170 5261.79 i 31.49 2.422 I 2.422 2.441 2.875! ---~ '203.1 6323.35 4.60. N/A _I N/A 2.441 2.875 glm 171 ' 5293.28: 30.93 2.417! 2.412 2.441 2.875 i I :204 6327.95 31.86 i 2.424: 2.415! 2.441 2.875 : joint Tally page 3 ! j N I I ~ j j f I 1 I ~ D ~ 1 PDS REPORT JOINT TALLY SHEET Pipe: 2.875 ins 6.5 ppf J-55 Well: 3N-07 Wall thickness: Body = 0.217 ins Upset = 0.217 ins Field: Kuparuk Nominal I 0: 2.441 ins Company: PHILLIPS ALASKA Country: USA Survey Date: August 2, 2002 - ---------- _.- ----------. ------- --_..------ --------- -.-------.---- --.-----.-. --'-.--'..-- ---'.---- --.----.----.--.---- '--.""'--."-'------ .----------- .__._--_.--- -----..----.--.----- Joint Depth Length Modal Mean Nominal Nominal Type Joint Depth Length Modal Mean Nominal Nominal Type No. 10 10 10 00 No. 10 10 10 00 feet feet inches inches inches inches feet feet inches inches inches inches ----- ---- -.---- ----- ---- -_._--- --- ----_._- ---- .----.---- ------- -_._-- 205 6359.81 30.18 2.427 2.428 2.441 2.875 - ---.------ --- ..-----..----- --_._----.- -------..---- -----.--- .-.----.-.----.---.-.------..-... ---------.--...---- -..-'.-.---.------.--.-------.--------.----.-'--- --.-.---------.--------. 206 6389.99 32.12 2.408 2.405 2.441 2.875 -- .--------- ----.-.-.----- -.----- -.------- ..._---.-_. --------- --- 207 6422.11 31.82 2.420 2.413 2.441 2.875 ---._---.- ..------.-.- ..---- ------- .-------------- --.---.------..- ._----.-- -----.--.--- ---.--.---- -----'---.-'---.-.---.-.-..--.'------'-.-..-.------ --.-------.----- ---------.-.---.----.- 208 6453.93 29.81 2.419 2.411 2.441 2.875 ---- -..--- ----.-- ----- -.--------..--.-- ----..--.----- .--.-- -- -------- 209 6483.74 30.93 2.412 2.403 2.441 2.875 ) -------- --------. --- ----.------.-- ---.-.-----..----.---- ------ .------- ----- -------.-.. ------.-- ----------..-.--- -----.----.--- 210 6514.67 31.30 2.426 2.415 2.441 2.875 ---- '---- -------..---- ...----------- ---.----.---.-.------ ------- ----.---.---- ----....-.---- ---..---------.-- .----------- -. ------- ---_._------ ----.---------- 211 6545.97 29.60 2.435 2.431 2.441 2.875 --------- ------..--.--.- .._---- ----.-- -.---.--- -.--.----.---- ------ -------- 212 6575.57 31.46 2.422 2.420 2.441 2.875 ---.--. ------------- -- ----.----- ----- ----.---------...---..--.-- ------ ....------.--.- ---.--.-'" ---"'.-'--..-.--.-- ....-.-'.-------.-- ..-.-----.-...-------....---- --_.'---_..- 213 6607.03 32,02 2.415 2.411 2.441 2.875 .--.------ .-- --- -.-- - ---- --- ---------- 214 6639.05 30.01 2.420 2.414 2.441 2.875 ----------- ----.,.--- ---------- -.-----.--'.------------'-'---------'-.-- ....-----.---.-- ----.-- ___m__..._- ------.-.--- -----..--.-. --------.--.------- 215 6669.06 31.89 2.441 2.409 2.441 2.875 -- ------_._---------- .---. ----- .- -_..- '--.- 216 6700.95 29.67 2.424 2.420 2.441 2.875 ----.---- --'--- -----_.-- -----.--.--'----- .---.- -------.. --.-- -.'-.'-- ----.-- .-.--.-- -----_.- -----'---- 216.1 6730.62 6.51 ~~ NA 2.441 2.875 1m ----- .-.---- --- -----.-- ---.----.--- -_._- --- 217 6737.13 32.92 2.430 2.414 2.441 2.875 -------- ------ .------ ------- .'-----.------- .---'---'---'-'-"- ---.-... ---.---- ----.. -----..--- ------ ..-,---..--.-- _._-------- 218 6770.05 31.23 2.399 2.398 2.441 2.875 - --- ---------- ---- -- ---...-. --.---- 219 6801.28 29.93 2.418 2.413 2.441 2.875 --'---- . ._-------- .--.------.-----.-- ----- ----- ---- --------------- ------- -- ----.----- ---.------.- 220 6831.21 31.31 2.426 2.415 2.441 2.875 --.--.-.--- .--- 221 6862.52 30.92 2.419 2.413 2.441 2.875 --- --- ----. ---- -.------------.--.- --- --_._- --- ----- ------------- --.-.-----. 222 6893.44 31.02 2.429 2.417 2.441 2.875 -------..--- -- .----------.--- 223 6924.46 29.38 2.440 2.422 2.441 2.875 -- 224 6953.84 31.34 2.436 2.429 2.441 2.875 --- -- --.--'--- --- ----- -------- -- 225 6985.18 31.62 2.424 2.409 2.441 2.875 -- 226 7016.80 28.69 2.423 2.414 2.441 2.875 --.---.-- ---- -------"j -- ----. -- -------- --- -- -- ------.------ 1227 7045.4L. NI A I 2.441 2.398 2.441 2.875 I ----- ) Joint Tally page 4 , _0, ,- ',,~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown - Stimulate~ Plugging - Perforate - Pull tubin Alter casin Repair well Other 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development X. 67' RKE 3. Address: Exploratory ---'" 7. Unit or Property: P.O. Box 100360 Stratagrapic ---'" Anchora e, AK 99510-0360 SeNice Kuparuk River Unit 4. Location of well at surface: 8. Well number: 1561' FSL, 304' FEL, Sec 29, T13N, A9E, UM 3N-07 At top of productive inteNal: 9. Permit number/approval number: 1257' FNL, 821' FEL, Sec 29, T13N, A9E, UM 86-28 At effective depth: 10. API number: 1105' FNL, 935' FEL, Sec 29, T13N, A9E, UM 50-029-21539-00 At total depth: 11. Field/Pool: 1015' FNL, 1004' FEL, Sec 29, T13N, A9E, UM Kuparuk River Field / Oil Pool 12. Present well condition summary Total Depth: measured 7793 feet Plugs (measured) None true vertical 6732 feet Effective Deptl measured 7624 feet Junk (measured) DV and JDS lost in rathole true vertical 6606 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 235SxCSil 115' 115' Surface 3654' 9-5/8" 1070 Sx PF E & 3691' 3634' 280 Sx Class G Production 7672' 7" 310 Sx Class G & 7707' 6669' 175 Sx AS I Liner Perforation Depth A R , G I ~J A L measured 7349' -7356', 7407'-7427', 7443'-7465' . I' true vertical 6402'-6407',6445-6460',6471'-6488' Tubing (size, grade, and measured depth) 2-7/8",6.5 Ib/ft, J-55 @ 7201' Packers and SSSV (type and measured depth) .. < " Packer: Baker HB @ 7163'; SSSV: Baker FVL @ 1788' 13. Stimulation or cement squeeze summary Fracture stimulate "A" sands on 4/22/98. Intervals treated (measured) 7407' - 7 427', 7443'-7465' Treatment description including volumes used and final pressure Pum ed 247,189 Ibs of 16/20, 12/18, and 10/14 ceramic ro ant into formation, f was 7234 si. 14. Representitive Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 284 252 291 1337 151 Subsequent to operation 587 373 367 1148 149 15. Attachments MIT form 16. Status of well classification as: Copies of Logs and SuNeys run - Daily Report of Well Operations X Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ TItle: Producfton Engineering Supervisor Date 9 lz,v/'f'1 Form 10-404 R 88 SUBMIT IN DUPLICATE ~ ARCa Alaska, Inc. ~.~.-~ KUPARUK RIVER UNIT ~~ WELL SERVICE REPORT ~~ K1 (3N-O7(W4-6» WELL JOB SCOPE JOB NUMBER 3N-O7 FRAC, FRAC SUPPORT 0414980724.2 DATE DAILY WORK UNIT NUMBER 04/22/98 A SAND REFRAC DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 3 @ Yes 0 No @ Yes 0 No DS-YOKUM BLACK/JORDAN FIELD AFC# CC# DAilY COST ACCUM COST Signed ESTIMATE KD2061 230DS36NL $106,513 $123,886 Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann Initial Outer Ann Final Outer Ann 430 PSI 7230 PSI 390 PSI 500 PSI 550 PSI 550 PSI DAILY SUMMARY A SAND FRAC. PUMPED 247,189 LB OF PROP WITH 237,973 LB IN FORMATION AND 12.9 PPA OF 12/18 AT PERFS. lEFT 9216 LBS PROP IN WELlBORE. ESTIMATE SAND TOP +/-1700'. TIME I LOG ENTRY 07:00 I MIRU OS FRAC FLEET - YOKUM. TGSM. PRIME UP AND PT. 08:29 I PUMP BREAKDOWN AND FLUSH ACCORDING TO PROCEDURE. ISIP 1812 PSI. 10:17 I PUMP DATA FRAC AND FLUSH ACCORDING TO PROCEDURE.ISIP 1899 PSI. 11:45 PUMP FRAC W/50# DELAY Xl GW @ 5-15 BPM. PAD REDUCED TO MIN 95 BBl BASED ON CLOSURE. PUMPED 44 BBL OF 75 BBL DESIGNTO ENDPOINT AT 12.9 PPA. SCREENED OUT WITH 15 BBL OF 44 BBL FLUSH AWA V, 7 BBL DIESEL IN TUBING. 13:30 RD OS FRAC UNIT. ALL TREESAVER CUPS RECOVERED. DEPRESSURE IA TO 500 PSI. PUMPED 247,189 LB PROP WITH 237,973lB IN FORMATION AND 12.9 PPA OF 12/18 AT PERFS. LEFT 9216 LB PROP IN WELlBORE. ESTIMATE TOP OF SAND AT +/- 1700'. 15:30 I RDMO OS. I = I I I I I I I I I I I I I I SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $678.00 APC $2,500.00 $3,100.00 DOWELL $101,013.00 $101,013.00 HALLIBURTON $0.00 $11,115.00 LITTLE RED $3,000.00 $7,980.00 TOTAL FIELD ESTIMATE $106,513.00 $123,886.00 ,- STATE OF ALASKA ( , ' q....) .,. ALASKA OIL AND GAS CONSERVATION COMMI~ION 1J / \ fr /> REPORT OF SUNDRY WELL OPERATIONS /, '. 1. Type of Request: Operation Shutdown - Stimulate X- Plugging - Perforate - Pull tubing Alter casing - Repair well - Pull tubing - Ot her - 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development ...x... AR Exploratory - fe t 3. Address Stratigraphic - 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Service Kuparuk River Unit 4. Location of well at surface 8. Well number 1561' FSL, 304' FEL, Sec. 29, T13N, R9E, UM {? At top of productive interval 1257' FNL, 821' FEL, Sec. 29, T13N, R9E, UM At effective depth 1182' FNL, 878' FEL, Sec. 29, T13N, R9E, UM At total depth 11. Field/Pool 1015' FNL, 1004' FEL, Sec. 29, T13N, R9E, UM Ku aruk River Oil Pool 12. Present well condition summary Total Depth: measured 7793' feet Plugs (measured) None true vertical 6 732' feet Effective depth: measured 7624' feet Junk (measured) None true vertical 6 606' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 80 ' 1 6 " 235 Sx CS II 1 1 5' 1 1 5 ' Surface 3691' 9-5/8" 1070 Sx PF"E" & 3691' 3633' Intermediate 280 Sx Class "G" Production 7707' 7" 310 Sx Class "G" & 7707' 6668' Liner 175 Sx AS I Perforation depth: measured 7349'-7356', 7407'-7427', 7443'-7465' MD true vertical " 6402'-6407', 6445'-6460', 6472'-6489' TVD Tubing (size, grade, and measured depth) 2 7/8", 6.5# J-55 AB mod. tubing with tail @ 7234' Packers and SSSV (type and measured depth) Brown HB kr @ 7163'; Baker FVL SSSV @ 1788' 13. Stimulation or cement squeeze summary"'" 'A' Sand Refracture Stimulation. No kill fluids were used. Actual BHP = 2300 psi. Intervals treated (measured) 7349'-7356', 7407'-7427', 7443'-7465' MD Treatment description including volumes used and final pressure , 75,600# of 20/40 carbo-lite wI 1707 bbls. elled water 4850 si final WHP. 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 5 05 1 38 0 1 1 5 0 1 2 0 Subse uent to 0 eration 8 9 1 3 1 2 0 1 1 68 1 2 2 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run - Daily Report of Well Operations ...x... Oil X Gas Suspended - Service 17. I hereby certify that the foregoing is true and correct to the est of my knowledge. ~ / .r>~ t If ~",f¡~ Title þY ,' ¿J < .~~ ~--~~ t. Date ¿; Cr:;( Ý c( J V 06/15/88 SUBMIT IN DUPLICATE ~ -~- ARCa Alaska, Inc. <> WELL SERVICE REPORT ,~ Subsidiary of Atlantic Richfield Company WELLPBDT FIELD. DISTRICT. STATE DAYS; DATE 3/V-? 7C;Z'{' KI<. I -/0-" CONTRACTOR OPERATION AT REPORT TIME L. R ~ ... 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Type of Request: Abandon - Suspend - Operation Shutdown - Re-enter suspended well - Alter casing - Repair well - Plugging - Time extension - Stimulate.x. Change approved program - Pull tubing - Variance - Perforate - Other- 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development .x. AR Exploratory - 7' KB feet 3. Address Stratigraphic - 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Service - Kuparuk River Unit 4. Location of well at surface 8. Well number 1561' FSl, 304' FEl, Sec. 29, T13N, R9E, UM N - 7 At top of productive interval 1257' FNl, 821' FEl, Sec. 29, T13N, R9E, UM At effective depth 1182' FNl, 878' FEl, Sec.29, T13N, R9E, UM At total depth 11. Field/Pool Kuparuk River Field 1015' FNl, 1004' FEl, Sec. 29, T13N, R9E, UM Ku aruk River Oil Pool 12. Present well condition summary Total Depth: measured 7793' feet Plugs (measured) None true vertical 6732' feet Effective depth: measured 7624' feet Junk (measured) None true vertical 6606' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 8 0 ' 1 6" 235 Sx CS II 1 1 5' 1 1 5' Surface 3691' 9-5/8" 1070 Sx PF"E"& 3691' 3633' Intermediate 280 Sx Class "G" Production 7707' 7" 310 Sx Class "G" 7707' 6668' Liner 175 Sx AS I Perforation depth: measured 7349'-7356' 8 SPF 0 degree phasing, 7407'-7427' 8 SPF 0 degree phasing, 7443'-7465' 4 SPF 90 degree phasing ~ ß ,¡~ true vertical , i 6402'-6407', 6445'-6460', 6472'-6489' Tubing (size, grade, and measured depth -- '¡'1 )-'; 'J , ' , ,J - 2 7/8", 6.5# J-55 AB mod. tubing set at 7234" - ' Packers and SSSV (type and measured depth) , ,"'. v i l'~' 1'::1'" Gommi3SiOí1 Baker HB kr. 7163' Baker FVl SSSV 1788' Ä\as\Œ UII l.( :-:'J'",'",',:;:'n 13. Attachments Description summary of proposal - Detailed operation program .x. B'ÖP sketch - 'A' Sand Refracture Stimulation. No kill fluids will be used. Ex ected BHP = 2500 Sl. 14. Estimated date for commencing operation 15. Status of well classification as: n 1 Oil -2L Gas - Suspended - 16. If proposal was verbally approved Name of approver Date approved Service 17, I hereby certify that the foregoing is true and 1rect to the best of my knowledge, " Si ned /(¡ G' /V ,.,' ,"? ~t . 'Title Sr. 0 erations En r. Date S FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Approval No. 9 Plug integrity - BOP Test - Location clearance - I"'" Mechanical Integrity Test - Subsequent form require 1 0- LJô If Approved Copy Returne~m ORIGINAL SIGNED BY ~ ,8- Approved b the order of the Commission NIE C. SMITH Commissioner Date b -~ .8'7 Form 10-403 Rev 5/03/89 SUBMIT IN TRIPLICATE r¡ l3S31a )t~11S = HSnl:l (~nOl:l \f~lllS ON) ~3)t\f3~8 + MÐ = Al:ll:lnlS 1:13)t\f31:18 I:IH 8 + I:InOl:1 \f~lllS l\fÐ 000 ~/8l OÞ + MÐ = a\fd S188 ÞÞ l.S\fl NO I:InOl:l \f~lllS aN\f ~3)tNI1-SSOI:I~ l.n~ (S188 90£ l.SI:II:1) 1:13>1\f31:18 I:IH 8 + I:InOl:J \f~llIS l\fÐ 000~/81 OÞ + MÐ = ~\fl:l:l-INIW 1:13>1\f31:18 I::IH 8 + ~nOl:l \f~llIS l\fÐ 000~/81 OÞ + MÐ = (~) NMOa>l\f31:18 (~nOl:J \f~llIS ON .1:I3)tNI1-SSOI:I~ ON) 1::13)t\f31:18 I::IH 8 + MÐ = (~) NMOC>I\f31:18 Isd 0099 = 3~nSS31::1d ÐNIl.\f31:1l. a3l.\fWIl.S3 (^Jessa~au II Wd8 9~ O¡ a¡eJ doJp) Wd8 O~ = 3l.\f1:l dWnd ( 3l.11O81:1\f~ WOÞ/O~ = l.N\fddOl:ld O' 9 V - (Sl88) S:H:j3d 01. 3~nlOA v 0 S ~ £ 0 £ 6 S £ 9 V ~ 1'11.01. - - - - - - - - - - - - - - - - - - - - - - - - .~ - v S S ~ v v 0 v v ,~HSnl;j .,', ,..., 9~S~ O~S~ Ov G66£~ S'~'~'.,',,':::. @ ÐddG~ 9£v ~ OL V ~ OS OG££G S'g"S" :;~,;..fi- ~ Ðdd O~ 9££ ~ 06£ ~ 00 ~ OvSVG 6'~:¿.",;< r-i..~~,;'" Ðdd S 99 G ~ 06 G ~ 0 LOS 6 £ ~ V . ~<g.uA _.I...,,~:Z "'" Ðdd 9 9 0 G ~ 0 G G ~ 0 9 6 9 S SO' ~.:-g.: '?;:) Ðd d V 1..,,-,. 9 V ~ ~ 0 9 ~ ~ 09 G £ 9 V ~ . 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'NI~ S as 9 v 0 S 0 S 0 0 S (~) NMOC>I\f31:18 (l88) @ S:Jtj3d (l88) lOA A1.tJIO (l8 8) (SONnOd) (l8 8) S1.IH 3ÐV1.S 3AI1.VlnV\Jno 3V\JnlOA A.ltJIO 1.NVddOtJd 3V\JnlOA N'v'3l0 3ÐVlS . . ~ 3lnO3H~S ÐNldV\Jnd OVtJ:J LO-N£ ll3M . 3 F - 1 4 Kuparuk Fluid Level Report 9 - 1 1 - 8 7 Casing 3 F - a 6 Kuparuk Fluid Level Report 1 2 - 06 - 8 6 Tubing 3 F - 1 4 Kuparuk Fluid Level Report 9 - 1 1 - 8 7 Casing 3 F - a 8 Kuparuk Fluid Level Report 1 0-1 1 - 87 Tubing 3 F - 1 4 Kuparuk Fluid Level Report 9 - 1 6 - 8 7 Casing 3 F - a 9 Kuparuk Fluid Level Report 4 - 1 1 - 8 8 Casing 3 F - 05 Kuparuk Fluid Level Report 4 - a 8 - 8 8 Casing 3 F - 09 Kuparuk Fluid Level Report 4 - a 1 - 8 8 Casing 3 F - a 6 Kuparuk Fluid Level Report 3 - 2 6 - 8 8 Casing 3 F - a 5 Kuparuk Fluid Level Report 1 - 3 a - 8 8 Casing 3 N -1 a Kuparuk Fluid Level Report 1 0 - 1 2 - 8 7 Casing 3 N - 1 a Kuparuk Fluid Level Report 1 0 - 1 5 - 8 7 Casing 3 N -1 1 Kuparuk Fluid Level Report 1 0 - 2 8 - 8 7 Tubing 3 N -1 0 Kuparuk Fluid Level Report 1 0 - 2 8 - 8 7 Tubing . \ 3 N - a 5 Kuparuk Fluid Level Report 1 0 - 2 8 - 8 7 Tubing 3 N - 0 4 Kuparuk Fluid Level Report 10- 2 8 - 8 7 Tubing 3 N -1 3 Kuparuk Fluid Level Report 3 - 1 9 - 8 7 Tubing 3 N -1 1 Kuparuk Fluid Level Report 9 - 1 2 - 87 Tubing 3 N -1 8 Kuparuk Fluid Level Report 9 - 1 0- 9 8 Tubing 3 N -1 7 Kuparuk Fluid Level Report ," 9 -1 0 - 8 7 Tubing ." 3 N - a 7 Kuparuk Fluid Level Report 9 - 1 0 - 8 7 Tubing 3 N -1 5 Kuparuk Fluid Level Report 9 - 1 2 - 8 7 Tubing 3 N - 0 5 Kuparuk Fluid Level Report 9 - a 8 - 8 7 Tubing 3 N - 0 9 Kuparuk Fluid Level Report 9 - 0 1 - 8 7 Tubing 3 N - a 4 Kuparuk Fluid Level Report 9 - 0 1 - 87 Tubing 3 N - 1 4 Kuparuk Fluid Level Report 9 - 0 6 - 8 7 Tubing 3 N - 08 Kuparuk Fluid Level Report 9 - a 6 - 8 7 Tubing 3 N - a 6 Kuparuk Fluid Level Report 9 - 06 - 8 7 Tubing 3 N - 0 2 Kuparuk Fluid Level Report 9 - 0 6 - 8 7 Tubing 3 N -1 a Kuparuk Fluid Level Report 6 - 0 1 - 8 7 3 N - 1 a Kuparuk Fluid Level Report 5 - 3 1 - 8 7 Casing 3 N - 1 0 Kuparuk Fluid Level Report 6 - 03- 8 7 3 N -1 0 Kuparuk Fluid Level Report 6 - 0 6 - 8 7 Casing 3 N -1 0 Kuparuk Fluid Level Report 6 - 0 8 - 8 7 Casing . 3 N -1 a Kuparuk Fluid Level Report 6 - 0 9 - 8 7 Casing 3 N - 1 a Kuparuk Fluid Level Report 6 - 2 5 - 8 7 Casing 3 N - 07 Kuparuk Fluid Level Report 4 - 1 7 - 8 7 Casing 3 N - 01 Kuparuk Fluid Level Report 4 - 1 8 - 8 7 Casing 3 N - 0 4 Kuparuk Fluid Level Report '. 6 - 1 7 - 8 7 Casing 3 N - 0 4 Kuparuk Fluid Level Report 6 - 20- 8 7 Casing 3 N - 0 9 Kuparuk Fluid Level Report 5 - a 7 - 8 7 Casing t?J ... . 3N-10 Kuparuk Fluid level Report 8-24-87 ~¡; ~.?~. c J-t 1 .[;<- . 1 '" ,~. ~, Alaska Oil .') G . C( 3S Con" C. R ece I pt Acknowl edg ed: uu--uu_u------u_----- D ate: u-- --- Arrcrrorag;" tjrnlì7iSS/Qii ~ D&M State of Alaska - Mobil Chevron Unocal SAPC . ARGO Alaska, Inc. ~~ ~". Date: February 17, 1989 Transmittal #: 7429 RETURN TO: I 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. 3 F -11 Sub-Surface Pressure Survey 1 0 - 06 - 8 8 # 7 - 8 8 9 3 H -1 2 Kuparuk Well Pressure Report 8 - 2 9 - 8 8 Amerada , 30-07 Kuparuk Well Pressure Report 1 2 -20 - 8 8 Sand 'A' 3 F -1 a Kuparuk Well Pressure Report 8 - 29- 8 7 Amerada 3 F - a 6 Kuparuk Well Pressure Report 8 - 29 - 8 7 Amerada 3 F - a 2 Kuparuk Well Pressure Report 8 - 29 - 8 9 Amerada 3 F -1 6 Kuparuk Well Pressure Report 8 - 1 7 - 8 7 Sand lA' 3 F - 1 6 Kuparuk Well Pressure Report 8 - 1 7 - 87 Sand 'A' 3 F - 1 1 Kuparuk Well Pressure Report 8 - 29 - 8 7 Amerada 3 F - a 4 Kuparuk Well Pressure Report 6 - 2 6 - 8 7 Sand 'A' 3 F - 05 Kuparuk Well Pressure Report 1 2 -1 2 - 8 8 3 F -1 3 Kuparuk Well Pressure Report 1 2 - 3 1 - 88 3 N -1 a Kuparuk Well Pressure Report 6 - 1 1 - 87 Both Sands 3 N -1 a Kuparuk Well Pressure Report 6 - 1 1 - 8 7 Both Sands 3 N - a 4 Kuparuk Well Pressure Report 9 - 0 1 - 8 7 Sand 'A' 3 N - a 9 Kuapruk Fluid Level Report 5 - 04- 87 Casing 30 -1 4 Kuparuk Fluid Level Report 2 - 1 3 - 8 9 Casing 30-14 Kuparuk Fluid Level Report '. 2 -1 0 - 8 9 Casing 3 M - 1 8 Kuparuk Fluid Level Report 2 - 1 0 - 89 Casing 3 F -1 6 Kuparuk Fluid Level Report 6 - 05- 8 7 Tubing 3 F -1 3 Kuparuk Fluid Level Report 6 - 09- 8 7 Casing 3 F - 1 3 Kuparuk Auid Level Report 6 - 1 8 - 8 7 Casing 3 F -13 Kuparuk Auid Level Report 6 -1 6.87 Casin If( ~ I \1- 1"'" J-\ 3 F - 1 3 Kuparuk Fluid Level Report 6 - 2 1 - 87 Casin ~..-:: I m-~" 3 F - a 8 Kuparuk Fluid Level" Report 5 - 0 8 - 8 7 Casing F ~~ 3 F -1 6 Kuparuk Fluid Level Report 8 - 1 8 - 8 7 01 ~ '- -Ie 1:; - 3 F -1 6 Kuparuk Auid Level Report 8 - 24- 8 7 ~D~ka . 3 F -1 3 Kuparuk Fluid Level Report 6 - 05 - 8 7 CasINg", 011 & Gas Con:. CommisslOn 3 F - 1 6 Kuparuk Fluid Level Report 6 - 2/3 - 8 7 Casing Anchorage 3 F -1 6 Kuparuk Fluid Level Report 8 - 5 - 8 7 Tubing 3 F - 1 6 Kuparuk Fluid Level Report 6 - 5 - 8 7 Casing 3 F - 1 4 Kuparuk Fluid Level Report 9 - 8 - 8 7 Casing - ~1f &ClfŒ lW ~ ¿t:1U~£ l~~ STEVECOWPE DEP.i\.RT~IENT OF N.i\.TUR.t\.L RESOUIICES DIVISION OF OIL AND GAS July 6, 1988 !Iil- --~' J~J88 John Wood, Area Landman ARCO Ala sk a, I nc . /\1(':31<3 Oil & GJS Cons. Commission P.O. Box 100360 Anc!JOrJge Anchorage, Alaska 99510-360 Dear Mr. Wood: In your July 5, 1988 letter you requested extended confidentiality for the data from the Kuparuk River Unit development wells 3N-5, 3N-7, 3N-8 and 3N-8A. These wells are situated south of an unleased tract at Oliktok Point, U. S. Survey No. 4275, with surface reserved for the U. S. Air Force (see attached map). The 3N-7 and 3N-8A wells are scheduled to be released on July 7, and the 3N-5 well is scheduled for release on July 9,1988. The 3N-8 well was released on April 14, 1988. On July 6,1988 you and other ARCO staff members met with division staff to discuss your request. Following your written request, and after careful consideration of the discussion between our staffs, I am denying your request to extend the confidentiality of the 3N-5, 3N-7 and 3N-8A wells. Under AS 3l.05.035(c): "If the conTllissioner of natural resources finds that the required reports and information contain significant information relating to the valuation of unleased land in the same vicinity, the commissioner shall keep the reports and information confidential for a reasonable time after the disposition of all affected unleased lands. \I - Significant reports and information from the ARCa Oliktok Pt. No.1 Well, as well as data from the 3N-4 and 3N-8 wells, are already available to the public. The data from the Oliktok Pt. No.1 Well, situated directly between the unleased tract and the three wells in question, are particularly significant to the valuation of the unleased tract. There are already several wells which have been released to the public which provide a good data base for valuation; therefore, we do not think that the data from these three wells would make a significant difference to an interpretation of the geology in the valuation of the unleased land at Oliktok Point. There are several other wells in this area scheduled to be released within the next year. So that you may evaluate any future requests for confidentiality extensions, we would like to advise you of our current leasing plans. January 1989 is the earliest month that the Oliktok Point tract could be offered for . -- ~- John Wood July 6; 1988 Page 2 lease. The division is considering offering the tract in January 1989 if all manpower, noticing, ownership and other legal requirements can be met. If this timing does not prove possible, September 1989 will present the division's next practical opportunity to offer this acreage. The division received your request only one day prior to the release date of the data from the 3N-7 and 3N-8A wells. We encourage you to submit any requests for extended confidentiality not more than 90 days prior to, but at least 30 days prior to, any release date in order to provide sufficient time for request evaluation, consideration, decision and notification of Alaska Oil and Gas Conservation Commission (AOGCC). By copy of this letter I am advising the AOGCC to proceed with release of the ARCO Kuparuk River Unit 3N-5, 3N-7, and 3N-8A wells as previously scheduled. Sincerely, ?-~_. . ~ames E. Eason Director Attachment 1 526E cc: C. V. Chatterton, Commissioner, AOGCC Judith M. Brady, Commissioner, DNR 1526E .. 'W w 1 I PARTIC/FA IIN! coO'> .. Q:Q:: ~.~ 0 0 I I r-- L___- 5 .. oJ I 0 0 I 0 I I : 0 I r-- 1-----1 -------. 10 BO~D:RY J + 0 0 0 I . I .10-06 . 0 0 0 I . ., . I 3 18 15 0 0 0 0 .JAI-18 DS-30 0 0 , . ---+'9'--- -------- + 20 21 22 . 0 0 0 0 0 0 . , . .1AI-05 ------- 29 28 27 .'5 ~ .1K-O2 . . , .JAI-O .JAI-O2 .1N-05 weST SAK T 6 . "1-()5 .1I-OJ .11-01 + ., , . ~ .:11-02 . . ..... . . J - - -- STATE OF ALASKA - /'/ ) ~.. ALJ.. .A OIL AND GAS CONSERVATION CO. ,IISSION (A/ REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown 0 Stimulate 0 Plugging 0 Perforate ¡g¡ Pull tubing lJ AI{ Alter Casing 0 Other 0 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc RKB 67' 3. Address 6. Unit or Property name B 4. Location of well at surface 7. Well number 1561' FSL, 304' FEL, Sec. 29, T13N, R9E, UM 3N- 7 ~ .Q. J. q At top of productive interval 8. Approval number 1257' FNL, 821' FEL, Sec.29, TI3N, R9E, UM #56 #- r~') At effective dep.th 9. API number 1105' FNL, 935' FEL, Sec.29, T13N, R9E, UM 50- 029-21539 Ab1OJ?-1 d~p.th 10. Pool 1 15 FNL, 1004' FEL, Sec.29, TI3N, R9E, UM Kuparuk River Oil Pool 11. Present well condition summary. , Total depth: measured 7793, MD feet Plugs (measured~One true vertical6732 TVD feet Effective depth: measured 7624' MD feet Junk (measured)None true vertical6606' TVD feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Report Conductor 80' 16/1 Not Available 115' MD 115' TVD Surface 3654' 9-5/8/1 1070 SX PF -E 3691' MD 3633' TVD xxxxoooo~~~oote & 280 SX Class G ~ Production 7675' 7" 310 SX Cl ass G 7707 I ~ r 6668' TVD xxxX*~xxxx & 175 SX ASI C '" Perforation depth: measured 7420' - 7 422' MD, 7443' - 7 465' MD c!;'" true vertical6454 1 -6456 I TVD. 6471' -6488' TVD 0( J~ Tubing (size, grade and measured depth) R E C. E 1 V E D 2-7/8/1, J-55 tbg w/tail @ 7234' HPackers ßnd. SSSV (jYRe and measured depth) B pkr ~ 7163' & SSSV @ 1788' ALJr 12. Stimulation or cement squeeze summary Alaska OiJ & G as Cons. Commission I ntervals treated (measured) Anchorage Treatment description including volumes used and final pressure 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 BaPD 0 MCFPD 0 BWPD 1100 psig 315 psig Subsequent to operation 173 BOPD 96 MCFPD 0 BWPD 1100 . 14. Attachments Daily Report of Well Operations ~ Copies of Logs and Surveys Run [~I , 15. I hereby certify that the foregoing is true and correct to the best of my knowledge '( Ó '- 0 ,.,l ~ ? .~- if, 3 rI- g/& Title Sr. Opera t i ons Eng i neer Date Jh I), Ý 7 Submit in uplicate ~ S¡OU)f seuw :Jo :10 ~odey peuD,S 1eA pulM AIIUqlslA JO¡O8:J IIILI:> .dwel JeLl¡p-<~ )f~V8 NO a3nNI1NO~ A~\fWWnS:l1 )f~O18 SIHl )f~3HO .....J {}f'rd{'\ij"'I!Ji. .I'.<.,,\.!, V . npIS(~1 WIlIO" "(>,1'0'1 (;r;r:¡ú I C~ r:)js~[\i f,.i!Jo". IJ,A.',i"JÍlI.i. ;,~,"'.r t T C[¡\f" Lv t! l, (J ~ 'vr , It "dAlllnI° OJ 4 ..~~ -, '0' "0 -0 ,. -~ II \. " ~ -« "&. . ,7 .¥ ~. I oddS;- 6' ~~~ ~ I (11 ç 0 ~ -Z (1/1 '{) ?J.17ðO:fd. : ), (/(1 U þf 17 ~ (YOJr;J(J 91 èI ..- 5/@/ ::I S Þ ~ f1VOcJ, - (h/¿I ::Id9 t¡? -:10 711"LO.J. C7 ?t¿;I ,¿zpt - , L4Pt 9flM19 7' (7Mf I CJ5it f¿ -,bpf"1- S(J,A/flS 1 D ~'¿"y~;NcI .~/ gLL .. ~)lIVp'--L- aL 771(YJ fV3d() - 00£; /t(¿j - 0 IC} / 9/V19Vltd of) ';lei>'? ~~tnft~/~ßIÍ3 r;;/'It79 :I;n¿ (w07 - 9/9/ ; ::J çtl " /fOOd. ¡VI ']nfYJ Þ?1t~ - 5PP/ .J¿eÞ~~()þ¿ .Çq~S' ctt OPtt 9S;¿ - b!Jf,L ~J5' /D ~lIdO:l~3t1 ~fVl ?/L . <;),/'tP-1. QL ~~ fVí1dO .- >/P! I ~/tII>t#lcI 0° :ld> P .).l('~f'la ~ ~~ 1M 11/(1 .,,-. 50i'/ I ~/117'~ e£ do (//77lð ~I 7J7(JJ , ~ 5r¿-Z1 ¡VI' / F:/fY) J. (}/tS ./XI ~ dt1tþlí)IfJ'3t?7 ,J,S2L . SI"t79 9fY~ð9d "1?ã~$t;. {I "6(1' ~ r:cI'iJ J-59L :.t-IT~d/t70~ ~I/tr r/fQ> tW> # {VI ,1. OW - 008 0 jf <; <7 IV itS' -Z 1:1! IV '7 ~ tfã' 0;1 diI d -<~ ,.,' 7/f8 ;""}j;f7;) J-9~ I?;; -2Þ/IÄ¿/" '~¡:JfI - -. . ~M 2J(J7/(/£- - 9!7¿Y!<l1 I I -,- - , ['19¿ - 31VO. SAV21-...... I load ~ ',_..uo:) PI911I.P ~ :muelW 10 ÁJelP!sqns ,¡ l~Od?~ "3~I^H3S 113/;\ <) .~UI 'e)fSBIV O~M" ' ARCO Alaska, Inc. ~ ..... Post Office Box 100360 ø ...... Anchorage, Alaska 99510-0360 ... .,.. Telephone 907 276 1215 ~." April 30, 1987 Transmittal # 5966 Return to: ARGO Alaska, Inc. Attn: Kuparuk Records Glerk 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. 3N-7 GET 4-1-86 6202-7597 3N-6 GET 4-1-86 6061-7583 3N-11 GET 4-22-86 7600-8675 3N-12 GET 4-29-86 6396-7965 3N-10 GET 4-14-86 7462-9130 3J-16 GET 3-29-86 7704-8727 3J-15 GET 3-29~86 7400-8398 lA-8 GET 1-5-86 5755-6154 22-7 GET 4-14-87 8250-8491 22-7 GET 4-12-87 8246-8595 22-7 Squeeze & Retainer Record 4-15-87 8250-8491 22-7 Squeeze, BP & Retainer Record 4-12-87 8290-8588 B : ~'; ì ! .. G / Aia:; tJ!i.\ Receipt Acknowledged: -------------------------- Date: ---------- DISTRIBUTION: NSK Drilling State of Alaska (+ sepia) BPAE Chevron Mobil SAPC Unocal Vault (film) ARca Alaska Inc IS a Subslolary at A!lan!lcR;cntleldCompany ARCO Alaska, In ,~, ~ ..... ()f--/ Post Office ,Q'-'X 100360 ... ~ "Jl Anchorage, Alaska 99510-0360 ~ ~ W,' Telephone 907 276 1215 /, v æH j1)Iu October 7, 1986 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached in triplicate is an intent notice on Kuparuk Well 3N-7: Well Action Anticipated Start Date 3N-7 Perforate October 3,1986 If you have any questions, please call me at 265-6840. Sincerely, I:J ß ~f' '1; l'! - ,r, 'I I. '1/ / '" ã'1/t./ ' ~) /' lÅ'./l:v{~/"'{'.?~~('"'" G. B. ~mallwood Senior Operations Engineer GBS:pg:0040 Attachments cc: Fi 1 e KOEl.4-9 \<ELE\VEO \. '.>T 1 /; 1986 , ,,' 1 on & Gas Corr;. C(n:¡'I),;~';: Ð,Jes.<a ^ h(';~"'( ,r:> .,,- ¡....nc..ulû;;" ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany .-' STATE OF ALASKA- ALA....."A OIL AND GAS CONSERVATION COI" , SSION 3 APPLICATION FOR SUNDRY APPROVALS 1, Type of Request: Abandon 0 Suspend 0 Operation Shutdown 0 Re-enter suspended well 0 Alter casing [) Time extension 0 Change approved program 0 Plugging 0 Stimulate 0 Pull tubing 0 Amend order [] Perforate ~ Other [] 2. Name of Operator 5. Datum elevation (DF or KB) ARCa Alas ka, I nc RKB 67 feet 3. Address 6. Unit or Property name PO Box 100360 Anchora e AK 99510 Ku aruk River Unit 4. Location of well at surface 7. Well number 1561' FSL, 3041 FEL, Sec.29, T13N, R9E, UM 3N-7 At top of proauctive interval 8. Permit number 1257' FNL, 8211 FEL, Sec.29, T13N, R9E, UM Permit #86-28 At e.ffEfcti'{~ depJh 9. API number 11ti2 FNL, 878' FEL, Sec.29, T13N, R9E, UM 50- 029-21539 At total depth 10. Pool 1015' FNL 1004' FEL Sec.29 T13N R9E UM Ku aruk River Oil Pool 11. Present well condition summary Total depth: measured 7793 r MD feet Plugs (measured) true vertical 6732 , MD feet Effective depth: measured 7624' MD feet Junk (measured) true vertical 6606 1 MD feet Casing Length Size Cemented Measured depth True Vertical depth Structural 1151 1611 235 SX CS11 115' MD 115' TVD Conductor 3691' 9-5/811 1070 SX PFIIEII 3691' MD 3633' TVD xxx~~xf~~~xx & 280 SX Cl ass IIGII Interme~iate 7707' 711 310 SX Class IIGII 77071 MD 6668' TVD xxxf*~~ & 175 SX ASl Liner Perforation depth: measured 7420'-7422' MD, 7443'-7465' MD . " ,',' c.' " \';}: C" true vertical6454 , -6456 1 TVD, 6471' -6488' TVD ~\. [ L t ~ V [, U Tubing (size, grade and measured depth)i 1986 2-7/811, 7234'MD , O.,"}n""("",.,,, "">C,'. ;;"1"')(J' 'il & \~<~~) ".",¡". "\, .;,;', , ..~....." Packers and SSSV (type and measured depth) ¡'J,nc:::u 12.Attachments Description summary of proposal D Detailed operations program D BOP sketch 13. Estimated date for commencing operation October 3,1986 14. If proposal was verbally approved Name of approver Mr. L. Smi th Date approved 10/2/86 15. I hereby certify that the for~going is true and wrrect to the best of my knowledge SignedJ;~l,~í{/1/ ') '<i'E/f..ø-ðt,t~~~,r~1'Ç/Ì{Y Title Sr. Operations Engineer DatèO/2/86 Commission Use Only Conditions of approval Notify commission so representat,ive may witness Approval No. '~," / /, D Plug integrity D BOP Te§t P Location clearance ,7 G:r, , /' is' rt:l" ik_,l..~". Wode ~~ . .,¡i ~..e~ "c;I ,:y",""~.........,,..p. '!í~"'" ," ,p' ",~"n';~'irán\} /6," . " ,," . 't1:íi"~:\~("',c"",\""",,, , 'rli,' "c""""",,' ~..."...Cftðtr' Jð-/~_,I",....fJclí(tA..bJ:1J. ",' ..' . ~ ~~ I. ft D" on 'UiL&JLit .I-~ ~ u..t.~,'" ;;1 t ~U¡J Y or er of Approved by ~J."!:!~.¥.~~~ . Commissioner the commission Date/O -/~- -~ Form 10-403 Rev 12-1-85 Submit in triplicate . . (, (" 0 " . 1-:')TTI~)CHhENï :~:..¡ ':'d""'¡¡+¡"';'\!"L 1"i:~!ì"~"O¡":;'i'¡""ì"i;' ",,"L:.1 I:>¡"C}") ",'¡"-.."¡' 'J"')'- ]/UI'1"'¡"l'{{'" W....ll' ',?¡\I..,.¡'.'!';' "'¡",-:. r', ,.I 1\ U,IQ i"'o;. I d \ \oJ i.., Ç(lo,;.. ... l/-)t-,.l. I I.. I I;' -<:1 u. 1:.... ,.J., " ¡ ^ I It-.. depths tobe shot and shot density are as foLlows: l)e~Pth (MD) Depth (TV I) SPF ...,................................,... ...................,...,........,........., ,.,'...... 'f' 3 -4 Ÿ I .... '? 3:56 ' Ó.4 ø 'i I .." é 4¡";) li . H "'}l.lf:,"JI ""b'-)"'}! '4'44!' :¡¡:'c.l C' ( l '.... ( 'M' { . 1 Ä.. i ...> .M' Ö ._~ ..~, l ,;~ REtElVE Ð " "."",' ":,,, , " """ ,', .",.",',' OCT 1 4 19~6 , ," '",° G's""'"""",Q,,cornmrss1on , 01 0. a \,¡\JH-" Alas\<.t " \ Anc\,oraQe ARCO Alaska. Inc,;.-., ~.' ~ ~ ~ Post OfficI... '00360 ø ~ Anchorage. AiasKa 99510-0360 -- ......." T el~pnone 907 216 1215 . ~ ." . DA:7. 08-08-86 ~"I\..<:VT-"'~ ~5~.'" ...~'_.._... ~ r; ,....1. PZT'JRN TO: ., A.~CO AlASKA, INC. A'!'TN: K-.:paruk Recorè.s Clerk ATe 1119 P. o. Box 100360 Anchorage AK 99510-0360 - Trans:r-i tted herewith are the following items. Please acknowledge receipt and retu..~ one signed copy of this transmittal. Open Hole Final Prints: Schl: One * of each 2T-1"""'" D1L/SFl-GR 03-08-86 Run 1f1 3671-8365 .. ---2" .!)1L/SFL-GR 03-08-86 Run D1 3671-836.5 ;[ ........... 5" Den/Neu-GR (poro) 03-08-86 Run if1 3671-834.0 ~ t\ ~2tf ben/Neu-GR (pore). 03-08-86 Run ill 3671-8340 . ........ 5" l>en/Neu-GR (ra~) 03-08-86 R~n #1 3671-8340 0 Ii """2" ~en/Neu-GR (ra~..) 03-08-86 Run nl 3671-8340 l/~' ~Cyberlook. 03-08-86 Run fl 7850-834~ ~~~roductive Interval 03-08-86 Run 01 7850-8340 ~ ~RFT Log 03-08-86 Run D1 7957-8212 /31-9 5" D1L/SFL-GR 03-13-86 IÜ1n ,iiI 1500-9122 2" D1LíSFL-GR 03-13-86 Rl'.n D1 1500-9122 ~ 5" Den/Neu (para) 03-13-86 Run Dl 8440-9096 . ,~ -, 2" Den/Neu (pore) 03-13-86 Run #1 8440-9096 ~It.. 5" Den/Neu (ra~) 03-13-86 Run nl 8440-9096 . ~ 2" Den/Neu. (ra~) 03-13-86 Ren ifl 8440-9096 Cyberlo~k 03-13-86 Ren #1 8440-9065 v 3N-7"'- 5" DIL/SFL-GR 03-06-86 Run #1 1800-7777 . . ~~ ...... 2" DIL/SFL-GR 03-06-86 ~ 1/1 1800-7777 ... - 5 " Den/Neu-GR (po re ) 03-06- 86 Run f! 1 6790- 7752 . - ~ Den/Neu-GR (pore) 03-06~86 Run ffl 6790-7752 -,,1(-5" Den/Neu-GR (:-aw) 03-06-86 R~n #J 6790-7752 ~-2" Den/Neu-GR (raw) 03-06-86 Run i~l 6790-7752 ...Cyberlook 03-06-86 Run #1 7190-7752 31-1 -j" D1L/SFL-GR 03-02-86 Run III 1500-9204 -t.,2" DIL/SFL-GR':' 03-02-86 Run ifl 1500-9204 5" Den/Neu (pore) 03-02-86 Run i:1 8750-9178 ~./ ~2" Den/Netl (Dore) 03-02-86 Run #1 8750-9178 7~. '" 5" Den/N.eu (~aw) 03-9:-86 R~:l:~ 8750-~: 78 ~,..." Den/Neu (raw) 03- -86 Run".. 875O-~...78 Cyber1oek 0 0 8750-9155 - ~, Receict Acknowledg l ,~ . D & M*bl Vault*films .... -"""""""'0 A~CO AlaSka. I"c. 'S " Sucs,Ola,'f of AII."hC~IC" I~ ClComøa"y - ~> STATE OF ALASKA / -- ~ ALASKA viL AND GAS CONSERVATION CoMMISSION '1J WELL COMPLETION OR RECOMPLETION REPORT AND LOQ--r4.,~ 1. Status of Well Classification of Secvice Well ":~ OIL B GAS 0 SUSPENDED D ABANDONED D SERVICE 0 (B 2. Name of Operator 7. Permit Number Ø'v ARCO Alaska, Inc. 86-28 3. Address 8. API Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21539 4. Location of well at surface 9. Unit or Lease Name 1561' FSL, 304' FEL, Sec.29, T13N, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1257 FNL, 821' FEL, Sec.29, T13N, R9E, UM 3N-7 At Total Depth 11. Field and Pool 1015' FNL, 1004' FEL, Sec.29, T13N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kupaurk River 0; 1 Pool 67' RKB ADL 25521 ALK 2557 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 03/01/86 03/06/86 06/07/86* N/ A feet MSL 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MDtTVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 7793'MD,6732'TVD 7624'MD,6606'TVD YES~ NoD 1788 feetMD 1700' (approx) 22. Type Electric or Other Logs Run DIL/GR/SP/SFL, FDC/CNL, Cal, GCT, CET 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED It>. t>L..::>1F H-LfuSurr 115' 24" 235 sx CS II 9-5/8" 36.0# J-55 Surf 3691 ' 12-1/4" 1 070 sx PF "E" & 280 sx '::1 ass G 7" 26.0# J-55 Surf 7707' 8-1/2" 310 sx Class G & 175 sx AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7420'-7422'MD 6454'-6456'TVD 2-7/8" 7234' 7163' 7443'-7465'MD 6471 '-6488'TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED See attached adden(um, dated 6/11/86, for fracture data 7373' - 7375' 300 sx Class G 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 GAS-OIL RATIO TEST PERIOD. Flow Tubing Casing Pressure CALCULATED IIIIIIIIIII. OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-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 RECE\VED JOl1 0 1986 . . '>"..')mi"~ion n:IL,(..,ç'I'.!'<':;\..¡;"'I"'" Alaska)1 () "to,) ,I" -- A_:,,_:n~" ,.,i'::- Form 10-407 * NOTE: Drilled RR 3/7/86. Well perf'd & tubing run 4/26/86. WC1/081 Submit in duPlicate- rJ Rev. 7-1-80 CONTINUED ON REVERSE SIDE f(jJ . --.~, >--".J I : ~ 29. . , 30. ,\1 " . , - ' . 1 GEOLOGIC MARKERS ' -FORMATION TESTS t 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 7338' 6393' N/A Base Kuparuk C 7355' 6405' Top Kuparuk A 7395' 6435' Base Kuparuk A 7493' 6509' I 31. LIST OF ATTACHMENTS Addendum (dated 6/11/86) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge S' d I.~. . Associate Engineer 7-2-ß¿, Igne ~ Title Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (OF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ~cc-.. . ADD END U M -------- WELL: 3N-7 3/21/86 Arctic Pak w/175 sx AS I, followed by 56 bbls Arctic Fake 6/07/86 Frac'd Kuparuk "A" sand perfs 7420', 7422' & 7443'-7465' in 9 stages per 6/5/86 procedure using Musol, diesel, gel/diesel, 100 mesh & 20/40 sand. Press'd annulus to 1800 psi w/diesel. Tst Ins to 7500 psi; OK. Stage #1: Pmp'd 20 bbls 1400 diesel w/5% Musol @ 4 BPM (no psi reported) Stage #2: 65 bbls gel/diesel spacer @ 16-20 BPM w/5800-4700 psi Stage #3: 15 bbls gel/diesel pre-pad @ 20 BPM w/4700-4830 psi Stage #4: 24 bbls gel/diesel w/1 ppg 100 mesh @ 20 BPM w/4830-4760 psi Stage #5: 128 bbls gel/diesel pad @ 20 BPM w/4760-4680 psi Stage #6: 19 bbls gel/diesel w/3 ppg 20/40 @ 20 BPM w/4680-4650 psi ("on fly") Stage #7: 40 bbls gel/diesel w/6 ppg 20/40 @ 20-17 BPM w/4650-5960 psi Stage #8: 15 bbls gel/diesel w/8 ppg 20/40 @ 17-16.5 BPM w/5960-6000 psi ("batch") Stage ¡19" 48 bbls gel/diesel flush @ 16.5-20 BPM w/6000-4350 psi Pmp'd 1000# 100 mesh & 17,250# 20/40 in formation leaving 270# 20/40 sand in csg. Load to recover 374 bbls of diesel. Job complete @ 1250 hrs,6/7/86. Turn well over to Production. Production to rn post frac logs. RECE1VED JUL 1 0 1986 Alaska Oil & Gas Cons. 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Operations performed: Operation shutdown 0 Stimulate 0 Plugging 0 Perforate ~ Pull tubing C /v.V £ Alter Casing 0 Other)D UmDl.efQ... / 2. Name of Operator 5. Datum elevation (OF or KB) tt ARCO Alaska, Inc. RKB 67' Feet 3. Address 6. Unit or Property name P.o. Box 100360 Anchoraoe. AK 99510 Klln~rllk Rivpr Iinir 4. Location of well at surface 7. Well number 1561 'FSL, 304'FEL, Sec.29, T13N, R9E, UM 3N-7 At top of productive interval 8. Approval number 1257' FNL, 821 'FEL, Sec.29, T13N, R9E, UM 56 At effective depth 9. API number 1105'FNL, 935'FEL, Sec.29, T13N, R9E, UM 50- 029-21539 At total depth 10. Pool 1015'FNL, 1004'FEL, Sec.29, T13N, R9E, UM Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured 7793 feet Plugs (measured) Non e true vertical 6732 feet Effective depth: measured 7624 feet Junk (measured) true vertical feet Non e 6606 Casing Length Size Cemented Measured depth True Vertical depth Conductor 80' 16" Conductor report 115'MD 115'TVD not available. Surface 3654' 9-5/8" 1070 sx PF "E" & 3691 'MD 3633'TVD 280 sx Class G Production 7675' 7" 310 sx Class G & 7707'MD 6668'TVD 175 sx AS I Perforation depth: measured 7420' - 7422' M D 7443' - 7465 'MD true vertical 6454' - 6456'TVD 6471' - 6488'TVD Tubing (size, grade and measured depth) 2-7/8", J-55 tbg w/tai 1 @ 7234' Packers and SSSV (type and measured depth) HB pkr @ 7163' & SSSV @ 1788' 12. Stimulation or cement squeeze summary Intervals treated (measured) 7373' - 7375' . Treatment description including volumes used and final pressure squeezed with 300 sx Class G 13. N / A Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 14. Attachments (Completion Well History) Daily Report of Well Operations l8l. Copies of Logs and Surveys Run ~ ßIAÝn 15. , hereby certify that the foregoing is true and correct to the best of my knowledge v Signed 4o0irvXJ ktHA.- Title Associ ate Enoi neer Date 5-14-8~ Form 10-404 Rev. 12-1-85 f/ ( DAM) S WO / 0 1 3 Submit in Duplicate " ItandGas Company <> Well History - Initial Report - Dally , Inatructlo'na: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started, Dally work prior to spudding should be summarized on the form giving inclusive dates only. District County. parish or borough Istate Alaska North Slope Borough Alaska Field Lease or Unit Iwell no. Kuparuk River ADL 25521 I 3N-7 Auth. or w.o. no. Title AFE AKl142 Completion Nordic 1 API 50-029-21539 Operator ARCO W,I. ARCO Alaska, Inc. 56.24% Spudded or W.O, begun Date Hour Prior status If a W.O. Complete 4/22/86 1415 hrs. Date and depth Complete record for each day reported as of 8:00 a.m, 7" @ 7707' 7384' PBTD, Prep to RIRw/7" R-3 pkr 10.0 ppg NaCl/NaBr Acce1Jt', ri-',@/1415 hrs.4/22l8&. NIl wellhead,. NU & tat BOPE. RIH w/WL, " perf f/sq~w"4'lt. 4SPFgun, POR,. Setretrv BP @ 73841, POB, RD :5'.;~/ WL. RIKwIR-¥-3 pkr'onDP. RU &. pmp.'2oa"'Xc:cl..., G eDIt' thru sqz , perfs @ 7313.tt-7375.'w¡'p.Jt set @ 71U'¿~"~§:" " >1!tI', rev out',,; poa , " " wÆ3~" DP¡';g.PJt.q):f.t.~Rm{¡1-3~"; DPto,6R,' ,"C~~.' RIB',;(t..cm.t' t~. " : ,109&f.~, drldnt-,'t,C1, 7384J'c~:CBU., , Tst,"~t~,,~,.~{1.1J).~~:;'Q~1;("J;~"~' .~ ~:l:/::;::r=~>h:;~ ~-~'¡ " ""',' ",' . ,', ;;, ' ' , " \,~'>F:7 384' PBT1),DrlaBP'Kb ¿7';"è;~O; '9.9ppgNaClt,NaBr-." n<, RIH,.set sq.,pkt'.st:tt- @,7111 t sqz t d vt100 s~ Cl ItG" w/.65% FL;..28 , .3%CD-31 & .1%FÞ;"6. Rev ou~& trip f/bit, WOC. Tagged cmt @7195' t Dr! cmt to 7384', tat sqz perfs' to 2000 psi. ",- The above is correct Title Drilling Supervisor For for preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. 8" ." , ' " .- ' , ",.""":"v"',^,,;;""."',,',,',,,,",' ',' . " .'~ ..".',.:,.",'",'.-":~~-?",:,':,';",:,t._.",.';.;-'C, . < '" ARCO Oil and Gas Company <> Daily Well History - Final Report ' Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold, "Final Report" should be submitted also when operations are suspended for an in definite 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, Accounting cost center code District County or Parish Stale Alaska North Slope Borough Alaska Field Lease or Unit I Well no, Kuparuk River ADL 25521 3N-7 Auth. or W,O. no. Title AFE AK142 Completion Nordic 1 API 50-029-21539 Operator A.R.Co. W,I. Total number of wells (active or inactive) on thiS ARCO Alaska Inc. 56.24% cost center prior to plugging and , abandonment of this well Spudded or W.O. begun Date Hour ¡Prior status if a W.O. Complete 4/22/86 1415 hrs. Date and depth Complete record for each day reported as of 8:00 a.m, 4/26/86 7" @ 7707' 7384' PBTD, RR 9.9 ppg NaCl/NaBr DO BP, chased to btm, circ & filter brine, POH, LD DP. RU Schl, perf w/4" guns, 4 SPF £/7443'-7465' & 7420'-7422', RD Schl. RU & rn 231 jts, 2-7/8", 6.511, J-55 EUE 8RD AB Mod IPC tbg w/SSSV @ 1788', PBR @ 7151', HB Hyd Pkr @ 7163', TT @ 7234'. Set pkr, shear PBR. Instl BPV, ND BOPE, NU & tat tree. Displ well w/diesel. Set BPV. RR @ 1200 bra, 4/26/86. Old TD New TD PB Depth 7384' PBTD Released rig Date Kind of rig 1200 hrs. 4/26/86 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 % GaR Gravity Allowable Effective date corrected The above is correct Title Drilling Supervisor For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. STATE OF ALASKA ALASKa, JIl AND GAS CONSERVATION COMM~,,_,ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Reques[: Abandon [] Suspend [] Operation Shutdown ~ Re-enter suspended well ~ Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate"~ Pull tubing Z Amend order ~_ Perforate .X~ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box. 1 00360 Anchr~ran~; AK 9qc. 1 ~ 4. Location of well at surface 1561'FSL, 304'FEL, Sec.29, T13N, R9E, UM At top of productive interval 1358'FNL, 784'FEL, Sec.29, T13N, RgE, UM (approx.) At effective depth 1123'FNL, 918'FEL, Sec.29, T13N, R9E, UM (approx.) At total depth 1031'FNL, 983'FEL, Sec.29, T13N, RgE, UM (approx.) 5. Datum elevation (DF or KB) 67 ' RKB feet 6. Unit or Property name 7. Well number 3N-7 8. Permit number 86-28 9. APl number 50-- 029-21539 10. Pool Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured true vertical 7793 feet Plugs (measured) No ne 6738 feet Effective depth: measured feet Junk (measured) true vertical 7624 feet None 661 2 Casing Length Size Cemented Measured depth Conductor 80 ' 1 6" Conductor report 11 5 'MD not avail able. Surface 3654' 9-5/8" 1070 sx PF "E" & 3691 'MD 280 sx Class G Production 7675' 7" 310 sx Class G & 7707'MD 1 75 sx AS I Perforation depth: measured None true vertical None True Vertical depth 11 5 ' TVD 3632'TVD 6674'TVD Tubing (size, grade and measured depth) None Packers and SSSV (type and measured depth) None 12.Attachments Description summary of proposal [] Detailed. operations program [] Well Hi story (/~/Udi~,.~ Add~r)d~.{./~'~ 13. Estimated date for commencing operation May, 1 986 BOP sketch [] 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 ~~ ~ Title Associate Engineer ~/ Commission Use Only ( DAM ) SA/024 Date Conditions of approval Approved by Notify commission so representative may witness [] Plug integrity [] BOP Test I Approval No. Location clearance -: ..- · ,-~ .~; ~ ....................... , ............... by order of Commissioner the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate ADDENDUM WELL: 3N-7 3/~1/86 Arctic Pak w/175 sx AS I, followed by 56 bbls Arctic Pak. Drilling Supervisor Date ARCO Oil and Gas Company Well History - Initial Report- Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Field I County, parish or borough [State Alaska Alaska North Slope Borough ILeaseorUnit IWollno. Kuparuk River ADL 25521 3N-7 Auth. or W.O. no, ITitle AFE AKl142 I Drill Doyon 9 API 50-029-21539 Operator IARCO W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begUnspudded IDate 3/1/86 IH°ur 2000 hrs. IPri°rstatusifaW'O' Complete record for each day reposed Date and depth as of 8:00 a.m. 3/Ol/86 thru 3/03/86 3/04/86 3/05/86 3/06/86 16" @ 115' 3710', (3595'), Prep to rn csg Wt. 9.2, PV 12, YP 14, PH 9.0, WL 11.6, Sol 6 A.~cept rig @ 1515 hrs, 3/1/86. NU diverter sys. Spud well @ 2000 hfs, 3/1/86. Navi-Drl & surv 12¼" hole to 3710'. 2450', Assumed vertical 2566', 5.4°, N 9.75W, 2565 TVD, 6 VS, 5N, 1W 2819', 8.7°, N17.25W, 2816 TVD, 35 VS, 36N, 3105', 17.5°, N21.25E, 3095 TVD, 90 VS, 96N, 22E 3572', 25.7°, N29.25E, 3526 TVD, 233 VS, 258N, 99E 3640', 25.7°, N31.25E, 3587 TVD, 255 VS, 283N, l14E 9-5/8" @ 3691 3710', (0'), Cut DL Mx new mud Short trip to HWDP, C&C, TOH, LD BHA. RU & rn 94 Jts, 9-5/8", 36#, J-55 csg w/FS @ 3691', FC @ 3610'. Cmt w/1070 sx PF "E" w/lO#/sx Gilsonite, followed by 280 sx C1 "G" w/2% CaCi_. Displ using rig pmps, bump plug. CIP @ 7:50 p.m., 3/3/~6. ND diverter, NU &tst BOPE. TIH w/BHA. 9-5/8" @ 3691' 6098', (2388'), Drlg Wt. 9.2, PV 7, YP 4, PH 9.5, WL 9.8, Sol 6 CO cmt to FC, tst csg to 2000 psi. DO to 3700'. Conduct formation tst to 12.4 ppg EMW. Navi-Drl, drl & surv 8½" hole to 6098'. 3989', 32.6°, N20.25E, 3892 TVD, 390 VS, 436N, 187E 4495', 35.9°, N 6.25E, 4307 TVD, 654 VS, 718N, 248E 4809', 41.1°, N 3.75W, 4553 TVD, 844 VS, 912N, 247E 9-5/8" @ 3691' 7793', (1695'), RU Schl Wt. 9.9, PV 16, YP 10, PH 9.5, WL 5.8, Sol 11 Navi-Drl & surv 8½" hole f/6098'-7793', short trip, rm 7763'-7793', C&C, POH f/logs. 6038', 43.5°, N32.75W, 5438.6 TVD, 1683.1VS, 1714.8N, 13.7W 6571', 42.7°, N33.75W, 5827.7 TVD, 2023.0 VS, 2021.8N, 209.7W 7261', 41.5°, N35.75W, 6341.0 TVD, 2446.5 VS, 2400.4N, 472.7W The above is Correct Signature For form preparation and~listrlbutlon, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date -- Title Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report instructions: Prepare and submit the "Final Report" on the first Wednesday after allowabre has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted aisc 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 Alaska Field Kuparuk River Auth. or W.O. no. AFE AKl142 Doyon 9 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded Date and depth as of 8:00 a.m. 3/07/86 3/08/86 Old TD Released rig 0800 hrs. Classifications (oil, gas, etc.) 0±'! Flowing ICounty or Parish Lease or Unit Title Complete record for each day reported North Slope Borough ADL 25521 I Accounting State cost center code Alaska JWell no, 3N-7 Drill API 50-029-21539 W.I. ~otal number of wells (active or inactive) on thisI lc@st center prior to plugging and I 56.24% Jabandonment of this well iHour I Prior status if a W.O. 3/1/86 | 2000 hrs. I 7" @ 7707' 7793' TD, 7624' PBTD, RD cmt'rs Wt. 9.9, PV 14, YP 8, PH 9.0, WL 5.7, Sol 11 RU Schl & log DIL/SFL/SP/GR f/7785'-3690' GR to 1900'. Rn CNL/FDC f/7785'-6800'. CAL f/7785'-5400'. Make cond'g rn. Chg rams to 7" & tst. RU & rn 187 jts + 2 mkr its, 7", 26#, J-55 BTC csg w/FS @ 7707', FC @ 7624'. Cmt w/100 sx C1 "G" w/ 50/50 Poz, .85% CFR-2, .7% Halad-9 & 9% gel, followed by 210 sx C1 "G" w/.6% FDP-C344 & .25% HR-5. Displ cmt w/9.8 ppg NaC1 brine, bump plug. CIP @ 0500 hrs, 3/7/86. 7" @ 7707' 7793' TD, 7624' PBTD, RR 9.8 ppg NaC1 brine Chg rams back to 5". ND BOPE, instl upper pack-off & tbg head, tst lower seals to 3000 psi. RR @ 0800 hrs, 3/7/86. FC @ 7624' FS @ 7707' Producing method JNew TD PB Depth 7793' TD IDate K nd of r g 3/8/86 Type completion (single, dual, etc.) Sinsle Official reservoir name(s) Kuparuk Sands 7624' PBTD Rotary Potential test data Well no. I 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 and ¥istribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. D.~a f},~/ , JTitle Drillln$ Superintendent ' -' STATE OF ALASKA -' ~ ALASKA O;- AND GAS CONSERVATION CO,~,MISSION ~. MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONSTM' · Drilling wellX~ Workover operation [] !2. Name of operator ARCO Alaska, Inc. 7. Permit No. 86-28 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50-029-21539 4. Location of Well atsurface 1561' FSL, 304' FEL, Sec.29, T13N, R9E, UN 6. Lease Designation and Serial No. ADL 25521 ALK 2557 For the Month of. March , 19 86 5. Elevation in feet (indicate KB, DF, etc.) 67 ' RKB 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 3N-7 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded we]l ~ 2000 hfs, 3/1/86. Dr]d 12-1/4" hole to 3710'. Ran, cmtd, & tstd 9-5/8" csg. to 7793'TD (3/6/86). Ran logs. Ran, cmtd, & tstd 7" csg. PBTD = 7624', Secured well 3/7/86. Drld 8-1/2" hole & RR ~ 0800 hrs, 13. Casing or liner ru.n and quantities of cement, results of pressure tests 16", 62.5#/ft, H-40, weld conductor set @ 115'. Conductor report not available. 9-5/8", 36.0#/ft, J-55, BTC csg w/shoe ~ 3691'. Cmtd w/lO70 sx PF "E" & 280 sx Class G. 7", 26.0#/ft, J-55, BTC csg w/shoe ~ 7707'. Cmtd w/310 sx Class G. 14. Coring resume and brief description None 15. Logs run and depth where run DIL/GR/SP/SFL f/7785' - 3690'; GR to 1900' FDC/CNL f/7785' - 6800' Cal f/7785' - 5400' 6. DST data, perforating data, shows of H2S, miscellaneous data None 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--Report o~/this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 DAM2/MR02 Submit in duplicate ARCO Alastca.. Post Office Box 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC. ATT~: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 04-01-86 TRANSMITTAL ~ 5613 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. OH LIS Tapes plus Listings: Schl: One of each 3N-9 03-23-86 3N-8 03-14-86 3N-8A 03-19-86 3N-7 03-06-86 31-12 03-22-86 3I-9 03-13-86 3I-8 03-02-86 2T-17 03-08-86 Run #1 0091'0-4424 R~ #1 0115.0-6670 R~ ~1 1766.5-7803 ~ ~ [500.0-9~22.~d~9.3 .Receipt Acknow!edqed: ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 31, 1986 A? Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commi ssion 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 ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany Jrlll I I II I i ii ~_~.~, i i ii ii i i I I LOCATED IN PROTRACTED SEC's 28 & z~,ti3 N, R 9E,U.M. m .... . LOCATED IN PROTRACTED LOCATED SEC. 29, TISN~ RgE~ U.M. SEC. 29, TISN~RgE, U.M. [ - Y = 6,0[3,799.67 LAT. 70°~6'55.96[5" [0 - Y = X - 517,946.19 LONG. 149°51' 12. 938" X 454' FEL, 1562' FSL OG · 28.2 PAD = 33.7 179' FEL, 1561' FSL OG ' 28.5 PAD : 34.0 2 - Y ' 6,013,799.65 LAT. 70026'55.9606" 11 - Y = 6,013,799.32 LAT. 70026'55.9508" X ~ 517,971.21 LONG.149°51'12.203" X - 518,246.03 LONG. 149°51'04.132'' 429' FEL, 1562' FSL OG = 28.2 PAD = 33.8 !55' FEL, !561' FSL OG ' 28.5 PAD : 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 LONG. 149°51'11.468" X : 518,270.89 LONG. 149o51'03.403" 404' FEL, 1562' FSL OG - 28.4 PAD : 33.9 130' FEL, 1561' FSL DG ' 28.5 PAD .= 34.0 4 - Y : 6,013,799.50 LAT. 70026'55.9580" 13 - Y : 6,013,799.41 LAT. 70026'55.9505" X - 518,021.16 LONG. 149°51'10.736" X = 518,295.97 LONG. 149o51'02.666" 379' FEL, 1562' FSL OG = 2B.~ PAD = 33.7 ~ 105 FEL, 1561 FSL OG ' 28.5 PAD ' 34.1 5 Y = 6,013,799.~ LAT. 70026'55.9572" - c= 14 - Y = 6,013,799.33 LAT. 70~26'55.9491" X = 518,046.18 LONG. 149°51' i0.002" '~ X = 518,320.91 L~G. 149°51'01. 934" 354' FEL, 1562' FSL OG = 28.5 PAD = 33.7 ~ ~ 80' FEL, 1561' FSL OG = 28.5 PAD ~ 34.0 ). 6 - Y = 6,013,799.44 LAT. 70026'55.9562" ~ LO ~ 15 - Y = 6,013,799.28 ~T. 70026'55.9480" X = 518,071.24 LONG.149°51'09.266" ~ X = 518,345.77 LONG.149°51'01.204'' 329' FEL, 1562 FSL OG = 28.5 PAD = 33.9 55' FEL, ~56~ FSL OG = 2B 5 PAD = 34.0 7 - Y = 6,013,799.44 LAT. 70°26'55.9556 .... ~ ~ ~ 16- Y = 6,013.799.25 LAT. 70°26'55.9471" ~ '' X = 518,370.74 LONG 149051'00.470" X = 518,096.21 LONG' I49°51'08' 533" ~ 0 ~ ~ ' , ~ ~ ~ 30' FEL, 1561' FSL OG 304' FEL 1561' FSL OG = 28.5 PAD = 33.9 ~ 8 - Y = 6,013,799.45 LAT. 70°26'55.9551" ~ ~ 17 - Y = 6,013,799.26 LAT. 70°~6'55.9466'' X = 518,121.15 LONG. 149°51'07.800" -- X = 518,395.63 LONG. 149°50' 59. 739" 279' FEL, 1561' FSL OG = 28.6 PAD = 33.9 ~ ~ ~ 5' FEL, 1561' FSL OG = 28.5 ~AD = 34.1 9 - y = 6,013,799.42 LAT. 70026'55.9542" X : 518,146.15 LONG. 149051'07.066" c) SEC. 28,TI3N, R9E, U.M. 254' FEL, 1561' FSL 0G = 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 20' ~k, ~6~~ FSL 0G: ~.S ~D : ~.0 I. ALL COORDiNaTES ARE A.S.P.,ZONE4. 2. SECTION LINE DISTANCES ARE TRUE. ). HORIZONTAL POSITIONS BASED ON ON-PAD PILING CONTROL PER LHD 4. VERTICAL POSITIONS BASED ON MODULE PILES 5JOI-8 5. O.G. ELEVATIONS INTERPOLATED FROM S/C DRAW:NG CED-RIXX-3OgO rev.~. mm, , mm m , ,, m CERTIFICATE OF SURVEYOR: , ~E~EBY CERt~"Y tHAT , :~ PROPERLY , ~ '~- :~ : -.M~S,O~S AND C--~ER DEtail'S k: g ~ KUPARUK PROJECT = , -~ .oo~ ~.. ~ AS BUILT LOCATIONS ............................ llDWG. NO. NSK a~-) ~3~5 Arc,lc Boule,lard. Su/re 207 Anc,~orage. J/a.s~a ~9503 /IscALE NOT TO SCALE ..... I ij O" ~ ..... I m Ii January 30, 1986 Mr. Jeffrey B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 TELECOPY NO. 276-7542 Re: Kuparuk River Unit 3N-7 ARCO Alaska, Inc. Permit No. 86-28 . Sur. Loc. 1561'FSL, 304'FEL, Sec.29, T13N, R9E, UM. Btmho!e Loc. l166'FNL, 823'FEL, Sec.29, T13N, R9E, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. · The permit to drill does not indemnify you from the probable need to obtain additional permits required 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. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. C. V. Chatted'ton Chaiman o f Alaska Oil and Gas Conservation Commission BY OPd)ER OF THE COF~ISSION dlf Enclosure cc: 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 B~x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 22, 1986 Mr. C. V. Chatterton Commi ss i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Kuparuk 3N-7 Dear Mr. Chatterton' Enclosed are' An application for Permit to Drill 3N-7, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore ° A proximity plot o A diagram and description of the surface hole diverter system o A diagram and description of the BOP equipment We estimate spudding this well on February 22, 1986. If you have any questions, please call me at 263-4970. Si n..~ely, Regional Drilling Engineer JBK/LWK/tw PD/L211 Enclosures RECEIVED JAN 2 1985 0il & Gas Cons. ~mmissi0n ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA u~L AND GAS CONSERVATION CO,,~MISSION PERMIT TO DRILL 20 AAC 25.005 DRILL ~X lb. T~pe of well EXPLORATORY ~ SERVICE ~ ST~.GRA~ REDRILL ~ DEVELOPMENT OIL ~X SINGLE ZONE DEEPEN ~ DEVELOPMENT GAS ~ MULTIPLE ZONE la. Type of work. 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 1561' FSL, 304' FEL, Seco29, T13N, R9E, UN At top of proposed producing interval 1358' FNL, 784' FEL, Sec.29, T13N, R9E, UM At total depth 1166' FNL, 823' FEL, Sec.29, T13N, R9E, UN 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. RKB 67', PAD 33' I ADL 25521 ALK 2557 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 9. Unit or lease name Kuparuk River Unit 10. Well number 3N-7 11. Field and pool Kuparuk River Fi eld Kuparuk River 0il Pool Amount $500,000 13. Distance and direction from nearest town 30 mi. NW of Deadhorse miles 16. Proposed depth(MD & TVD) 7463' MD, 6648' TVD feet 14. Distance to nearest property or lease line 304 feet 17. Number of acres in lease 2560 15. Distance to nearest drilling or completed 3N-6 well 25' ~ surface feet 18. Approximate spud date 02/22/86 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures 2909 KICK OFF POINT 2492 feet. MAXIMUM HOLE ANGLE 36 oI (see 20 AAC 25.035 (c) (2) 3340 psig@__80 °F Surface psig@ 6487 ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SIZE Hole Casing 24" 16" 12-1/4" 9-5/8" 8-1/2" 7" 22. Describe proposed Weight 62.5# 36.0# CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Grade H-40 1-55/HF-EI 26.0# 1-55/HF-Et program: Coupling Weld ,'W BTC [W BTC Length MD TOP TVD 80' 35' 3672' 7429 ' 35' I 35' I 35' I 34' 34 I MD BOTTOM TVD 115~ 115' 37071 3627' 7463~ 6648' I (include stage data) ± 200 cf 1070 sx PF "E" & 280 sx PF Class "G" 300 sx Class "G" neat ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 7463'MD(6648' TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 13-5/8", 5000 psi, RSRRA BOP stack will be installed on the 9-5/8" surface casing. The stack and related equipment will be tested to 3000 psig upon installation and weekly thereafter. Expected maximum surface pressure is 2909 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 3500 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 3N-7 will be 25' away from 3N-6 at the surface. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. (continued on attached sheet) · 23. I hereby cer,~c~hat the foregoing/~, true and correct to the best of my knowledge The space b~[/q~ for ~or~'m~on' use Regional Drilling Engineer DATE CONDITIONS OF APPROVAL Samples required Mud log required E~YES ~NO ~YES ~AIO Permit number Approval date oO/~' Zf 01/30186 A PPROVEDBY.~. Form ~0401 Rev. 7-1-80 Directional Survey required I APl number SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE by order of the Commission January 30, 1986 Submit in triplicate PERMIT TO DRILL 3N-7 (cont'd) Upon completion of the disposal process, the 9-5/8" x 7" annulus will be sealed with a minimum of 175 sx cement followed by Arctic Pack. The well will be completed by the workover rig using 3-1/2" or 2-7/8" tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. RECEIVED JAN 2 4 19gS Alaska Oil & Gas Cor~s. Commission Anchor~ PAD 3N, WELL NO: 7 ~.,OPOSED KUPARUK FIELD. NORTH SLOPE. ALASKA EASTMAN WHIPSTOCK. INC. ,, SURFACE 1000 BASE PERMAFROST TVD=IZ17 2000] TOP UGNU SNDS TVD=2477 KOP._ TVD=2492 TMD=2492 DEP=O ~ 3 ~ BUILD 3 DEO -- 9 PER 100 FT 3000 5 ~ 21 TOP W SAK SNDS TVD=3172 TMD=:3187 DEP=125 ~ 27 K-12 TVD=:3427 TMD=:3469 DEP=245 ~ . ~ 33 EOC (9 5/8" CSG PT) - TVD=:362Z TMD=:3707 DEP=:374 = 4000 .......................... AVERAGE ANGLE 36 DEG 27 MI N K-5 TVD=5467 TMD=5995 DEP=I 7:33 6000 1000 2000 VERTICAL SECTION 7000 _ 0 T/ ZONE D TVD=6242 TMD=6959 DEP=2306 T/ ZONE C TVD=6284 TMD=7011 DEP=2337 ~ "~ , T/ ZONE A TVD=638:3 TMD=71:34 DEP=2410 X~ TARGET CNTR TVD=6435 TMD=7198 DEP=2448 B/ KUP SNDS TVD=6487 THD=726:3 DEP=2487 TD (LOG PT) TVD=6648 TMD=7463 DEP=2605 I I ! R[CEIV 'D JAN 2 4 '""'~' Alaska Oil & dj:; ~'- ~ ~ . HOR I ZONTAL~ PROJECT I ON ............. SCALE IN. = 1000 FEET _ _ __ _ . . PAD 3N. WELL NOt 7 PROPOSED ..... KUpARUK F!ELDt ..... NORTH. SLOPE! .... ALASKA .... / ~,/~ EASTMAN WHIPSTOCK. INC. . _ -- - WEST-EAST 2000 1000 0 1 000 4000 _ I ! I ............................................................. TD LOCA~[ONt ....... 1166' FNL. 823' FEL ........ SEC. 29. TI3N. R9E 3000 .......... i ......... ...'~.~./.; ....... '~',". ............ ~ ..................... TARGET CENTER ..... . - ' TVD-64..35 THD-?198 DEP-2448 ........................ _ NORTH 2399 WEST 488 TARGET LOCATION' 1320' FNLo 792' FEL z .2000 ' ' SEC. 29. T13N. RgE . SURFACE LOCATION~ 1~1' FSL, 304' FEL SEC, 29. T13N. RgE i800 ?00 ~00: $00 400 _ 300 _ 200 _ 800 700 600 500 400 300 200 ' 100 . 0 ' · ------L__ ..L g ...,- · i ~ .... ,, , · . } ~ , ~ . ' : - ' ' . · ' · I , ~ ~ ~' ' ' ~ ' ~ ' I ~ , : ~ , ' ....... : ......... : ....... ~ --:~::!. , ' ; '" ' : ~'~ ..... :' ~,..':<~;~.:~:~!!~' '---' : .. ; . .~:. ................... ~ ........ .. .... ,..-.: ..... I ' ' ' ........ ~~ ~ ~ 0 % ......... J .... ' ' , ~~ 5 ........ .... · ,o, __=-- ... . ...... : ~ 500 I ~ , - ..... I w J ,,,, / 2000 800 7OO / / 1500 6O0 I I I i I I 150Q I : I I I I I 500 400 300 200 100 ,I i, .. O0 KUPARUK RI VER UNIT 20" .DI VE~TER SCHEMATIC DE S CR I P T I ON I. IG' CO¢~CTC~. 2. TAI'~O STARTER HEAD. 5. TANKO SAVER SUB. 4. TAI',,I<O LOhER QUI CK-CCt, I',ECT ASSY. 5. TAI~O UPPER QUICK-C~CT ASSY. G. 20' 2000 PSI DRILLING SPOOL W/I O' OUTLETS. '7. IO" HCR BALL VALVES' W/lO' DIVERTER LINE~o VALVE~ OPEN AUTOMATICALLY UPON CLOSURE OF' At,,N.~AR PREVENTER. 8. 20" 2000 PSI AtNNJLAR PREVENTER. 5 MAI NTENANCE & OPERAT I ON I. UP-ON INITIAL INSTALLATIC~ CLOSE PREVENTER AND VERIFY THAT VALVES HAVE OPENED PROPERLY, 2. CLOSE AN'~LAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. 5: CLOSE ANNULAR PREVENTER IN THE EVENT 'THAT AN INFLUX OF WELLBC~ " FLUIDS OR GAS IS DETECTED. IF NECESSARY, IN4AI'~ALLY OVERRIDE AINI~ CLOSE APPROPRIATE VALVE TO ACHIEVE DO~INWlND DIVERSIC~N. DO NOT SHUT IN ~ELL UNC>ER' ANY C I RCUIVS ~,NCES. 7 6 .. DI AGRAJ~ #~ · .I~-5/F~' "~00 PSI RSRRA 8C~ STACK/ 1. 16' - 2000 PSI TAN<CO STARTI 3, Ii" - ~ ~I X 1~8' - ~ 4. 1~8' - ~ ~I PI~ 5. 1~8' - ~ ~I ~I~I~ KI~ LI~ 6. 1~8' - ~ ~I ~ ~ ~/PI~ ACO_MJLATOR CAPACITY TEST I. c~CK AND FILL' A(XI~TCR RESERVOIR TO 'PRC~ LEVEL WlTM HYDRAULIC ~UID. 2. ~ ~T A~T~ ~~ IS ~ ~I WI~ 1~ ~i ~T~ ~ ~ ~~T~. 3. ~~ TI~, ~ ~ ~ ~ITS SIXThlY ~L ~ITS ~ ~~ WI~ ~I~ ~ ~. 4. ~~ ~ ~ ~T, ~ A~T~E L~ LIMIT IS 45 ~~ ~I~ TI~ ~ I~ ~I ~INI~ P~~. 5 4 3 2 13-5/8" BCP STACK TEST I. FILL BOP STACK AND C~ N~%NIF~ WlTM ARCTIC DIESEL. 2. Q-ECK THAT AIL LOCK ~ SC~ IN ~ELLHEAD ARE FLLLY R~-'TRACT~. SF_AT TEST PLLK$ IN Y, E1.U-F~ WITH RL~IN~ JT AND RLIW IN LOC~ SC~. 3. CLOSE ~ PR~'VE]NrrB~ AND MANJ~ K~LL A~ CHO<E LI~ V~VES ~~ TO ~ STA~ ~L V~S ~ ~ ~ ~ ~. 4. P~~ ~ TO 2~~ F~ lO ~IN. ~ ~~ T~~~ ~ F~ lO ~IN. BL~ ~~ TO ~. 5. ~ ~ PR~~ ~ ~AL KI~ ~ LI~ VALVES. ~E T~ PIPE ~ ~ ~ VALVES ~ KILL ~ ~E 6. TEST TO 2~ PSI ~~~ ~ IN ST~ 7. ~I~ TESTI~ ALL~, LI~S, ~ WITM A ~ PSI L~ ~ ~ PSI HI~. TEST AS IN ST~ 4. ~ ~T ~~, TEST.~ ~ ~T ~I~ 75SI ~S ~T ~ ~ ~LY ~. TEST B~ PIPE ~ TO ~ ~I ~ ~ ~I. 9. ~ BO~ PIPE R~, ~ ~ ~I~ ~ ~ .lO. ~ ~I~ ~ ~ TEST TO 2~ ~I ~.~ PSI. Il. ~ ~I~ R~ ~ ~I~E TEST ~. ~ ~IF~ ~ LI~S ~ ~L, ~ ~UID. ~ A~ VALVES IN ~I~I~ P~ITI~ 12. TEST STRIPE VALVES, K~LY, ~Y ~S, ~ILL' PI~ S~Y VALVE, ~ I~I~ B~ TO ~ PSI 3~ PSI. JAN 2 0084001 REV. 2 CHECK LIST FOR NEW WELL PERMITS Company fJR(][) Lease & Well No. K R Ll... 3/V- 7 ITEM APPROVE DATE YES NO REMARKS --- - (1) Fee ~K 1-¿7-~' 1. Is the permit fee attached .......................................... ~--- I (2) Loc ~t::. J~27-f'b 2. Is well to be located in a defined pool ............................. ~ --- (2 thru 8) 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................)!Ig,}K. --- ~ 7. Is operator the only affected party ................................. ~ --- IVvr;l JJ~7 $b 8. Can permit be approved before ten-day wait .......................... ~ --- (8) I I (3) Admin ~~ /-Z7-¿r6 9. Does operator have a bond in force ...................;.............. ~ --- (9 thru 12) 10. Is a conservation order needed ...............,...................... --- ~ .,. J/¿r;¡. 1/~7/%6 11. Is administrative approval needed ................................... --- ~ ( ~ i 2) I 12. Is the lease number appropriate..................................... iIJ!2t:. --- ., (4) casg/lld€. J-:-28-ß/' 13. Is conductor string provided ........................................ dIL --- (13 thru 21)14. Is enough cement used to circulate on conductor and surface......... ~ --- g 15. Will cement tie in surface and intermediate or production strings ... Lf!l --- ~z 16. Will cement cover all known productive horizons ..................... ~ --- ~ ~ 17. Will surface casing protect fresh water zones, ....................... ~ --- 00 ~ 18. Will all casing give adequate safety in collapse, tension and burst.. .Ht. --- ~ ~ 19. Is this well to be kicked off from an existing wellbore ............. --- ~. ~ ~ 20. Is old wellbore abandonment procedure included on 10-403 ............ ---~)Q. H 21. Is adequate wellbore separation proposed. . . . . . . . . . . . . . . . . . . . . . . . . . .. ;¡¡j --- )<Op'::J 'tf~ I S~ç: Rt;MN'tJ<S Z (5) BOPE~.t 1-~.8I. 2.2.' ¡sa d..iv."ert.er.systemr.eq..tdre.d..........."""""""'.".'.'.'.'.""""'" j...'.'.'..'..".,..,'.'."'......'.' -. .~........,.,..,......t;;'øM.'E.Io"JI¿/J"I<"~lkrUl'~l,- Ilk. (22 thru 26) 23. Are necessary diagrams of diverter and BOP equipment attached....... " ---" 24. Does BOPE have sufficient pressure rating - Test to 30ð(!) psig. . ..' --- . 25. Does the choke manifold comply w / API RP-53 (F.eb. 78) . . . . . . . . . . . . . . .... --- --.A'øf t~i,,¿JlM/-Hl!Cd {" 26. Is the presence of H2S gas probable................................. --- 8. "'-- i (6) Add:~~t 27. Additional requirements ..............................,.............. --- ~ Geology: HWK * ~ INITIAL GEO. UNIT ON/OFF WVA .. POOL CLASS STATUS AREA NO. SHORE JAL ~. rev: 03/13/85 . 6.011 .,.",,""".",-' ",..,..._",."".".-.."......-........".,......,......-~~.._,.,..-,"""','.,'n.---."",.""""",,'.,""""" .,'.-,',"'-""""': """,,"""""""-"'-',---"'-"""'--"""--'----"--,-"'--'.---...--..-.-"----..'--.-..-..'-----..-.--.-.-. 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. , .... SCHLUMBERGER .... , LIS TAPE VERIFICATION LISTING RECEIVED .Vp OlO.kt02 VERIFICATION LISTING PASE 1 =~:.' REE:L H~ADER ...... -,--,- ;ERVICE NAME :EDIT )ATE :86/03117 }RIGIN : ~EEL NAME :1~9409 :ONTINUATiON ~ :01 ~REVIOUS REEL 'OMMENT.S :LiSRARY 'TAPE ,..,. 'TAP:~ HEADER; ~X~: ~ERVICE NAME :EDIT )ATE :86103/17 ]RIGIN :FS1A FAPE NAME : :ONTINUATION ~ :01 ~REVIOUS TAPE : :OMM:ENTS :LIBRARY TAPE ',-';~ FILE HEADER ;',~: =ILE NAME :EDIT SERVICE NAIAE : CERSION ,~ : ]ATE : qAXIMUM LENGTH : :ILE TYPE : ~REViOUS FILE : .00i 1024 ,~-"'-'°-,- INFORMATION RECOROS '"'",,, MNEM CONTENTS UNIT TYPE CATE SIZE CODE i ! I I CN : ~RCO ALASKA, INC. 000 000 015 065 NN : 3N-7 000 OOO 00~ 085 ~N : KUPARUK RIVER 000 000 014 065 RANG: 9= 000 000 002 065 T~WN: 13N 000 000 006 SECT: 29 000 000 002 06~ COUN: NORTH SLOPE 000 000 012 055 STAT: ALASKA 000 000 006 065 MNEM CONTENTS UNIT TYP~ CATE SIZE CODE Iili llil !ili IllI ilii LVp O!O.H02 VERiFICATiON LISTING OAGE 2 ,.- SCHLUMB:RG:R ::: ALASKA COMPU'TI'NG CENTER COMPANY : ARCO ALASKA iNC WELL = 3N-7 FIELD = KUPARUK COUNTY = NORTH SLOPE BOROUGH STATE = ALASKA JOB NUMBER AT ACC: 71331 RUN ~ONE, DATE LOGGEO: 6 MAR 86 LOP: T HALSTE~O CASING TYPE FLUID DENSITY VISCOSITY PH =LUIO LOSS ~ATRIX SANDSTONE : 9.623" @ 3690' - BIT SIZE : 8.5" TO 7793' : LS'NO · = 9.9 LB/G RM = 3.9'70 ~ 68 OF = 43.0 S RMF = 4.060 @ 68 DF = 9.5 RMC = 3.120 @ 6.8 D~ : 5.8 C3 RM AT BHT = 2.053 @ 138 DF THIS DATA HAS NOT SEEN DEPTH SHIFTED - OVERLAYS FIELD PRINTS .~P OlO.H02 VERiFtC&TION LiSTiNG PAGE 3 ,SCHLUM~ER'$ER LOGS INCL~JO-=O WBTH THIS MIGN~TZC TIPE: *:~ OUAL iNDUCTION SPHERICALLY F$CU,SED LOG (OIL) ~= DAT~ ~VAiLABLE: 7777' TO 3700' ~,~ .,. FORMATION O;NSITY COMP~NqAT~D LOG (FDN) ,,."' COMPENSATED NE~TR3N :LOG (FDN) ..-'""~ -~ DATA AVAI-LABLE: 775Z' TO 6790' .,. " GAMgA RAY ZN CASING (.GR.CNL) -,- ~Tl IVlIL~BL~1 3800 TO 1800' :::: ~AT~ FORMAT RECORD. -.-"'"'.- :NTRY BLOCKS TYPE SiZE RE'PR COOE ENTRY 2 1 56 0 4 I 55 I 8 4 7 3 60 9 4 65 . I I N 16 1 66 I 0 1 66 0 IATUM SPECIFICATION BLOCKS INEM SERVICE SERVICE UNIT API AP1 4PI API FILE SIZE SPL REPR ID OROER ~ LOG TYPE CLASS MOD NO. CODE PROCESS (OCTAL) LVP 010.H02 VERIFICATION LI]STING DEPT FT O0 S~:LU DIL ILO D ZL SHMM ILM OIL SP DIL MV O0 GR DiL GAPI O0 G R !,= 0 N G A P I CALI FDN IN O0 RHO8 ~DN G/C3 O0 DRHO FDN G/C3 O0 NRAT FON O0 ~qNRA =ON O0 NPHI FON PU O0 N C N L F D N C P S 00 FCNL FDN CPS O0 GR ~,,~'NL G4oI~ O0 O0 22 IZ 12 Ol 3t 31 28 35 35 O0 89 33 33 31 ]EPT 78.03. 5000 SFLU SP -8.0605 GR RHOB 2.4690 DRHO '~IPHI 43. 8985 NCNL DF:PT 7800.0000 SPLU SP -8.6074 GR ~HOB 2.4590 DRHO NPHI 43.2129 NCNL 3EPT 7700.0000 SFLU S? -24. 0576 GR ~HOB 2.5120 DRHO qPHI 4! .5527 NCNL DEmT 7500.0000 SFLU SP -4.5540 ~HO6 2.4534 DRHO WPHI 36.2793 NCNL ]EPT 7500.0000 SFLU SP 26.5924 GR q'Hg5 2.4260 NPHI 44.3359 NCNL DEPT 7400.0000 SFLU SP 41.4180 GR RHO5 2. 3928 DRHO qPHI 32.0313 NCNL Dr'PT 7300.0000 S~LU S? 22.6143 :~HOB 2.6096 DRH~ ~PHI 33.7391 NCNL 114. O. 1722. 2. 114. O. 1722. 3. 116. O. 1930. 5. 103. O. 2221. 2. 111. O. 1885. 6. 90. -0. 2229. 2. 127. O. 2307. 5706 4648 1836 6875 5706 4648 1836 6875 2346 4023 0649 5875 1453 9023 017~ 5000 6663 7773 0190 6875 3718 7148 0029 5000 ~788 9023 0781 5000 O0 O1 46 44 Ol 01 Ol 0 t 02 Ol O1 O0 00 31 30 Ol ILD GR NRAT mCNL i LO GR NRAT FCNL 1 L D GR NRAT FCNL ILO GR NR AT =CNL GR NRAT ~CNL ILO GR NRAT FCNL GR NRAT FCNL 68 00000000000000 -68 00000000000000 i 1 1 68 00000000000000 I 6~ 00000000000000 t 68 00.000000000000 1 68 00000000000000 1 6~ 00000000000000 1 6~ 00000000000000 1 68 00000000000000 1 68 1 68 00000000000000 1 58 00000000000000 1 68 00000000000000 1 68 00000000000000 i S8 00000000000000 1 68 00000000000000 2.7190 !LM 2.4866 114.4648 CALI 8.5020 3.5393 RNRA 3.4397 500.6406 GR -999.2500 2.7190 ILM 2.4866 114.4648 CALl 8.9707 3.5393 RNR~ 3.4397 500.640:6 GR -999.2500 2.7170 ILM 2.8557 116.4023 CALl 8.7129 3.4280 RNRA 3.2405 595.8125 GR -999.2500 4.0164 1LM 4.2507 103.9023 CALI 8.5488 3.1272 RNR~ 2.8831 770.3125 GR -999.2500 2.2952 ILM 2.4221 111.7773 C~_Z o ==o~ 3.5745 RNR~ 3.3811 557.8125 GR -999.2500 5.7273 iLM 5.8054 '90.7148 CALi 8.6738 2.8909 RNRA 2.8811 773.3125 GR -999.2500 3. 1975 ILM 3. 3245 127.9023 CALI 9.3691 3.0569 qNR~ 3.0295 761.3125 GR -999.2500 LVP OiO.H02 VERIFICATION LISTING PAGE 5 SP NPH i DE~T SP NPHI DEPT SP RdO8 NPHi DE PT RHO8 NPHi OEPT SP RHOB NPHI OEPT SP RHO~ NPHI DEPT SP NPHI DEPT SP NPHI NPHI DEPT SP NPHI OEPT S~ ?ZO0.O000 SFLU 5.8484 GR 2.3518 DRHG 47.0703 NCNL 7100.0000 SFLU 36.1367 GR 2.4221 DRHO 53.3691 NCNL ?000.0000 SFLU -36.3320 GR 2.3'928 DRHO 45.7031 NCNL 6900.0000 SFLU -58.6133 GR 2.4163 DRHO 45.2637 NCNL 6800.0000 SFLU -4.3743 GR 2.3928 DRHO 42.6758 NCNL 6700.0000 SFLU -2.3376 GR -999.2500 DRHO -999.2500 NCNL 6600,0000 SFLU 5.8835 GR -999.2500 DRH'O -999.2500 NCNL 6500.0000 SFLU -0.5776 GR --999.2500 DRHO -999.2500 NCNL 5~00.0000 SFLU 51.4492 GR -999.2500 DRHO -999.2500 NCNL 6300.0000 SFLU 41.9180 GR -999.2500 DRHO -999.2500 NCNL 6200.0000 SFLU 20.9424 GR -999.2500 DRd3 2.2190 iLD 127.4023 GR 0.0068 NRAT 1740.68'75 FCNL 1.7901 ILO 109.8398 GR 0.0200 NR,aT 1793.6875 F~N~¢ ~' 2.5]295 ILO 126.1523 GR 0.0273 NRAT 1721.58'75 FCNL 4.1687 iLO 178.93?5 GR 0.0229 NR4T 1861.6875 FCNL 4.0671 ILO 217.4375 GR 0.0352 NR~T 1891.8875 FCNL 3. 3967 ILD 1 36. 1875 GR -999. 2500 NRAT -999.2500 FCNL 4.3328 iLO 1t4,4648 GR -999.2500 NRAT -999.2500 FCNL 4.1804 ILD 117.6523 GR -999.2500 NRAT -999.2500 FCNL 3.2073 ILO 127.2773 GR -999.2500 NRAT -999.2500 mCNL 4.1335 iLO 125.0898 -999.2500 NRAT -999.2500 FCNL 1.8985 ILD 120.9548 GR -999.2500 NR~T 1.8829 iLM 127.4023 CALi 3.7424 RNR~ 514.8125 GR 1.4424 ILM 109.8398 CALI 4.0945 RNR4 431.6406 GR 2.2971 ILM 126.1523 CALI 3.6682 RNRA 496.1406 GR 3.1975 !LM 178.9375 C4LI 3.6389 RNRA 514.3125 GR 3.0979 ILM 21'7.4375 CALI 3.5139 RNRA 534.8125 GR 3.2776 ILM 136.1875 CALi --999.2500 RNR4 -999.2500 GR 3. ~5 9 2 Z L M 114.4 4 -9'99.25OO -999.2500 GR 3.5823 iLM 117.6523 CALI -999.2500 RNRA -999.2500 GR 3.0588 ILM 127.2773 CALI -999.2500 RNR4 -9'99.2500 GR 4.2039 ILM 125.0898 C6LI -999.2500 RNRA -999.2500 GR 2.4241 ILM 120.9548 CALI -999.2500 RNR~ 1.9981 8.8848 3.3811 -999.2500 1.5655 8.9551 4.1531 -999.2:500 2.4299 8.8848 3.4690 -999.2500 3.4280 8.8145 3.6194 .-999.2500 3.2366 9.0176 3.5374 -999.2500 3.4045 9.4316 -999.2500 -999.2500 4.1804 9.6348 -999.2500 -999.2500 3.7366 9.6973 -999.2500 -999.2500 3.2355 9.8379 -999.2500 -999.2500 4.3801 9.2129 -999.2500 -999.2500 2.3401 9.4238 -999.2500 LV~ OlO.M02 VERiFiCATION LISTING PAgE 6 N P M i DEPT S? RHOB NPHI SP RHOB NPHI DEP'T SP RHOB NPHI DEPT SP RHOB 3EPT SP RHO8 NPHI O~PT SP NPHI OE~T SP RHO8 NPHI 3EPT S~ ~HOB NPHi ,...SEPT SP RHSB NPHi DEPT SP h~PHi D~mT -999.2500 NCNL 6100.0000 SFLU -28.0889 GR -999.2500 DRHO -999.2500 NCNL 6000.0000 S~LU -39.8320 GR -999.2500 DRHO -9~9.2500 NCNL 5900.0000 S~LU 6. 8953 GR -999. 2500 DRHO -999. 2500 NCNL 5800.0000 SFLU i2.6191 GR -999.2500 DRHO -999.2500 NCNL 5700.0000 SFLU -5.6165 GR -999.2500 ORH8 -999.2500 NCNL 5600.0000 SFLU -14.35'?~ GR ,-999.2500 DRHO -999.2500 NCNL 5500.0000 SFLU -6.3313 GR -999.2500 DRHO -999.2500 NCNL 5400.0000 SFLU -0.5908 GR -999.2500 ORHG -999.2500 NCNL 5300.0000 SFLU -999.2500 ORmG -999.2500 NCNL 5200.0000 S~LO -25.3B57 GR -999.2500 GRHO -999.2500 NCNL 5t03.0000 SFLU -31.5732 GR -999~. 2500 FCNL 2.6077 ILO 108.5898 o~R -999.2500 NRAT -999.2500 FCNL Z.992~ ILD 96.9848 -999.2500 NRAT -999.2500 ,FCNL 3.3362 ILD 121.2148 GR -999.2500 NRAT .-999.2500 FCNL 2.7307 ILO 105.2773 GR -999.2500 NRAT -999.2500 FCNL 3.2639 ILO 112.2773 GR -999.2500 NRAT -999.2500 FCNL 2.9690 ILO 110.5898 GR -999.2500 NR~T -999.2500 FCNL 2.3127 ILD 105.7773 GR -999.2500 NRAT -999.2500 FCNL 3.7756 IILD 113.2773 GR -999.2500 NR~T -999.2500 FCNL 3.5647 iLD 104.3398 SR -999.2500 NR~T -999.2500 FCNL 3.1057 ILO 9 ~. 4648 GR -999.2500 NRAT -999.2500 FCNL 2.7014 ILD 104.0998 GR -999.2500 GR 2.3254 ILM I 08. 5898 CALI -9:99. 2500 RN'~ -999.2500 GR 2.7151 ILM 96.9648 CALI -999.2300 RNRA -999.2500 GR 3.3!08 ILM 121.2148 CALi -999.2500 RNRA -999.2500 GR 2.7444 ILM 105.2773 CALI -999.2~00 RNRA -999.2500 GR 3.1526 ILM 112.2773 CALI -999.2500 RNRA -999.2500 GR 2.9631 ILM 110.5~98 C4LI -999.2500 RNRA -999.2500 GR 2.2659 !LM 105.7773 CALi -999.2500 RNRA -999.2500 GR 3.7678 !LM -999.2500 C~LI -999.2500 RNR:6 -999.2500 GR 3.1833 ILM -999.2500 C&LI -999.2500 RN~ -9~9.2500 GR 3.1116 ILM -999.2500 C~LI -999.2500 RNRA -999.2590 GR 2.7561 ILM -999.25CJ C4LI -999.2500 2.4182 9.0254 -999.2500 -999.2500 2.9124 9.1035 .-999.2500 -999.2500 3.4436 9.1191 -999.2500 -999.2500 2.8811 9.2285 -999.2500 -999.2500 3.2'776 9.0176 -999.2500 -999.2500 3.0999 8.7441 -999.2500 -999.2500 2.3616 8.2910 -999.2500 -999.2500 3.8~99 -999.2500 -999.2500 -999.2500 3.2874 -999.2500 -999.2500 -999.2500 3.2014 -999.2500 -999.2500 -999.2500 2.8518 -999.2500 LgP OlD.M02 VSRIFICATION LISTING OaG5 7 -999.2.500 D~HO -999.2500 NCNL OEOT 5000.0000 SFLU SP -52,.0820 02 RHO~ -999,2500 ORHO NPHI -999,2500 NCNL DEPT 4900.0000 SFLU SP -111.0977 GR ~qHO8 -999,2500 DRHO NPHI -999°2500 NCML DEPT ~$00.0000 SFLU SP -112,8477 GR RHOB -999,2500 ORHO NPHI -999.2500 NCNL 3~PT 4700,0000 S~LU SP -70.7852 GR ~H05 -999,2500 ORHO NPHI -999.2500 NCNL DEPT 4600,0000 SFLU SP -$5,0508 GR RHOB -999,2500 CRHO NPHi -999.2500 NCNL DEPT 4500,0000 SFLU SP -44.5820 GR RHO5 -999,2500 DR~O NPHZ -999.2500 NCNL OEPT 4~00,0000 S~LU SP -62,8320 GR RH08 -999.2500 02HO NPHI -9'9'9.2500 NCNL OEPT 4300,0000 SFLU SP -55,0820 GR RHSB -999.2500 DRH3 NPHi -999.2500 NCNL DEPT 4200,0000 SFLU Se -54,0508 GR qHO~ -9'99,2500 ORHO qPHZ -999.2500 NCNL 3EOT 4100.0000 SFLU SP -43.5~45 GR ~H05 -999.2500 DRHO NPMI -999.2500 NCNL -999,2500 NRAT -999,2500 FCNL 2,5706 ILD 115.4648 GR -999.2500 NR&T -999,2500 FCNL 2.4006 iL3 94,3398 G~ -999,2500 NR~T -999,2500 FCNL 3,1i55 104,5273 GR -999,2500 NRAT '-999,2500 FCNL 2,701~ ILO 108.0273 GR -999,2500 NRAT -999.2500 ~CNL 3.1174 ILD 99,2145 GR -999,2300 NR~T -999,2500 FCNL 2,8186 ILO 102,2773 GR -999,2500 NRAT -999,,2500 FCNL 2.7288 iLD 89.9023 GR -999.2500 NRAT -999.2500 FCNL 2.9456 ZLD 96.7773 GR -999,2300 NRAT -999,2500 FCNL 3.4983 ILO 99.8398 GR -999,2500 NRAT -999,2530 FCNL 3.4143 ILD 90.9648 GR -999,2500 NRAT -999.2500 FCNL -999.2500 -999.2500 2.5608 ILM -999.2500 CALl -999.2500 RNR~ -999,2500 GR 2,5605 ILM -999,2500 C~Li -999,2300 RNRA -999,2500 GR 3,1077 ILM -9~9,2500 C~LI -999,2300 RNRA -999,2300 GR 2,78.15 ILM -999.2500 CALI -999,2500 RNRA -999.2500 GR 3,0061 ILM -999,2500 CALI -999,2500 RNR~ -999,2300 GR 2.8225 ILM -999,2500 CALl -999,2300 RNRd -999,2500 GR 2.8401 ILM -999,25'00 CALI -999,2300 RNRA -999,2300 GR 3.1018 ILM -999,2500 CALI -999,2500 RNRd -999,2.300 GR 3.2014 iLM -999,2500 CALi -999.2500 RNR~ -999,2500 GR 3.6721 !LM -999,2500 CALi -9~9,2500 RNRA -999.2500 GR -999.2500 -999,2500 .2..6331 -999,2500 -999.2300 -999,2500 2,5725 -9~9,2500 -999,2500 -999,2500 3.1975 -999.2500 -999'2500 -999,2500 2,855? -999,2500 -999,2500 -999,2500 3.0803 -999.2500 '-999.2500 -999.2500 2,8772 -999,2500 -999,2500 -999.2500 2.8772 -999,2500 -999.2500 -999.2500 3.1467 -999,2500 -999,2500 -999,2300 3.3030 -999,2500 -999.2500 -999,2500 3.6077 -999.2500 -999.2500 -999.2500 3EPT 4000.0000 SFLJ 3.2717 iLD 3,2793 ILM 3.3889 LV~P OlO,Hi~2 VERIFICATION LZSTING ?~GE 8 SP NPHI DEPT SP RHOB NPHI DEPT SP RHOB NPHI DEPT SP RHO5 NPHI OEPT SP NPHI OEPT SP RHOB NPHI DEPT SP NPHI DEPT S? RmS~ NPHZ SP NPHI SP OEPT Se RH~B -40.5508 GR -999,2500 DRHO -999,2500 NCNL 3900,0000 SFLU -48,8320 GR -999,2500 DRHO -999,2500 NCNL 3800,0000 SFLU -47,0820 GR -999,2500 DRHO -999.2500 NCNL 3700,0000 SFLU -61.~20 GR -999,2500 DRHO -999.2500 NCNL 3600,0000 SFLU -999,2500 GR -999,2500 DRHO -999,2500 NCNk 3500.0000 SFLU -999,2500 GR -999.2500 ORH2 -999,2500 NCNL 3400:,0000 SFLU -999,2500 GR -999,2500 DRHO -999,2500 NCNL 3300.0000 SFLU -999.2500 GR -999.2500 DRH8 -999,2500 NCNL 3ZO0.O000 SFLU -999,2500 GR -999,2500 DRHO -999.2500 NCNL 3100.0000 SFLU -999,2500 GR -999,2500 DRHO -999.2500 NCNL 3000.0000 .SFLU -999.2500 G:q -99'9.2500 DRHg -999.2500 NCNL 97,7773 GR -999,2500 NRAT -999,2500 FCNL 3.6292 ILO 103.0273 GR -999.2500 NRAT -999.2500 FCNL 2,5725 iLO 98.2148 GR -999.2500 NRdT -999.2500 FCNL 3,0295 ILO 85.0273 GR -999,2500 NR~T -999.2500 FCNL -9:99,2500 ILO -999,2500 GR -999.2500 NRAT -999.2500 FCNL -999,2500 ILD -999,2500 GR -999.2500 NRAT -999.2500 ¢CNL -999,2500 ILO -999.2500 GR -999,2500 NRAT -999.2500 FCNL -999,2500 ILD -999.2500 GR -999.2500 NRA'T -999.2~00 FCNL -999.2500 -999.2500 GR -999.2500 NR~T -999.2500 FCNL -999.2500 ILD -999,2500 GR -999.2500 NRAT -999,2500 FCNL -999.2500 iLD -999.2500 GR -999.2500 NR~T -999.2500 FCNL -999,2500 CALi -999.2500 RNRA -999.2500 GR 3.3616 ILM -999.2500 CALi -999.2500 RNRA -999.2500 GR 2,7249 ILM -999.2500 CALl -999.2500 RNRA -999.2500 GR 3,2578 ILM -999,2,500 CALl -999,2500 RNRA -999.2500 GR -999,2500 !LM -999,2500 :CALl -999,2500 RNRA -999.2500 GR -999.2500 !LM -999,2500 CALI -999,2500 RNRA -999.2500 GR -999,2500 ILM -999.2500 CALl -999.2500 RNR~ -999.2500 GR -999.2500 ILM -999.2500 CALl -999.2500 RNRA -999,2500 GR -999.2500 ILM -999.2500 CALl -999.2500 RNRA -999.2500 GR -999.2500 ILM -999.2500 CALl -999,2500 RNRA -999,2500 GR -999.2500 ILM -999,2500 CALl -999,2300 RNR,~ -999.2500 GR -99'9,2500 -999,2500 -999,2500 3.3459 -999.2500 -999.2500 -999.2500 2.6760 -999.2500 -999.2500 101.2773 3,2053 -999,2500 -999,2500 84,.2148 -999,2500 -999,2500 -999,2500 50,9805 -999.2500 -999.2500 -999.2500 51.7930 -999.2500 -999,2500 -999.2500 55,9492 -999,2500 -999.2500 -999.2500 50.9492 -999,2500 -999,2500 -999,2500 46,82~2 -999.2500 -999.2500 -999.2500 57.5992 -9'99.2500 -999.2500 -999.2500 32.5742 .HO..~ VER!FICA'Ti3N L~'STING~. ~!'3=, ~. 9 EPT 2900.0000 SFLU P -999.2500 GR HOB -999.2500 9R~3 PHI -999,2500 NCNL -999,2500 ZLD -999,2500 GR -9'99,2500 NR~T -999,2500 FCNL EPT 2800,0000 SFLU P -999,2500 3R HOB -999,2500 ORH~ PHZ -999.2500 NCNL -999.2500 ILS -999°2500 GR -999.2500 NRAT -999,2500 FCNL E~T 2700.0000 SFLU P -999.2500 GR HO~ -999,2500 DRHO PHI -999,2500 NCNL -999,2500 ILD -999.2500 GR -999,2500 NRAT -999,2500 FCNL EPT 2600,0000 SFLU P -999,2500 GR HO5 -999.2500 DRHO PHI .-999.2500 NCNL -999,2500 -999,2500 -9:9'9,.2500 NRAT -999,2500 FCNL EPT 2500,0000 SFLU -999,2500 GR -999,2500 DRHO -999,2500 NCNL -999,2500 iLD -999,2500 GR -9'99,2500 NRAT -999.2500 FCNL ;P ',HOB ~PHI 2400,0000 SFLU -999,2500 GR 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