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200-135
Ima~[]~roject Well History File Cove~ge XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. c;~ D.~ _[ ~:)_~' Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: BY: [] Other, No/Type BEVERLY ROBIN VINCENT SHERYL~INDY Project Proofing BY: BEVERLY ROBIN VINCENT SHERYL ~WINDY Scanning Preparation x 30 =_ (~ BY: BEVERLY ROBIN VINCENT SHERYL~,_~INDY · ~ Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: BY: Stage 2 BY~ (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES ) PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION' ._~ YES BEV~~INCENT SHERYL MARIA WINDY ~/S/ NO IF NO IN STAGE 1, PAGE(S) DISCREP~E FOUND: YESNO III IIIIIIIIll Illll RESCANNED BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: DATE: /SI Quality Checked 12/10/02Rev3NOTScanned.wpd 'r ' M STATE OF ALASKA ~ r~~,~ Z~lQ9 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPT~+~~c4~?~I„m;~~~~r, 1a. Well Status: Oil ^ Gas Plugged / Abandoned / Suspended 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. Well CIa~~ChQCa e Development ^ _ ~ Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., rAband.: February 20, 2009 12. Permit to Drill Number: 200-135 / 308-450 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. pudded: September 19, 2000 13. API Number: 50-103-20349-00 4a. Location of Well (Governmental Section): Surface: 6' FNL, 529' FEL, Sec. 3, T9N, R7E, UM ' 7. Date TD Reached: October 3, 2000 14. Well Name and Number: 2N-305 Top of Productive Horizon: 2155' FSL, 324' FWL, Sec. 26, T10N, R7E, UM 8. KB (ft above MSL): RKB /S~f Ground (ft MSL): 119' AMSL~ 15. Field/Pool(s): Kuparuk River Field Total Depth: 2552' FNL, 345' FWL, Sec. 26, T10N, R7E, UM 9. Plug Back Depth (MD + TVD): ~- 3370' MD / 2453' TVD Tarn Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 461064 y- 5912001. Zone- 4 10. Total Depth (MD + TVD): .~ 10334' MD / 5682' TvD ~.~~ ~. Property Designation: ,/~.DL 80053, 380054, 375074 TPI: x- 461944 y- 5919437 Zone- 4 Total Depth: x- 461967 - 5920010 Zone- 4 11. SSSV Depth (MD + TVD): landing nipple @ 507' MD ! 506' TVD 17. Land Use Permit: 4601 18. Directional Survey: Yes ^ No ^/ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (TVD): approx. 1249' TVD t 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): GR/RES 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 41' 118' 41' 118' 24" 8 cu yds High Early 7.625" 29.7# L-80 41' 3026' 41' 2296' 9.875" 330 sx AS Ilt Lite, 240 sx Class G " 5.5" 15.5# L-80 41' 9383' 41' 5210' 7.5" 170 sx Class G & 520 sx Class 3329' 3.5" 9.2# L-80 9383' 10328' 5210' 5679' 7.5" included above " 5.5" casing cut at 3370' MD 23. Open to production or injection? Yes No / If Yes, list each 24. TUBING RECORD Interval open (MD+T~/D of Top & Bottom; Pertoration Size and Number): SIZE DEPTH SET (MD) PACKER SET none none perforations plugged off ~. } 7~j '_t ~~~~ z ' w'~~~' •~ ~r ,1 4 25. ACID, FRACTURE, CEMENTS EEZE, ETC. . . a ~,... t. DEPTH INTERVAL (MD) a MOUNTAND KIND OF MATERIAL USED cement retainer @ 8958'-9328' bls Class G 15.8 ppg cement cement retainer @ 2925'-3374' bbls Class G ~,~SV~ ~. `~z~'n ` y ~-~ ~z ~B~s c~i<s~s 'C' cr.,,~ ~ ~~ 3 ~ ~ ~~ `t 718' ,~ r'~. l(~.~ ~,, .' ~ T 26. PRODUCTION TEST C S Date First Production Method of Operation (Flowing, gas lift, etc.) plugged and abandoned Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corr) 27. CORE DATA Conventional Core(s) Acquired? Yes ^ No / - Sidewall Cores Acquired? Yes No / 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. ,/~ J~ C~+tr2 N NE ~ ~~~ VERIFIED J1 0 ~ ~ I.'.~:''~m_:.w .' Form 10-407 Revised 2/2007 a CONTINUED ON REVERSE SIDE ~~ ~~ ~~~.~~ ~~ ~/~f f ~:. 28. GEOLOGIC MARKERS (List all formations and mar ncountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes ^~ No If yes, list intervals and formations tested, Permafrost -Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom 1287' 1249' needed, and submit detailed test information per 20 AAC 25.071. T-3 9592' 5307' T-2 9746' 5381' N/A Formation at total depth: T-3 30. LIST OF ATTACHMENTS Summary of Daily Operations 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mike Greener @ 263-4820 Printed Name Mik Greener Title: Drillino Enoineer ~/ / d Signature Phone Date /'~~/ ~ 7 INSTRUCTIONS Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00}. Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 ~ 2N-305 Summary ~AT~ ~ SUMMARY 2/6/09 PULLED 2.75" CA-2 PLUG r~ ~4' RKB. DRIFTED TBG WITH 2.74" SW~; TAGGED ~ 9718' SLM, EST. 5' FILL. PUMPED 20 BBL DSL @ 1.5 BPM, 1450 PSI, PERFS CLEAR. READY FOR .E/L. 2/6/09 SEI 3.5" HALLIBURTON EZ DRILL SQUEEZE PACKER AT 9282.5', LIKELY IN BOTTOM OF SLEEVE. COULD NOT PASS THROUGH NIPPLE AT 9374', PULLED TIGHT COMING OFF OF NIPPLE AT 9374'. PULLED TIGHT IN GAS LIFT MANDREL ABOVE NIPPLE. PULLED OUT OF GLM AND ,OT STUCK IN V AT A 80'. PRESSURE TESTED TO 2500 PSI AND OBSERVED 200-PSI DROP OVER A 5-MINUTE INTERVAL LIKELY DUE TO KNOWN TUBING AND PRODUCTION CASING LEAKS. 2/7/09 PERFORMED CEMENT P&A THRU EZSV CEMENT RETAINER PUT 3 8 BBLS 15 8 ppq RFI OW RETAINER AND 18 BBLS SQUEEZED INTO PERFS. STUNG OUT OF RETAINER ANn I AvFn IN ~ gBl ~ cFMFNT ON TOP OF RETAINER. CONTAMINATED WITH 810 AND REVERSED CIRCULATED DOWN TO 9090' CTMD.USING SLICK DIESEL LEAVING 200' CEMENT ON TOP OF RETAINER, WELL LEFT SHUT IN AND LOADED WITH DIESEL, TURN OVER TO DSO, 24 HR WAIT FOR P&A PRESSURE TEST. READY FOR SLICKLINE. 2/10/09 DRIFTED TBG TO TAG @ 9128' WLM W/ 2.73" DRIFT. BLED IA AND TBG TO 0 PSI; MONITORED WHILE MAKING DRIFT- REMAINED @ 0 PSI. Note: State witness o ag waived by John Crisp. 2/10/09 JET CUT 3.5" TUBING AT 8490' USING 2.5" SCHLUMBERGER POWERCUTTER. VALVE CREW TO SET BPV AND VR PLUG WHEN WEATHER BREAKS. 2/16/09 Nipple up BOPE equipment. Pick up 4" drill pipe, HWDP and jars. Test BOPE. Good test. Witnessed by AOGCC Chuck Scheve. Clean out debris from top of hanger and pull hanger to rig floor. Circulated seawater to clean hole. Set and iced in rig mats, run hi-line for shop and camps across pad. 2/17/09 Pull 3-1/2" gas lift completion. Tubing not cut completely, pulled entire completion string from well. Tested BOPE with 4" and 5-1/2" test joints. Sort used tubing and kick out corroded tubing. Pick up enough new tubing to make scraper run and set cement retainer. 2/17/09 STANDBY FOR POWERCUTTER ON DOYON 15 2/18/09 Run to bottom of 5-1/2" casing with scraper. No problems during trip in hole. Tagged up on depth. Circulate bottoms up at TD. Pull out of hole with scraper and picked up 5-1/2" cement retainer. 2/18/09 WEATHER DAY, STANDBY FOR JETCUT ON DOYON 15 2/19/09 STANDBY FOR DOYON 15 RIG 2/19/09 Run 5-1/2" cement retainer on 3-1/2" tubing to 9378' MD. Set retainer and circulate bottoms up. Rig up Dowell and pertorm infectivity test and pump 10 bbl cement plug on top of retainer. Circulate and pull out of hole. Make up 2nd retainer and prep to run in hole. 2/20/09 Pressure test cement plug. Run and set second retainer at 3400'. MD. Displace well to mud, lay down work string and pressure test retainer. Cut casing with jet cutter on eline. Attempt to displace annulus to mud, no returns. Spear 5-1/2" casing and pull free. ~~E r i ~o ~-~- 2/20/09 CUT 5.5" CSG AT 3370' WITH A 4.15" POWERCUTTER. GOOD INDICATION AT SURFACE. ~. . "~_- KUP ~ 2N-305 ConoCC3P~lrllips 1 ~ Well Attribut es _ Max A ° ngte is MD TD [`) h.~ I{ 111 Wellbore APl/UWI Field Name Well Status Prod/Inj Type Inc! ( ) MD (ftKB) Act 81m (ftKB) ~ 501032034900 TARN PARTICIPATING AREA PRODUCING 68 25 ~ 6,396 10,334 Comment ~ H25 (PPm) KBGrd (ftl iRig Release Datl (Date Annotation Entl Date -- °~~ fi 2N 305 2 15/20 - -_-- SSSV' NIPPLE (~-U%' 'N 30 1(112009 'Last WO' 41.64 I ~. 10/7/2000 - - Wep Con g , I _ SG -Halle -A . U . I A tat-or ' ~ Depth (%KB) End Date Annotaton End Date was[ I ag SLM 9 718 2B/2009 Rev Reason PULL PLUG. JE I CUl iBG ( 2/15/2009 CONDUCTOR I 161 15.0621 OI 1181 118 0 '~ ' SURFACE 0 3,025 2,296.1 75/8 6J50 conlDUCro s_ PRODUCTION ~ 5 1l2 4 950 0 9,383 5 209 7 PRODUCTION 3 1/2 2 992 9,383 10,3281 .5 678.6 " Tubing Strings String OD I String ID Set Depth Set Depth (TV D) Tubing Description (inl (inl Top (HKB) (ftKB) (kK8) NIPPLE 50]- TURING 3112''. 2.992 0 9.395 5.215 ens uFT. _ - _ ~ ~ 2,715 2,152.5 62 91 GAS LIFT CAMCOlKBG 2-9/1lDMY/DCK///Comment: STA 1 10/7/2000 2.992 2.]t5 _.~ F 5,899 3,613.9 60.11 GAS LIFT CAMCO/KBG 2-9fi/DMY/DCK///Comment: STA 2 1017/2000 2 992 8.001 4,570.5 61.43~GAS LIFT CAMCO/KBG 2-911/DMY/DCK//l Comment: STA3 10/7!2000 2.992 2/10/2009 2.992 8,490 4,802.0 62.101JET CUT JET CUT TBING @ 8490 ON 2.10.2009 suRFAC E, 3.025 - 9,290 5,168.2 64.09 SLEEVE-C BAKER CMU SLEEVE -CLOSED 4/24/2007 10!7/2000 2.8131 I ' 63.40 GAS LIFT ~GAMGrI/KBG 2-9/1/DMY/DCW/l Comment: STA4 10/25/2001 2.992 9,331 5,186.2 9,374 5,205.Sj 62.89 NIPPLE CAMCO'D' NIPPLE NO-GO 10!7!2000 2.750 9,375 5,206.0 ~, 62.88 LOCATOR ,BAKER 5.125' OD LOCATOR 10/7!2000 2.985 ens uFT. s.e9s I -_ 9,383 5,209.7 ~ 62.78 SEAL 'BAKER 80-00 CSG SEAL ASSY; 5.5' x 4' 10!1/2000 2.985 9,395 5,215.2 62.(4 GUIDE (BAKER TT RE-ENTRY GUIDE 10Al2000 P rt ti & Sl t e ora ons o s snm i "- - - - -- --__.._ - - Top (TVD) Bim (TYD) Dans Bim IHKBI (ftKB) (ftKB) Zone Date (sh"' TYPe Commen[ Top (fiKB) GAS UFT. ~ . 10/15/2000 40IPERF 2-1/2'HSD; 180 tleg ph 9,724 9.764 5.372.1 5.3727. S-3. 2N-305 ' 8.00? ~ 1 8 _ Stimulations Treatments Bottom _._ _ Min Top Maz Btm Top Depth Dapih Depth Depth (TV DI m'DI (ftKB) (HKB( (ftK61 If<KB) Type Date Comment ! 9,724 9 734 5,372.1 5,377.2 FRAC 110/1812000 'PUT 170 MLBS IN FORMATION. ~ - - CUT,9490 f - - . ~. Notes: General 8 Safety rr _.- End Date Annotation - - 4/28/2007 NOTE TUBING LEAK DETECTED BETWEEN 7666' 7868' RKB .~s~ ~ ~.~`~1 s~ IQs OAS LIFT, _ 9,331 NIPPLE, 9,316- - ' LOCATOR. 9,315 PRODUCTION, - 9,393 i GUIDE, 5.395 - IPERF, 9.724-9.736 FRAC, 9.724 PRODUCTION, 10,328 TD (2N-305J, 10,334 ConocoPhillips Time Log & Summary tNeftview tYeb Reporting Report Well Name: 2N-305 Rig Name: DOYON 15 Job Type: DRILLING SIDETRACK Rig Accept: 2/14/2009 10:30:00 PM Rig Release: 3/20/2009 8:30:00 AM Time Lo s Date From To Dur S. De th E. De th Phase Cod Subcod T Comment 2/11/2009 24 hrSummarv Move rockwasher, pits and sub off of 3H-33. Begin changing tires on pit module. 11:00 13:00 2.00 0 0 MIRU MOVE DMOB P Continue disconnecting lines between modules. 13:00 13:15 0.25 0 0 MIRU MOVE SFTY P PJSM -laying down beaver slide. 13:15 13:45 0.50 0 0 MIRU MOVE DMOB P Lay down beaver slide 13:45 14:00 0.25 0 0 MIRU MOVE SFTY P PJSM -skidding rig floor 14:00 14:45 0.75 0 0 MIRU MOVE DMOB P Skid rig floor 14:45 15:00 0.25 0 0 MIRU MOVE SFTY P PJSM -moving pits 15:00 20:15 5.25 0 0 MIRU MOVE DMOB P Move pits offf of mats and to side of ad where tires will be chan ed. 20:15 20:30 0.25 0 0 MIRU MOVE SFTY P PJSM - raiseing stompers. 20:30 21:00 0.50 0 0 MIRU MOVE DMOB P Rasie stomper feet. 21:00 23:00 2.00 0 0 MIRU MOVE DMOB P Move sub off of well and off of rig mats. 23:00 00:00 1.00 0 0 MIRU MOVE RGRP P Prep new tires, tent overtire and place heaters on tires. Begin pulling tire off it module. 2!12/2009 Changed two tire on pit module. Moved from 3H pad to 1Y -Spine road intersection. 00:00 05:00 5.00 0 0 MIRU MOVE DMOB P Replacing tires on pit module. Picking up rig mats and herculite. Cleanin ad. 05:00 17:00 12.00 0 0 MIRU MOVE MOB P Line up modules to exit pad, de-energize hiline, move modules from 3H to 1Q. 17:00 18:30 1.50 0 0 MIRU MOVE SFTY . P Safety standup at Drilling Tool House with both crews. 18:30 00:00 5.50 0 0 MIRU MOVE MOB P Move from 1Q to 1Y detour. Move across 1Y pad to ice road detour. Move down ice road to 1Y -Spine road intersection. 2!13/2009 Move from 1 Y -Spine road intersection to 2M pad. Make repairs to moving system as needed. Gave AOGCC, Jeff Jones, 24 hours notice of u comin o erations on 2N-305A. 00:00 05:00 5.00 0 0 MIRU MOVE MOB P Move from 1Y -Spine road intersection to 2B ad. 05:00 08:00 3.00 0 0 MIRU MOVE OTHR P Waiting on field crew change. 08:00 15:30 7.50 0 0 MIRU MOVE MOB T Repair moving system on pit module. 15:30 19:00 3.50 0 0 MIRU MOVE MOB P Move from 26 past 4 corners and halfwa to 2M ad. 19:00 22:00 3.00 0 0 MIRU MOVE MOB T Replace clutch on sub module drive motor. Page 1 of 48 Time Lo s Date From To Dur S. De th E. De th Phase Cod Subcode T Comment 22:00 00:00 2.00 0 0 MIRU MOVE MOB P Move to 2M pad. Stop and allow traffic to ass. 2/14/2009 Move rig to 2N pad and spot sub over well 305. Begin moving camps, shop, parts house and rockwasher from 3H to 2N ad. 00:00 00:45 0.75 0 0 MIRU MOVE MOB P Let traffic pass at 2M pad. 00:45 12:15 11.50 0 0 MIRU MOVE MOB P Move from 2M pad across two bridges to hill before 2L pad. Hock up cats to sub and pull up hill. Move to 2N ad. 12:15 14:00 1.75 0 0 MIRU MOVE PRLO P Prep cellar area for sub. Haul and dump gravel, build up location for stom ers. 14:00 18:45 4.75 0 0 MIRU MOVE PRLO P Spread herculite and lay rig mats 18:45 19:00 0.25 0 0 MIRU MOVE SFTY P PJSM -moving sub onto mats and over well. 19:00 22:15 3.25 0 0 MIRU MOVE MOB P Move sub onto mats and turn 180 de rees. 22:15 23:45 1.50 0 0 MIRU MOVE PRLO P Work with Drill Site Operator to jack up oil and gas lines on adjacent wells to make room for stom er feet. 23:45 00:00 0.25 0 0 MIRU MOVE MOB P Spot sub over well 305. 2/15/2009 Set stomper feet, skid rig floor, Spot pits and rockwasher. Make rig ready for acceptance. Move and spot camps, shop and parts house. Displaced well to seawater, nipple down tree and begin nipple up of BOPE. Crews moving into 2L camps. Rig ready for acceptance at 13:30. Backed up time 15 hours due to CPAI caused delays during move. See toda s time to for details. 00:00 00:15 0.25 0 0 MIRU MOVE SFTY P PJSM -setting and preloading stom er feet. 00:15 00:45 0.50 0 0 MIRU MOVE MOB P Set stomper feet and preload. Turn pit module 90 degrees and prepare to crab onto mats. 00:45 01:00 0.25 0 0 MIRU MOVE SFTY P PJSM -skidding rig floor. 01:00 01:45 0.75 0 0 MIRU MOVE MOB P Skid rig floor into position over well and install hand rails. 01:45 03:30 1.75 0 0 MIRU MOVE MOB P Move pits onto mats and spot next to sub. Install beaver slide. Prep pad for sho and cam s. 03:30 04:00 0.50 0 0 MIRU MOVE MOB P Install roof caps between modules. Spot camps, shop, parts house and on 2N ad. 04:00 06:00 2.00 0 0 MIRU MOVE MOB P Spread herculite for rockwasher. Spot rockwasher next to pits. Berm up around rig. Begin hooking up water, steam air and mud lines between modules. Page Z of 48 r~ ~~ Time i.o s Date From To Dur S. th E. th Phas Gode Subcode T Comment 06:00 13:30 7.50 0 0 MIRU MOVE MOB P Spot cuttings tanks for rockwasher, berm up around rockwasher and rig. Continue hooking up interconnects between modules. Work on rig acceptance checklist. Rig ready for acceptance @ 13:30. Rig acceptance backed up 15 hours due to CPAI caused delays during rig move (6.5 hours for field crew changes and safety stand up at DTH plus 8.5 hrs while rig waited on 2N pad for location to be made ready) i wellview as 13:30 14:15 0.75 0 0 SURFAC RPCOM PULD P Pick up lubricator and crossovers. 14:15 16:00 1.75 0 0 SURFA( RPCOM MPSP P Rig up lubricator and pull BPV. 16:00 17:45 1.75 0 0 SURFA( RPCOM RURD P Rig up lines for displacing well. 17:45 18:00 0.25 0 0 SURFA( RPCOM PRTS P Pressure test lines to 1500 psi. Good test. 18:00 19:30 1.50 0 0 SURFA( RPCOM CIRC P Pump 42 bbls seawater down annulus displacing dielse from tubing. Pump 67 bbls seawater/safe-surf-o down tubing followed b 217 bbls of seawater. 19:30 20:00 0.50 0 0 SURFAC RPCOM CIRC P Shut in and blow down lines. Open annulus and tubing, check for flow, well is dead. 20:00 20:30 0.50 0 0 SURFAC RPCOM RURD P Rig down lines from displacement. 20:30 21:00 0.50 0 0 SURFAC RPCOM MPSP P Set BPV. 21:00 21:30 0.50 0 0 SURFAC RPCOM SFTY P PJSM -nipple down tree and nipple u BOPE. 21:30 23:00 1.50 0 0 SURFAC RPCOM NUND P Nipple down tree and adapter. Clean threads in tubing hanger. Install blanking plug per FMC rep. Cycle u er and lower lock down screws. 23:00 00:00 1.00 0 0 SURFA( RPCOM NUND P Nipple up spool adapter and riser. 2/16/2009 Nipple up BOPE equipment. Pick up 4"drill pipe, HWDP and jars. Test BOPE. Good test. Witnessed by AOGCC Chuck Scheve. Clean out debris from top of hanger and pull hanger to rig floor. Circulated seawater to clean hole. Set and iced in ri mats, run hi-line for sho and cam s across ad. 00:00 05:00 5.00 0 0 SURFAC RPCOM NUND P Nipple up BOP stack, bell nipple, riser, choke & kill lines and flow line. Chan a out saver sub. 05:00 07:15 2.25 0 0 SURFA(' RPCOM RURD P Rig up to pick up 4"drill pipe. 07:15 07:45 0.50 0 0 SURFAI RPCOM NUND P Nipple down riser so it can be shortened to accomodate flush mounts iders. 07:45 11:00 3.25 0 0 SURFA( RPCOM PULD P Pick up 111 joints of 4"drill pipe and 14 'oints of HWDP lus 'ars. 11:00 11:45 0.75 0 0 SURFAC RPCOM NUND P Nipple up shortened riser. Page 3 of 48 r~ Time Lo s Date Fr m To Dur S. De th E. De th Phase ode Subcode T Comment 11:45 13:15 1.50 0 0 SURFA( RPCOM BOPE P Rig up to test BOPE. 13:15 17:00 3.75 0 0 SURFA( RPCOM BOPE P Test BOPE 250 psi low, 3500 psi high. Test annular, top and bottom rans with 3-1/2" test joint. Test 4" XT-39 dart valve and TIW valve. Test upper & lower IBOP, HCR kill, manual kill, blind rams and 18 choke manifold valves. Accumulator drawdown test starting pressure 3000 psi. Function HCR's, top & bottom rams and bag. 34 seconds for 200 psi increase, 3 minutes 17 seconds to full charge. 5 bottle average pressure 2400 psi. Test witnessed by AOGCC Chuck Scheve. 17:00 18:45 1.75 0 0 SURFA( RPCOM BOPE P Rig down test equipment and blow down -ines. 18:45 19:30 0.75 0 0 SURFA( RPCOM MPSP T Attempt to pull BPV. Unable to catch BPV with T-bar due to debris on han er. 19:30 21:15 1.75 0 0 SURFA( RPCOM MPSP T Rig up suction hoses and suck out stack. Attempt to screw into hanger with landing joint. Wash top of hanger with water and compressed air. Screw into hanger with landing ~oint. Back out lock down screws 21:15 21:45 0.50 0 0 SURFA( RPCOM PULL P Pick up 20', 210k on weight indicator and tubing came free. Pull tubing hanger to rig floor. Pull landing joint, Check for pressure in tubing via BPV. Pull BPV. 21:45 22:00 0.25 0 0 SURFA( RPCOM SFTY P PJSM -circulating, laying down han er and com letion tubin . 22:00 22:30 0.50 0 0 SURFA( RPCOM PULL P Make up landing joint to hanger, break off & lay down hanger and landin 'oint. 22:30 23:30 1.00 0 0 SURFA( RPCOM CIRC P Make up head pin and circulate 130 bbls of seawater. Recovered 15 bbls of diesel when be an circulatin . 23:30 00:00 0.50 0 0 SURFA( RPCOM CIRC P Rig down circulating equipment and blow down lines. 2/17/2009 Pull 3-1/2" gas lift completion. Tubing not cut completely, pulled entire completion string from well. Tested BOPE with 4" and 5-1 /2" test joints. Sort used tubing and kick out corroded tubing. Pick up enough new tubin to make scra er run and set cement retainer. 00:00 06:00 6.00 0 0 SURFA( RPCOM PULL P POOH with 3-1 /2" gas lift completion. Removed 80 centralizers from first 40 joints of tubing. Monitoring hole fill via trip tank. PU wt 110k, SO wt 98k. 06:00 12:45 6.75 0 0 SURFA( RPCOM PULL P Continue pulling 3-1/2" tubing. PU wt 90k, SO wt 90k. Casing was not completely cut at 8500', joint # 270. Appear to be pulling complete tubing strip . 12:45 13:45 1.00 0 0 SURFA( RPCOM OWFF T Monitor well -static. Page 4 of 4$ r~ Time t_o s Date From To Dur S. De th E. De th Phase Code Su code T Comment 13:45 15:00 1.25 0 0 SURFA( RPCOM PULL T POOH with 3-1/2" tubing string to seal assembly. Hole took 13 bbls over calculated fill on TOOH. 15:00 15:30 0.50 0 0 SURFA( RPCOM RURD P Rig down GBR handleing tools. 15:30 16:45 1.25 0 0 SURFAc RPCOM BOPE P Set test plug and fill stack with water for BOP test. Rig up test equipment. Pick u MWD tools via beaver slide. 16:45 19:45 3.00 0 0 SURFA( RPCOM BOPE P Test upper and lower rams with 4" test joint and annular preventor and upper rams with 5" test joint. Test manual and HCR chokes. 19:45 20:15 0.50 0 0 SURFA( RPCOM BOPE P Pull testjoint and rig down test equipment. Begin removing corroded tubing from pipe shed. Remaining tubing will be used for scraper run and cement retainer. 20:15 20:45 0.50 0 0 SURFA( RPCOM OTHR T Install wear bushing and run in 2 lock down screws. 20:45 00:00 3.25 0 0 SURFA( RPCOM PULD T Continue unloading corroded tubing from pipe shed. Load shed with enough new tubing to run scraper and cement retainer to TD. Service drawworks. 2/18!2009 Run to bottom of 5-1/2" casing with scraper. No problems during trip in hole. Tagged up on depth. Circulate bottoms u at TD. Pull out of hole with scra er and icked u 5-1/2" cement retainer. 00:00 00:15 0.25 0 0 SURFA( RPCOM SFTY P PJSM -picking up and running in hole with scra er. 00:15 01:15 1.00 0 0 SURFA( RPCOM PULD P Make up scraper and crossovers to 3-1/2" EUE 8rd tubin . 01:15 05:15 4.00 0 0 SURFAC RPCOM TRIP T TIH with scraper with tubing from pipe shed. Monitor displacement via tri tank 05:15 06:45 1.50 0 0 SURFA( RPCOM TRIP T TIH with tubing from derrick. PU wt 100k, SO wt 95k. Monitor dis lacement via tri tank 06:45 07:45 1.00 0 0 SURFA( RPCOM SVRG P Steam and service Upper & Lower IBOP. Service drawworks. 07:45 10:30 2.75 0 0 SURFA( RPCOM TRIP T TIH with tubing from derrick. PU wt 120k, SO wt 100k. Monitor dis lacement via tri tank 10:30 10:45 0.25 0 0 SURFA( RPCOM SFTY T Post JSM -TIH from derrick. Pre JSM -Sin le in hole from i e shed. 10:45 14:00 3.25 0 0 SURFA( RPCOM TRIP T Single in hole with tubing from pipe shed. PU wt 140k, SO wt 103k. Ta ed u on de th. 14:00 15:30 1.50 0 0 SURFA( RPCOM CIRC T Rig up head pin and circulate bottoms up with seawater at 6 bpm, 2390 psi. 2727 units max gas EPOCH on bottoms u . 15:30 15:45 0.25 0 0 SURFA( RPCOM SFTY T PJSM -POOH with tubing. 15:45 22:00 6.25 0 0 SURFA( RPCOM TRIP T POOH with scraper, racking back tubin in derrick. 22:00 23:15 1.25 0 0 SURFA( RPCOM PULD T Lay down scraper and corssovers. 23:15 23:30 0.25 0 0 SURFA( RPCOM SFTY T PJSM -picking up and running cement retainer. Page 5 of 48 r~ • Time Igo s Date From To Dur S. De th E. De th Phase ode Subcode T Comment 23:30 00:00 0.50 0 0 SURFA( RPCOM PULD T Pick up and make up cement retainer for 5-1/2" casin . 2/19/2009 Run 5-1/2" cement retainer on 3-1/2" tubing to 9378' MD. Set retainer and circulate bottoms up. Rig up Dowell and perform injectivity test and pump 10 bbl cement pluca on toy of retainer. Circulate and pull out of hole. Make u 2nd retainer and re to run in hole. 00:00 00:45 0.75 0 0 SURFA( PLUG TRIP T TIH with cement retainer on 3-1/2" tubin from i e shed. 00:45 08:45 8.00 0 0 SURFAt PLUG TRIP T TIH with retainer on 3-1/2" tubing from derrick. PU wt 120k, SO wt 100k. 08:45 09:00 0.25 0 0 SURFA( PLUG RURD T Make up crossover to top drive. 09:00 11:30 2.50 0 0 SURFA( PLUG PLUG T Pick up 2' and rotate 15 turns to the right. Slack off 2'. Plug not set. Reciprocate pipe to work turns down to setting tool. Rotate 10 turns and reciprocate pipe. Slack off, plug set. Pick up 25k overpull (175k) to confirm set. Slack off and set 25k down on tool (80k). Repeat 2 times. Pick up to 147k and make 10 turns to the right. Observed 5k loss in weight. Pick up, packer not released. Work pipe until packer released. Retainer set at 9,328'. 11:30 12:00 0.50 0 0 SURFAt PLUG TRIP T POOH and replace joint with bad collar. Rig up head pin and lines. 5' in to to of lu . 12:00 12:45 0.75 0 0 SURFAt PLUG CIRC T Circulate bottoms up at 4 bpm, 1040 psi. PU wt 145k, SO wt 105k. Max as 1405 units. 12:45 13:00 0.25 0 0 SURFA( PLUG OWFF T Monitor well -static. 13:00 14:15 1.25 0 0 SURFAt PLUG PLUG P Turn over to Dowell to perform injectivity test and set cement plug. Sting into retainer and pressure up to 1000 psi. Hold for 10 minutes. No pressure loss, formation not taking fluid. Sting out of retainer and set 10 bbl cement lu on to of retainer 14:15 15:00 0.75 0 0 SURFA( PLUG TRIP T POOH at 20 fpm. PU wt 140k, SO wt 105k. 15:00 16:15 1.25 0 0 SURFAt PLUG CIRC T Circulate 2+ bottoms up at 6 bpm, 2050 si. Max as 847 units. 16:15 16:30 0.25 0 0 SURFAt PLUG OWFF T Monitor well -static. 16:30 16:45 0.25 0 0 SURFAt PLUG RURD T Rig down head pin and lines, blow down lines. Install stri in rubber. 16:45 17:00 0.25 0 0 SURFA( PLUG SFTY T PJSM -POOH with work string. 17:00 18:30 1.50 0 0 SURFA( PLUG TRIP T POOH with 3-1 /2" tubing and retainer running tool, racking back tubing in derrick. 18:30 22:45 4.25 0 0 SURFA( PLUG TRIP T POOH laying down tubing to pipe shed. 22:45 23:15 0.50 0 0 SURFAt PLUG PULD T Lay down retainer running tool. 23:15 23:30 0.25 0 0 SURFAt PLUG SFTY P PJSM -running 2nd retainer. Page ti of 48 i Time La s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 23:30 00:00 0.50 0 0 SURFA( PLUG PULD P Make up retainer to tubing. 2/20/2009 Pressure test cement plug. Run and set second retainer at 3400' MD. Displace well to mud, lay down work string and pressure test retainer. Cut casing with jet cutter on eline. Attempt to displace annulus to mud, no returns. S ear 5-1/2" casin and ull free. 00:00 00:30 0.50 0 0 SURFAI PLUG PRTS P Pressure test cement plug to 1000 psi. Hold for 15 minutes. Lost about 50 psi during test. No pressure increase observed on 7-5/8" x 5-1/2" annulus. 00:30 00:45 0.25 0 0 SURFA( PLUG PRTS P Rig down test equipment and blow down lines. 00:45 03:00 2.25 0 3,400 SURFAI PLUG PLUG P TIH with cement retainer on 3-1/2" tubing. Pick up single and make top drive connection. PU wt 95k, SO wt 90k. 03:00 03:30 0.50 3,400 3,400 SURFAI PLUG PLUG P Make 15 turns to the right, PU to 25k overpull, SO putting 10k on retainer. Repeat twice to confirm set. make 12 turns to the right and unsling. Sting back in confirm set and depth, 3400' MD. Unstin . 03:30 03:45 0.25 3,400 3,400 SURFA( PLUG SFTY P PJSM -displacing well to LSND mud. 03:45 04:15 0.50 3,400 3,400 SURFAC PLUG CIRC P Displace well to mud at 4 bpm, 460 si. 04:15 04:45 0.50 3,400 3,400 SURFAI PLUG OWFF P Monitor well -static. Rig down circulatin a ui ment. 04:45 09:15 4.50 3,400 3,400 SURFA( PLUG TRIP P POOH laying down tubing to pipe shed. La down retainer runnin tool. 09:15 10:15 1.00 3,400 3,400 SURFA( PLUG PULD P Lay down tubing from derrick 10:15 10:45 0.50 3,400 3,400 SURFA( PLUG RURD P Rig down 3-1 /2 handling equipment and ri u test a ui ment. 10:45 11:15 0.50 3,400 3,400 SURFA( PLUG PRTS P Test casing / retainer to 1000 psi for 30 minutes. No ressure loss. 11:15 12:00 0.75 3,400 3,400 SURFA( PLUG PRTS P Rig down test equipment and blow down lines. 12:00 12:30 0.50 3,400 3,400 SURFA( RPCOM SFTY P PJSM -rigging up and cutting casing with eline. 12:30 15:00 2.50 3,400 3,400 SURFAC RPCOM RURD P Rig up eline and casing jet cutter. 15:00 16:00 1.00 3,400 3,400 SURFAI RPCOM ELOG P RIH with jet cutter on eline, 3370' i WLM. J«~SS ~ `~ ~~l 16:00 17:15 1.25 3,400 3,400 SURFA( RPCOM ELOG P POOH with jet cutter and rig down eline. 17:15 17:30 0.25 3,400 3,400 SURFAC RPCOM SFTY P PJSM -displacing 7-5/8" x 5-1/2" annulus 17:30 19:00 1.50 3,400 3,400 SURFAI RPCOM CIRC P Attempt to displace annulus. Unable to circulate, no returns. Pressured up to 900 psi, pumped away 8 bbps. Shut down, pressure stabilized at 410 psi. Bleed back 4 bbls to trip tank. 19:00 20:00 1.00 3,400 3,400 SURFA( RPCOM RURD P Pull wear bushing. Page 7 of 4$ LS~ r~ ~~ Time Lo s Date From To Dur S. De th E. ~ th Phase Code Subcode T Comment 20:00 21:00 1.00 3,400 3,400 SURFAC RPCOM PULL P Pull packoff. RIH with retrieval tool, close annular preventer, pressure up to 500 psi and back out lock down screws. Bleed off pressure. Casing did not grow. Open annular preventer and ull ackoff. 21:00 22:30 1.50 3,400 3,400 SURFA( RPCOM FISH P Make up spear to fish 5-1 /2" casing. Grapples too large to fit thru hanger. Change out grapples and engage fish. 22:30 23:45 1.25 3,400 3,400 SURFA( RPCOM FISH P Attempt to pull casing free. Work pipe puling to 240k up wt. Increase pull to 270k up wt. Casing not free. Kick on pumps at 2 bpm, 500 psi and work casing. Casing came free at 220k up wt. No returns while um in . 23:45 00:00 0.25 3,400 3,400 SURFA( RPCOM PULD P Lay down double used to spear fish and blow down to drive. 2/21 /2009 Lay down 5-1/2" casing hanger and spear. Attempt to circulate well every 3 joints on trip to surface shoe. Establish circulation once in surface shoe. Circulate out diesel and gas trapped in 7-518" x 5-1/2" annulus. Pull out of hole, fillip i e eve 3 'oints due to hole swabbin . 00:00 00:45 0.75 3,400 3,400 SURFA( RPCOM PULL P Lay down 5-1/2" casing hanger and s ear. 00:45 01:30 0.75 3,400 3,400 SURFA( RPCOM RURD P Rig up 5-1/2" handling equipment. 01:30 01:45 0.25 3,400 3,400 SURFA( RPCOM SFTY P PJSM -POOH with 5-1/2" casing. 01:45 03:30 1.75 3,400 3,400 SURFA( RPCOM PULL P POOH with 5-1/2" casing on elevators. Stop every 3 joints and attempt to circulate. Pressure up to 600 psi spp with no returns. Continue POOH until cut joint abive surface shoe. 03:30 04:30 1.00 3,400 3,400 SURFA( RPCOM CIRC P Break circulation and divert returns thru poor boy degasser sending 50 bbls diesel to rockwasher. Pump 4 b m, 310 si, total of 257 bbls. 04:30 04:45 0.25 3,400 3,400 SURFA( RPCOM OWFF P Monitor well -slight weeping. Mud weight in non-pressurized 9.0 ppg., mud weight out non-pressurized 8.4 ppg. Mud weight pressurized 9.0 04:45 05:45 1.00 3,400 3,400 SURFA( RPCOM CIRC P Circulate 232 bbls, until mud weight out non- ressurized = 8.8 05:45 06:15 0.50 3,400 3,400 SURFA( RPCOM CIRC P Circulate bottoms up taking returns down flow line. 06:15 07:15 1.00 3,400 3,400 SURFA( RPCOM RURD P Rig up for LOT using test pump. 07:15 08:00 0.75 3,400 3,400 SURFA( RPCOM LOT P Perform LOT. Formation broke over at 600 si s , 14.0 EMW. 08:00 08:30 0.50 3,400 3,400 SURFA( RPCOM RURD P Rig down LOT equipment 08:30 10:15 1.75 3,400 3,400 SURFA( RPCOM CIRC P Circulate 40 bbl nut plug sweep at 8 bpm, 520 psi. PU wt 105k, SO wt 105k. Max as 158 units. 10:15 10:30 0.25 3,400 3,400 SURFA( RPCOM OWFF P Monitor well -breathing to static. Page 8 of 48 Time Lo s Date From To Dur S. De th E: De th Phase Code Subcode T Comment 10:30 11:30 1.00 3,400 3,400 SURFA( RPCOM CIRC P Circulate at 8 bpm, 520 psi. PU wt 105k, SO wt 105k. Max gas 157 units. 11:30 12:00 0.50 3,400 3,400 SURFA( RPCOM OWFF P Monitor well -breathing to static. 12:00 12:30 0.50 3,400 3,400 SURFA( RPCOM CIRC P Circulate at 7.5 bpm, 460 psi. PU wt 105k, SO wt 105k. Max gas 122 units. 12:30 13:00 0.50 3,400 3,400 SURFA( RPCOM OWFF P Monitor well -breathing to static. 13:00 13:15 0.25 3,400 3,400 SURFA( RPCOM PULL P POOH with 3 joints, hole swabbing. 13:15 14:00 0.75 3,400 3,400 SURFA( RPCOM CIRC P Circulate at 8 bpm, 520 psi. PU wt 105k, SO wt 100k. Max gas 194 units. 14:00 14:15 0.25 3,400 3,400 SURFAC RPCOM OWFF P Monitor well -breathing to static. 14:15 15:00 0.75 3,400 3,400 SURFA( RPCOM CIRC P Circulate at 8 bpm, 500 psi. PU wt 105k, SO wt 100k. Max gas 156 units. 15:00 15:15 0.25 3,400 3,400 SURFA( RPCOM OWFF P Monitor well -static 15:15 15:30 0.25 3,400 3,400 SURFA( RPCOM PULL P POOH with 3 joints, hole swabbing. 15:30 16:00 0.50 3,400 3,400 SURFA( RPCOM OWFF P Monitor well -static 16:00 17:15 1.25 3,400 3,400 SURFA( RPCOM PULL P POOH with 6 joints, hole swabbing. Fill hole. Monitor well -static 17:15 17:30 0.25 3,400 3,400 SURFA( RPCOM CIRC P CBU at 8 bpm, 500 psi. PU wt 105k, SO wt 100k. Max as 183 units. 17:30 18:00 0.50 3,400 3,400 SURFA( RPCOM PULL P POOH with 3 joints, hole swabbing. Fill hole. 18:00 00:00 6.00 3,400 3,400 SURFA( RPCOM PULL P POOH. Fill hole, calculate fill volume eve 3 'oints Burin tri out of hole. 2/22/2009 Pulled out of hole with 5-1/2" casing. Test annular preventer, good test. Made cleanout run to top of 5-1/2" casing stub. Backreamed to surface casing shoe. Began singling in hole with 2-7/8" tubing /cement stinger for settin lu . 00:00 01:15 1.25 3,400 3,400 SURFA( RPCOM PULL P POOH with 5-1/2" casing. Fill hole, calculate fill volume every 3 joints during trip out of hole. Pulled total of 78 joints, plus hanger and 9.71' cut off joint. Hole took 7.8 bbls more than calculated hole fill over tri . 01:15 01:30 0.25 3,400 3,400 SURFA( RPCOM OWFF P Monitor well -static 01:30 02:00 0.50 3,400 3,400 SURFA( RPCOM RURD P Rig down 5-1/2" handling equipment. Blow down lines. 02:00 03:30 1.50 3,400 3,400 SURFAC RPCOM BOPE P Rig up and test annular preventer (250 psi low, 3500 psi high) with 3-1/2", & 5-1 /2" test joints. Good test. Ri down test a ui ment. 03:30 04:00 0.50 3,400 3,400 SURFA( RPCOM OTHR P Install wear bushing and run in 2 lock down screws. 04:00 04:15 0.25 3,400 3,400 SURFA( RPCOM SFTY P PJSM -picking up and running in hole with cleanout assembl . 04:15 05:00 0.75 3,400 3,400 SURFA( RPCOM PULD P Pick up cleanout BHA per DD. Monitorin hole via tri tank. Page 9 of 48 :Time Lo s Dat From T Dur S. De th E. De th Phase Code Subcode T Comment 05:00 06:15 1.25 3,400 3,400 SURFA( RPCOM TRIP P TIH with cleanout assembly on 4" drill pipe to surface casing shoe. Fill pipe at 2300'. PU wt 115k SO wt 108k 06:15 07:15 1.00 3,400 3,400 SURFA( RPCOM CIRC P Circulate bottoms up pumping 9 bpm, 460 psi. Max Epoch gas 460 units. 07:15 07:30 0.25 3,400 3,400 SURFA( RPCOM OWFF P Monitor well -static 07:30 10:30 3.00 3,400 3,400 SURFA( RPCOM WASH P Wash in hole pumping 8 bpm, 520 psi. rotating 35 rpm to 3358' MD. Packed off and pressured up to 1300 psi. POOH to 3235' MD. Max EPOCH as 500 units. 10:30 11:00 0.50 3,400 3,400 SURFA( RPCOM CIRC P Circulate bottoms up pumping 8 bpm, 520 psi. PU wt 120k, SO wt 110k, rotating wt 110k. Max EPOCH as 2300 units. 11:00 13:00 2.00 3,400 3,400 SURFA( RPCOM WASH P Wash in hole pumping 8 bpm, 470 psi. rotating 35 rpm. PU wt 120k, SO wt 110k, rotatin wt 110k. 13:00 14:15 1.25 3,400 3,400 SURFA( RPCOM REAM P BROOH pumping 8 bpm, 460 psi. rotating 35 rpm. PU wt 125k, SO wt 108k, rotatin wt 105k. 14:15 14:45 0.50 3,400 3,400 SURFA( RPCOM CIRC P Circulate bottoms up pumping 8 bpm, 510 psi. PU wt 115k, SO wt 108k. Max EPOCH as 300 units. 14:45 15:15 0.50 3,400 3,400 SURFA( RPCOM OWFF P Monitor well -static. Blow down top drive. 15:15 16:30 1.25 3,400 3,400 SURFA( RPCOM LOT P Rig up and perform LOT. Calcuted 13.7 EMW. 16:30 17:15 0.75 3,400 3,400 SURFA( RPCOM TRIP P TIH and tagged up on 5-1 /2" casing stub at 3374'MD. Continue in hole until wash pipe 10' inside 5-1 /2" casin stub 17:15 19:15 2.00 3,400 3,400 SURFA( RPCOM CIRC P Circulate hole pumping 8 bpm, 450 psi, reciprocating string 60'. PU wt 120k, SO wt 110k. Max EPOCH gas 126 units. 19:15 19:30 0.25 3,400 3,400 SURFA( RPCOM OWFF P Monitor well -static 19:30 19:45 0.25 3,400 3,400 SURFAC RPCOM TRIP P POOH on elevators to surface casing shoe. 19:45 20:00 0.25 3,400 3,400 SURFA( RPCOM OWFF P Monitor wel- -static. Pump 20 bbl d ~ob. 20:00 21:00 1.00 3,400 3,400 SURFA( RPCOM TRIP P POOH on elevators to BHA. Monitorin hole fill via tri tank. 21:00 22:00 1.00 3,400 3,400 SURFA( RPCOM TRIP P POOH with BHA, racking back HWDP and jars. Hole took 5 bbls over calculated Burin tri . 22:00 23:00 1.00 3,400 3,400 SURFA( RPCOM PULD P Clear rig floor and rig up GBR 2-7/8" handlin tools. 23:00 23:15 0.25 3,400 3,400 SURFA( CEMEN' SFTY P PJSM -picking up 2-7/8" cement stin er and runnin in hole. 23:15 00:00 0.75 3,400 3,400 SURFA( CEMEN' TRIP P Single in hole with 2-7/8" cement stinger monitoring displacement via tri tank. Rage 1 Q of 4$ Time Lo s Date From To Dur S. De th E. De th Phase Code Subc e T Comment 2/23!2009 za hr Summary Ran in hole with 2-7/8" cement stinger on 4" drill pipe. Circulated hole and pumped 28 bbl cement plug. Pulled out of plug and circulated out excess cement. Layed down cement stinger and rigged up slickline. made 'unk basket run and cali ed run in 7-5/8" surface casin . 00:00 00:45 0.75 3,400 3,400 SURFA( CEMEN" TRIP P Single in hole with 2-7/8" cement stin er. from i e shed. 00:45 01:00 0.25 3,400 3,400 SURFA( CEMEN" RURD P Rig down 2-7/8" handleing equipment and ri u 4"drill i e tools. 01:00 03:30 2.50 3,400 3,400 SURFA( CEMEN" TRIP P make up cross overs to 4" drill pipe and single in hole with drill pipe from shed. 03:30 04:00 0.50 3,400 3,400 SURFA( CEMEN' CIRC P Circulate bottoms up at surface casing shoe pumping 7 bpm, 390 si. Max E och as 112 units. 04:00 04:30 0.50 3,400 3,400 SURFA( CEMEN" TRIP T POOH and rack back 10 stands while waiting on cementers. 1st batch of cement mix went off early Dowell turned trucks around to unload, remix and reload. 04:30 05:00 0.50 3,400 3,400 SURFA( CEMEN" TRIP T Single in hole 10 stands while waitin on cementers. 05:00 05:30 0.50 3,400 3,400 SURFA( CEMEN" TRIP T POOH and rack back 10 stands while waitin on cementers. 05:30 06:15 0.75 3,400 3,400 SURFA( CEMEN" TRIP T Single in hole 10 stands while waitin on cementers. 06:15 06:45 0.50 3,400 3,400 SURFA( CEMEN" CIRC P Circulate bottoms up at surface casing shoe pumping 8 bpm, 450 si. 06:45 07:30 0.75 3,400 3,400 SURFA( CEMEN" OWFF P Monitor well -static. Blow down top drive. Pre for cement 'ob. 07:30 08:15 0.75 3,400 3,400 SURFA( CEMEN" TRIP P TIH on elevators and tag casing stub. 08:15 09:45 1.50 3,400 3,400 SURFA( CEMEN" CIRC P Circulate bottoms up and continue circulating while rigging up for cement 'ob. 09:45 10:15 0.50 3,400 3,400 SURFA( CEMEN" SFTY P PJSM -setting cement plug. 10:15 10:45 0.50 3,400 3,400 SURFA( CEMEN" PLUG P Set cement plug in open hole and up into surface casing. Pressure test lines to 3000 psi. Dowell pumped 18 bbls mud push, 28 bbls cement, 5 bbls mud push and displaced with 20 bbls of mud. Held 200 psi of backpressure using annular preventer while pumping and displacing cement. 10:45 11:15 0.50 3,400 3,400 SURFA( CEMEN" TRIP P Pull stinger out of cement at 20 fpm. Washin u and blowin down lines. 11:15 12:45 1.50 3,400 3,400 SURFA( CEMEN" CIRC P Circulate out mud push and excess cement. Approximately 3 bbls of cement back to surface. Pumped 6 b m, 400 si. 12:45 13:15 0.50 3,400 3,400 SURFA( CEMEN" TRIP P POOH on elevators. 13:15 14:00 0.75 3,400 3,400 SURFA( CEMEN" CIRC P Flush stack and lines, function bag and rams. Blow down lines. 14:00 14:30 0.50 3,400 3,400 SURFA( CEMEN" TRIP P POOH with 4"drill pipe. Page 11 of 48 r 1 Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 14:30 15:00 0.50 3,400 3,400 SURFA( CEMEN" RURD P Rig down 4" handleing equipment and ri u 2-7/8". 15:00 15:15 0.25 3,400 3,400 SURFA( CEMEN" SFTY P PJSM -laying down 2-7/8" cement stin er. 15:15 17:00 1.75 3,400 3,400 SURFA( CEMEN' TRIP P POOH and lay down 2-718" tubing. 17:00 18:30 1.50 3,400 3,400 SURFA( EVALWE RURD X Rig up Halliburton slickline for caliper to in . 18:30 20:15 1.75 3,400 3,400 SURFA( EVALWE SLKL X RIH with junk basket on slickline. Worked basket down to 2600' SLM. POOH. Dumped cement from basket. 20:15 21:30 1.25 3,400 3,400 SURFAI EVALWE SLKL X Lay down junk basket and pick up call er tools. 21:30 00:00 2.50 3,400 3,400 SURFA( EVALWE SLKL X RIH with caliper on slickline. Log while POOH. First run bad, rerun. TD 2900'SLM. 2/24/2009 Finish caliper log, RlD, change lower rams to 3-1 /2" x 6" variables, test with 3-1 /2", 4" and 5-112" test joints to 250 and 3500 psi, set wear bushing, PU/MU drilling assembly, upload MWD, continue with BHA to 648', shallow pulse test, PU 51 joints of 4" dp from pipe shed, trip into 2917', service rig, PJSM, slip and cut drilling line, test the 7-5/8" surface casing to 1200 psi f/ 30 min (lost 80 psi in 30 minutes), R/D ewipment, trip in to top of cement @ 2925', drill cement to 3130', kick of point 3130', directional drill to 3185', CBU, POOH to 3010', perform LOT to 14.2 ppg EMW, R/D equipment, drop ball to activate Smith 7-1/2" Rhino Reamer, Ream to 3185', POOH to 3145', perform PWD baseline test, directional drill with 6-3/4" bit, GeoPilot and 7-1/2" Rhino Reamer to 3457'. 00:00 00:30 0.50 3,400 3,400 SURFA( EVALWE SLKL X RIH with caliper on slickline. Log while POOH. First run bad, rerun. TD 2900' SLM. 00:30 00:45 0.25 3,400 3,400 SURFA( EVALWE SLKL X Rig down and release slickline. 00:45 01:15 0.50 3,400 3,400 SURFA( DRILL OTHR P Pull wear bushing. Install test plug. 01:15 02:00 0.75 3,400 3,400 SURFAI DRILL BOPE P Change lower pipe rams from 2-7/8" x 5" variables to 3-1 /2" x 6" variables. 02:00 02:30 0.50 3,400 3,400 SURFA( DRILL BOPE P Rig up testing equipment. 02:30 03:30 1.00 3,400 3,400 SURFA( DRILL BOPE P Test lower pipe rams to 250 psi low and 3500 psi high. Hold each test 5 minutes. Chart test. Tested with 3-1/2", 4", and 5-1/2" test'oints. 03:30 03:45 0.25 3,400 3,400 SURFA( DRILL BOPE P Rig down testing equipment. Set wear bushing (10-11/16" OD x 7-13/16" ID 03:45 06:00 2.25 3,400 3,400 SURFAC DRILL PULD P Pickup drilling assembly. 06:00 07:00 1.00 3,400 3,400 SURFA( DRILL PULD P Upload Sperry Sun MWD. 07:00 07:45 0.75 3,400 3,400 SURFA( DRILL PULD P Continue to pick up BHA. 07:45 08:00 0.25 3,400 3,400 SURFA( DRILL DHEO P Shallow pulse test MWD tools. Pumping 280 gpm w/ 930 psi-29% flow out. Rotate 15 rpm w/ 1 k ft Ibs of for ue. Good test. 08:00 09:00 1.00 3,400 3,400 SURFA( DRILL TRIP P Trip in the hole w/ 51 jts of 4" drill pipe from the pipe shed. Monitor dis lacement on the tri tank. Page 12 of 48 r~ Time t_o s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 09:00 09:30 0.50 3,400 3,400 SURFA( DRILL TRIP P Trip in the hole w/ 4"drill pipe from the derrick. Monitor displacment on the trip tank. Fill pipe. Break in seals on the geoPilot, pumping 280 gpm w/ 1130 psi-29% flow out. Rotate 20 r m w/ 2k ft Ibs of for ue. 09:30 10:00 0.50 3,400 3,400 SURFA( DRILL SVRG P Service rig. 10:00 10:15 0.25 3,400 3,400 SURFA( DRILL SFTY P Pre job safety meeting on slip and cuttin drillin line. 10:15 11:30 1.25 3,400 3,400 SURFAC DRILL SVRG P Slip and cut 90' of 1-3/8"drilling line. Ins ect brakes on the drawworks. 11:30 12:00 0.50 3,400 2,917 SURFA( DRILL RURD P Rig up to test the 7-5/8" casing @ 2917'. 12:00 12:45 0.75 3,400 2,917 SURFA( DRILL PRTS P Test the 7-5/8" casing to 1200 psi. Bleed off 80 pis in 30 minutes. Rig down testin a ui ment. 12:45 13:00 0.25 3,400 3,130 SURFA( DRILL TRIP P Trip in to 2925'. 13:00 15:00 2.00 3,130 3,130 SURFAC DRILL WASH P Rotate and wash in the hole from 2925' to 3130' (drilling cement). Pumping 290 gpm w/ 1300 psi-30% flow out. Rotate 90 rpm w/ 3k ft Ibs of torque. PU wt 130k, SO wt 100k, Rotatin wt 118k. 15:00 16:15 1.25 3,130 3,185 SURFAC CEMEN" DRLG P Kick off point is 3130'. Directional drill from 3130' to 3185'. WOB 10k, 70 rpm w/ 4-5k ft Ibs of ~- "3 ®5 ~ ~ ~ - ~~ torque.Pumping 270 gpm w/ 1230 psi-29% flow out. PU wt 130k, SO wt 100k, Rot wt 118k. Total hrs on bit 1.2 hrs, jar hours 9.49. Max gas observed b EPOCH 442 units. 16:15 16:45 0.50 3,185 3,185 SURFAC DRILL CIRC P Circulate. Rotate and recip from 3185' to 3125'. Pumping 265 gpm w/ 1150 psi-29% flow out. Rotate 70 rpm w/ 4k ft Ibs of torque. Circulated 132 bbls. 16:45 17:00 0.25 3,185 3,185 SURFAC DRILL TRIP P Pull out of the hole to 3010' (Inside of 7-5/8" casin 17:00 17:30 0.50 3,185 3,185 SURFAC DRILL RURD P Rig up to perform LOT. 17:30 17:45 0.25 3,185 3,185 SURFA( DRILL LOT P Perform LOT to 14.2 ppg EMW. 17:45 18:30 0.75 3,185 3,185 SURFA( DRILL RURD P Rig down equipment and blow down lines. 18:30 18:45 0.25 3,185 3,185 INTRMI DRILL CIRC P Drop ball to activate Rhino Reamer. Pressure up to 2500 psi, shear ball seat. 18:45 19:00 0.25 3,185 3,185 INTRM1 DRILL REAM P Ream to bottom. Pumping 275 gpm w/ 1050 psi-30% flow out. Rotate 90 rpm w/ 4k ft Ibs of torque. PU wt 125k, SO wt 103k, Rot wt 110k. 19:00 19:30 0.50 3,185 3,145 INTRM1 DRILL TRIP P Pull out of the hole to 3145'. Perform PWD baseline test. Pumping 250 psi, 280 psi and 310 psi. Rotate 70 rpm, 80 rpm and 90 rpm at each flow rate. Clean hole ECD's with 9.3MW is a 9.98 Page 13 of 48 f/V~~~ L~ yP T "I~.4/U~~1 /1/"AL ProActive Diagnostic Services, Iac. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax (907) 2458952 1) Correlation Log 23-Fetr09 2N-305 EDE 50-103-20349-00 2) ~~ \~' 6 . l '..- f :'.i ~~--. .~ 1 Signed : e ,~~~~ s" ...~ .fit -" ~- ~a , '1 ~~ .ca E '~ "fin{} Date : ~'~~~,~~ ~ ~u~, Print Name: _ , PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99618 PHONE: (907j246-8961 FAx: (907 j2a5-88952 E-MAIL: Gt~s~fi3Ci3{33'3~~7Ja~~~:3°r3~~,~as:a WEBSITE:xu~nnv.~~~at°r1a€~.Y~ ` ~ l C:lDocumen~and5ettings\Om~er\Desktop\Transmit Conoco.docx WELL LOG a y_ S TRANSNI/TTAL ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907 659-5102 RE : Cased Hole/Open Hale/Mechanical Logs and/or Tubing Inspection(Caliper/ MTTJ The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax (907) 245.8952 1 j Caliper Report 23-Fet}09 2N-305 1 Report/ EDE 50-103-20349-00 2j Jam" ~/1 / _' J~- ~` `~a ~?.~'µ~,A~~ 'q , 1 Y! !^:~` ~_ F~_ ~ ~ S,r a OU - ~ ~ ~f l(J ~.. L. .~ __ ~ ~ ; a -_ Signed : Date . - ; ' ~ ~ ~;? Print Name: PROACTIVE DIAGNOSTIC SERVE:ES, INC., 130 W. INTERNATIONAL AIRPORT RD SURE C, ANCHORAGE, AK 99518 •~~ ~~ PHONE: (907)245-8951 FAX: (907)2~4Q5.88952 E-MAIL: ~J'[T~J~9~L31~9~caC{1.1/~~.3~+~4~13y.r'~9:! WEW~E:'1V~°~'%Y,i31~~15~9''Ii~L~.{.13~ ~~ C:\Documen& artd Settings\Oamex\Desktop\1Yansmit_Conoco.docx • Memory Multi-finger Caliper ,. LQg Results summary Company: ConocoPhillips Alaska, Inc. Well: 2N,305 Log Date: February 23, 2009 Field: Kuparuk ~ ~ Log No.: 10540 State: Alaska '~ Run No.: 3 APl No.: 50-103-20349-00 '~ Pipet Desc.: 7.625" 29.7 tb. L-80 BTCM Top Log Intvl1.: Surface Pipet Use: Surface Casing Bot. Log Intv11.: 2,$95 Ft. (MD) Inspection Type : Corrosive and Mechanical Damage Inspection ' COMMENTS This caliper data is zeroed at the Rig Floor. This log was run to assess the condition of the 7.625" surface casing with respect to internal corrosive and mechanical damage. The caliper recordings indicate the 7.625" surtace casing logged is in good condition with respect to internal corrosive and mechanical damage, with no significant wall penetrations or areas of ' cross-sectional wa11 loss recorded. Deposits restrict the LD.to 5.50" in joint 63 (2,698'}. A graph illustrating minimum recorded diameters on a joint by joint basis of the 7.625" surface casing logged is included in this report. ' The caliper recordings indicate buckling from -350` to --1,080', with some slight bending recorded intermittently throughout this interval. A lot plot of the surface casing togged is included in this report, with both centered and off-center image maps presented to highlight the buckled interval. MAXIMUM RECORDED WALL PENETRATIONS : No significant wall penetrations (> 18%) are recorded throughout the casing logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS Na significant areas of cross-sectional wall loss (> 10%) are recorded throughout the casing logged. MAXIMUM RECORDED ID RESTRICTIONS Deposits Minimum I.D. = 5.50" Jt. 63 ~ 2,698 Ft. (MD) Deposits Minimum I.D. = 5.56" Jt. 66 C~ 2,856 Ft. (MD) Deposits Minimum I.D. = 5.56" Jt. 67 ~ 2,878 Ft. (MD) Deposits Minimum LD. = 5.63" Jt. 64 ~ 2,742 Ft. (MD) Deposits Minimum I.D. = 5,66" Jt. 65 ~ 2,828 Ft. (MD} ,~~\ a~P-5.1~~}~C w~k...:~i ~r' /~14- k; ''Y, ~VV~ Field Engineer: G. E(•hen`on Analyst: M. Lawrence/C. Waldrop Witness: F. Herbert/S. Lapine ProActh~e Diagnostic Services, Inc. j P.Q. Box 1309, Stafford, T;i 77497 Phone: {281) or {888) 565-9085 Fax: (2$1) 565-1309 E-mail: PDS~memorylog.cam Prudhoe bay Field Office Phone: (907) 659-230? Fax; {90?) 659-2314 ~~- (3S !'3- (03~ • .~~ PDS Multifinger Caliper 3D Log Plot ' Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2N-305 Date : February 23, 2009 Description : Detail of Caliper Recordings Across 7.625" Surface Casing 2~0° o°I i • t 19 J i o n Joint 20 Bucklin g 900 ~ Joint 21 _ +~ Buckling ~ J i t 22 o n Bend 1000 Joint 23 Slight Bend Joint 23.1 , Joint 24 ~, = Slight Bend 1100 _ - ` - Joint 25 Joint 26 Joint 27 1200 Joint 28 Joint 29 A Joint 30 1300 ..., Joint 31 " ~~ i'}, ..:4`~~ 1400 I ~ ~ Joint 32 ~, _ Joint 33 Joint 3a 1500 _~ Joint 35 s = Joint 36 Joint 37 1600 Joint 38 0 Joint 39 17 0 Joint 40 Joint 41 1800 Joint 42 Joint 43 Joint 44 1900 '; ~ - t. • Joint 45 ~, 2000 Joint 46 F ~T- .. Joint 47 Joint 48 2100 ~ Joint 49 Joint 50 0. Joint 51 2200 Joint 52 ~ i t 53 J 2300 o n Joint 54 F- #i i Joint 55 2400 Joint 56 s Joint 57 2500 Joint 58 Joint 59 Joint so 2600 Joint 61 Joint 62 ~-' J t 63 i 2700 o n _ . _ ,j~ Joint 64 ~ J i t 65 2800 o n ;~:- Joint 66 f ! _ . -++~, "` Joint 67 t +~ ~;, Nominal I.DJO.D. 5800 7800 Min I.D. (1!1000 in.) 5800 7800 Comments Depth Max I.D. (1/1000 in.) Image Map (Off-Center) Image Map (Re-Centered) 1ft:1500ft 5800 7800 0° 90° 18p° 270° 0° 0° 90° 180° ' 270' 0' • • ~~ Minimum Diameter Profile Well: 2N-30S Survey Date: February 23, 2009 field: Kuparuk Tool: UW MfC 40 fxt No. 213121 Company: ConocoPhillips Ahaska, Inc. Tool Size: 2.75 inches Country: USA Tubing LD.: 6.875 inches Minimum Measured Diameters (In.) 2.75 3.25 3.75 4.25 4.75 5.25 5.75 6.25 6.75 0.1 2 4 6 8 10 12 14 16 18 20 22 13.1 25 27 29 r 31 Z 33 ~. c 35 .$ 37 39 41 43 45 47 49 51 53 55 57 59 67 63 65 67 Correlation of Recorded Damag Pipe 1 7.625 in (42.0' - 2868.4') Well: Field: Company: Country: Survey Date: • ;e to Borehole Profile 2 N-305 Kuparuk ConocoPhillips Alaska, Inc. USA February 23, 2009 ^ A pprox. Tool De viation ^ A pprox. Borehol e Profil e I 45 5 218 10 431 15 647 2O 861 25 1078 - ~ ~ 30 1294 '-" C C lL 7 C 35 1510 a 'o w 40 1725 45 1940 5(1 2154 5 i 2361 60 2569 (i 5 2 784 67 2868 0 50 1 00 Da mage Pr ofile (°I ° wall) /Tool D eviatio n (degr ees) Bottom of Survey = 67 • PDS Report Overview ~, ~. Body Region Analysis Well: 2 N-305 Survey Date: February 23, 2009 Field: Kuparuk Tool Type: UW MFC 40 Ext No. 213121 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Anal st: C Waldro Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 7.625 ins 29.7 f L-80 BTCM 6.875 ins 7.625 ins 6.0 ins 6.0 ins Penetration and Metal loss (% wall) ~ penetration body $..~ metal loss body 80 60 40 20 0 0 to 1 to 10 to 1% 10`% 20% 20 to 40 to over 40% 85% 85% Number of ~oints anal se d total = 69 pene. 2 21 46 loss 9 60 0 0 0 0 0 0 0 Damage Configuration (body ) 10 0 isolated general line ring hole /puss pirong corrosion corrosion conosion ible hole Number of 'oints dama ed total = 2 1 1 0 0 0 Damage Profile (°k wall) ~ penetration body metal loss body 0 50 100 0 20 39 59 Bottom of Survey = 67 Analysis Clverview page 2 • PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset W aIL ~y Y Page 1 Well: 2 N-305 f L-80 BTCM Kuparuk 7.625 in 29.7 PP Field: ConocoPhillips Alaska, Inc. 0.375 in Company: USA 0.375 in Country: February 23, 2009 ~ st75 in Survey Date: • PDS REPORT JOINT TABI, Pipe: 7.625 in 29.7 ppf L-80 BTCM Well: Body Wall: 0.375 in Field: Upset Wall: 0.375 in Company: Nominal I.D.: 6.875 in Country: Survey Date: • iLATION SHEET 2 N-305 Kuparuk ConocoPhillips Alaska, Inc USA February 23, 2009 Joint No. Jt. Depth (Ft.) I'~>n. Ut~set Iln~.) Pen. Body (Ins.) I'~~n. % ~~~i,~l I os~ `% Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 49 211 t ~ 0.06 17 ~ 6.8 50 2 54 t 1. u S 0.06 t t~ a 6. 51 2196 tt.u5 0.0 1 ~ t, 6.84 52 2238 t~.tu, 0.07 1 ti - 6.82 5 279 U.U 0.0 1, 6.82 54 3 (LU6 0.07 1 ti ~; 6.$0 5 23 1 t~.(u~ 0.06 1E~ t, 6.81 56 2404 t~.(17 0.07 lEi tt 6.83 l~ 0.0 1 G ~ 6.83 58 483 u.~)~ 0.06 1 G ~ 6 87 59 2526 U 0.06 15 t~ 6.84 60 569 t ~ 0.06 15 ~ 6.83 61 2612 U.Ub 0.0 17 7 6.84 62 2655 U 0. 6 16 4 6.78 Lt De sits 63 697 u.22 0.07 1 £3 ~ 5.49 D its. 64 741 U.12 0.07 I £f 5 5 6 e sits. 65 2784 t) 0.06 15 5.66 e osits. 6 8 U 0. 6 15 6 5.5 e sits. 67 2868 (~ 0 U ti 5.56 De sit . ~,Penetralion Body Metal Loss Body Page 2 PDS Report Cross Sections 4 Well: 2N-305 Survey Date: February 23, 2009 Field: Kuparuk Tool Type: UW MFC 40 Ext No. 213121 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of fingers: 40 Tubin 7.625 ins 29.7 f L-80 BTCM Anal st: C. Waldro Cross Section for Joint 63 at depth 2698.48 ft Tool speed = 44 Nominal ID = 6.875 Nominal OD = 7.625 Remaining wall area = 97 Tool deviation = 77 ° Finger 33 Projection = •1.32 ins Deposits Minimum I.D. = 5.50 ins HIGH SIDE = UP ~~ • Cross Sections page 2 ~ ~ ~ ~ i ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~1u M ~~ , PDS Report Cross Sections Well: 2N-305 Survey Date: February 23, 2009 Field: Kuparuk Tool Type: UW MFC 40 Ext No. 213121 Company: ConocoPhillips Alaska, Inc. Tool Size:L.75 Country: USA No. of Fingers: 40 Tubing: 7.625 ins 29.7 ppf L-80 BTCM Analyst: C. Waldrop Cross Section for Joint 66 at depth 2855.863 ft Tool speed = 43 Nominal ID = 6.875 Nominal OD = 7.625 Remaining wall area = 98 Tool deviation = 77 ° Finger 21 Projection = -1.319 ins Deposits Minimum I.D. = 5.56 ins HIGH SIDE = UP Cross Sections page 3 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Oas Lift arMreVDianmy Vah~e 1 (2775-2716, OD:4.725) Gas Lift andrellDummy Valve 2 (5899-5900, OD:4.725) Gas Lift andreVDunmy Valve 3 (8001-8002, OD:4.725) TUBING (0-9395, OD:3.500, ID:2.992) PROD CASING (0-9383, OD:5.500, Wt:15.50) Gas Lift ardreYDummy Valle 4 (9331-9332, OD:4.725) NIP (93749375, OD:3.500) PLUG (93749375, OD:2.750) SEAL (9383-9384, OD:4.000) GUDE (9395-9396, OD:3.500) FRAC (97249734) Perf (97249734) PROD CASING (9383-10328, OD:3.500, ConocoPhillips Alaska, Inc. KRU 2N-305 2N-305 API: 501032034 900 Well T : PROD An le TS: d SSSV T : NIPPLE Or' Com letion: 10/7!2000 An le TD: 60 d 10334 Annular Fluid: Last W/0: Rev Reason: TAG, PULL PUMP, Set PLUG, LEAK FOUND Reference L Ref L Date: Last U ate: 5/17/2007 Last Ta : 9734' TD: 10334 ftK6 Last Ta Date: 4/2412007 Max Hole An le: 68 de 6396 Casin Strin -ALL S TRINGS Descri tion Size To Bottom TVD VYt O rade Thread CONDUCTOR 16.000 0 118 118 62.50 H-40 WELDED SURF CASING 7.625 0 3025 2296 29.70 L-80 BTCM PROD CASING 5.500 0 9383 5210 15.50 L-80 BTC MOD PROD CASING 3.500 9383 10328 5679 9.30 L-80 8RD EUE Tubin Strin -TUBI NG Size To Bottom TVD Wt C3rade Thread 3.500 0 9395 5215 9.30 L-80 SRD EUE Pertorations Summa Interval TVD Zone Status Ft SPF Date T Comment 9724 - 9734 5372 - 5377 10 4 10/15/2 000 IPERF 2-1l2" HSD 180 d h Stimulations 8 Treat ments Interval Date T Comment 9724 - 9734 10/18/2000 FRAC PUT 170 MLBS IN FORMATION. Gas Lift MandrelsNal ves St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 2715 2152 CAMCO KBG 2-9 CAMCO DMY 1.0 DCK 0.000 0 10/7/2000 2 5899 3614 CAMCO KBG 2-9 CAMCO DMY 1.0 DCK 0.000 0 10/7/2000 3 8001 4571 CAMCO KBG 2-9 CAMCO DMY 1.0 DCK 0.000 0 10f7l2000 4 9331 5186 CAMCO KBG 2-9 CAMCO DMY 1.0 DCK 0.000 0 0/25/2001 Other l u s ui ., etc. -COMPLETI ON De th TVD T e Descri tion ID 507 506 NIP CAMCO'DS' NIPPLE 2.875 9290 5168 SLEEVE-0 BAKER CMU SLEEVE - O ned 2/25/2002 2.813 9374 5206 PLUG CA-2 BLANKING PLUG set 4/28/2007 0.000 9374 5206 NIP CAMCO'D' NIPPLE NO-GO 2.750 9375 5206 LOCATOR BAKER 5.125" OD LOCATOR 2.985 9383 5210 SEAL BAKER 80.40 CSG SEAL ASSY~ 5.5" x 4" 2.985 9395 5215 GUIDE BAKER TT RE-ENTRY GUIDE 0.000 General Not es Date Note 428/2007 NOTE: LEAK DETECTED BETWEEN 7666'-7868' RKB From: Ennis, J J [J.J.Ennis@conocophillips.com] Sent: Wednesday, February 11, 2009 10:46 AM To: Maunder, Thomas E (DOA) Cc: NSK Problem Well Supv; Schwartz, Guy L Subject: RE: 2N-305 P&A sundry# 308-450, PTD#200-135 Attachments: 20090211121317 001.PDF Tom. Interesting is certainly one adjective that could be used in this situation. l suspect this is a case of a standard procedure not getting modified for differing well conditions. I've attached the WSR from the CT cementing job to provide the requested squeeze specifics. Following our phone conversation yesterday afternoon, slickline found the SITP to still be 500 psi, tagged the TOC @ 9158' RKB and successfully bled the well to zero. Eline then cut the tbg @ 8490` RKB last evening and saw no well pressure during the job; confirming we have a competent cement plug. Please let me know if any questions or concerns. Thanks for your help in this matter. Jim Ennis j j.ennis@conocophillips.com (907)265-1544 (VV) (907)632-7281 (C) From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, February 10, 2009 2:18 PM To: Ennis, J J Cc: NSK Problem Well Supv; Schwartz, Guy L Subject: RE: 2N-305 P&A sundry# 308-450, PTD#200-135 Jim, (t appears the leaks have been known about for some time. It is interesting that the pressure test would be proposed with that knowledge. Gan you provide specifics regarding the squeeze? That information and the tag should confirm the deep plug. I agree that it is unlikely that an applied pressure will hold given the well's history. I look forward to your reply. Tom Maunder, PE AOGCC From: Ennis, J J [mailto:J.J.Ennis@conocophillips.com] Sent: Tuesday, February 10, 2009 12:07 PM To: Maunder, Thomas E (DOA) Ce: NSK Problem Well Supv; Schwartz, Guy L Subject: 2N-305 P&A sundry# 308-450, PTD#200-135 Tom, Work accomplished thus far for this well has been: 2/11/2009 2N-305 P&A sundry# 308-450, PTD#200-135 Page 2 of 2 • 1) Removed 'CA-2' plug from nipple 9374' KB. SITP increased from 625 psi to 1450 psi after prong was pulled. 2) Established injection rate into Bermuda perfs 1.5 BPM @ 1450 psi w/diesel. 3) Eline set EZSV @ 9280' after getting stuck in base of CMU sliding sleeve. PT 2500 psi w/ 200 psi loss in 5 minutes likely to tbg leak above @ 7380'. 4) CT stung into EZSV, pumped 21.8 bbls cmt below retainer & dumped 3 bbls on top. CT then reversed tbg clean to 9090' leaving 192' of cmt above retainer & diesel in the tbg above. SITP pre & post pumping cement was 1422 psi & 500 psi, respectively. Due to the previously identified tbg & csg leaks in this well, it is unlikely that the cement can be successfully MIT'd. Approval is sought to alter the original procedure by eliminating pressure testing the cement plug to 1500 psi and instead verify that the post-cement drawdown differential (922 psi) has been maintained. The SITP will be verified when ambient temperatures allow slickline to tag the cement top in the tbg. Please let me know if any questions or if further information is required. Jim Ennis j j.ennis@conocophillips.com (907)265-1544 (W) (907) 632-7281 (C) 2/11 /2009 r~ _ ---_ - i WSR Historical -FILE COPY- Job: Drilling Support -Capital ' Report Date: 2/7/2009 ConocoPhill ips 2N-305 Unit: SLB-DS COILED TUBING CTU 4 Rowell, John -CPAs, Wells Supervisor: API / UWI Field Name 5010320349 TARN PARTICIPATING AREA Well Type Original KB/RT Elevation (ft) Well Status Legal WeIlName Well Services 154.73 PROD 2N-305 JOB; Drilling Support -Capital _ _ _ _ _ Actual Start Date End Date Secondary Job Type Drillsite Primary Wellbore Affected 2/7/2009 06.00 2/7/2009 19:00 2X52 Cementing 2N ~2N-305 -- - Project 12N-305 Dulling Support - - - - Dasc t_egalVJellName-__..r ~_~ ~ Tyoa-~ ~---~ - -_AFE_1R_FE~-. i-~~--NalworWl~# Capital -Wells 2N-305 Drilling Support -Capital 10246747 j 10246747 _ _ --- UNIT/RIG: SLB-DS COI LED TUBING CTU 4 Rig Accept Date Rig Release Date Contractor Rig Name/No Rig Type I 2/7/2009 _06:00__ J - SLB-DS ~ 2/7/2009 19:00 ___ CTU 4 COILED TUBING _ I. - Rig Supervisor _ _ ;Company Title _ Phone Mobile Phone Work Rowell, John -CPAI, Wel ls Supervisor CPAI Wells Supervisor 943-1214 659-7285 Comment BHA #1-2.188" MHA WITH BLANK CHECKS AND 5!8" BALL DISC0,2"X0,2.7" HES EZSV CEMENT STINGER, OAL=9.78' ( ; ,DAILY OPERATIONS: 2/7/2009 EDITED BY: w.attemn _ i ' Report Start Date __ _ ___ __ _ _ Report End Date f General Remarks _ Daily Cost Total 2/7/2009 06:00 2/7/2009 19:00 ITI0=1422/1436/200 FTI0=500/500/208 Last 24hr Summary PERFORMED CEMENT P&A THRU EZSV CEMENT RETAINER, PUT 3.8 BBLS 15.8 ppg BELOW RETAINER AND 18 BBLS SQUEEZED INTO PERFS, j STUNG OUT OF RETAINER AND LAYED IN 3 BBLS CEMENT ON TOP OF RETAINER. CONTAMINATED WITH BIO AND REVERSED CIRCULATED DOWN TO 9090' CTMD USING SLICK DIESEL LEAVING 200' CEMENT ON TOP OF RETAINER, WELL LEFT SHUT IN AND LOADED WITH DIESEL, TURN OVER TO DSO, 24 HR WAIT FOR P&A PRESSURE TEST. READY FOR SLICKLINE. -- -- i - - Weather ---- ----- ----_-__ Temperature (°F) rWind Unit Supervisor _ _ _ ~ I - Supervisor CLARK -SLB-DS, Coil Tu ~, Company j Title l - M1loblle ~ Phone Work i - - bing SLB DS Coil Tubing Operator N/A 943-1564 ILOperator I i ITime Log - - -- - --- -- -- - - - -- _--- - - _ _ - _... -._ -- ---- --. -- r Start Timei Cnd Time Dur (hr5) _ _ Cum Dur (hrs) ~ __O~eration '; Wellbore ~ I :06:00 07:30 1.50, _ 1.50iARRIVE LOCATION,PJSM,MIRU 2N-305 i i .07:30 08:30 1.00 2.50jRIG UP COMPLETE,MU MHA 2N-305 j 08:30 i 09:00 ~I 0.50'. 3.00 I PT MHA TO 3500# 2N-305 I .09:00 '09:30 0.50 3:501MU HES EZSV CEMENT STINGER ~2N-305 ~ 109:30 110:00 0.501 4.00 ON WELL NIPPLE UP BOPS 2N-305 i I 10:00 'i 10:12 0,20 4;20 FLUID PACK TO TANKS, PT ALL 250# LOW/4000# HIGH 2N-305 X10:12 110:18 '~ 0.10 4.30jOPEN WELL RECORD PRESSURES, RIH 2N-305 10:18 11:18 1.00' 5.303000' CTMD, 5K WTCK,2 PSIG WHP,88 PSIG CTP,54 PSIG IA,O PSIG OA,CONTINUE RIH 2N-305 '111:18 11:33 0.25 5.55ON LINE WITH SEAWATER DOWN COIL i2N-305 '11:33 111:48 0.25, 5.8016000' CTMD, 9.3K WTCK,11 PSIG WHP,203 PSIG CTP,67 PSIG IA,116 PSIG OA,CONTINUE RIH 2N-305 1 ' 11:48 12:30 0.70 6.5019199' CTMD, 14 WTCK,41 PSIG WHP,775 PSIG IA,165 PSIG OA,PARK ABOVE EZSV AND PUMP 10 2N-305 I '.BBLS SEAWATER BEFORE STINGING INTO RETAINER ' ~ ' 12:30 12:33 0.05 6.55 12 BBLS SEAWATER OUT, RIH STING INTO RETAINER ~2N-305 12:33 12.36 0.05 6.60 9290' CTMD, SET DOWN 3K, REALLY GOOD INDICATION THAT STINGER INGAUGED RETAINER, 12N-305 I ~ BRING PUMPS ON LINE @ 1 BPM CHECK INJECTNITY. I .12:36 12:39 0.05 6.65:9291' CTMD,524 PSIG WHP,2100 PSIG CTP,524 PSIG IA,216 PSIG OA, CONTINUE TO CIRCULATE 12N-305 ~ ' SEAWATER, PJSM WITH CEMENTERS I I ;12:39 13:09 i 0.50 7.15 CEMENTERS READY FP COIL PUMP LINE UP CEMENTERS TO COIL 2N-305 ~ I 13:09 13:15 ~ 0.10 , , 7.25 ON LINE 5 BBLS FRESHWATER AHEAD ~2N-305 (13:15 ,13:18 ', 0.05 7.30 SHUT DOWN PT LINES TO 4000# 2N-305 ~ I ,13:18 113:24 i 0,10 7.40 CEMENT AT MICROMOTION, 1 BPM, 461 PSIG WHP,1742 PSIG CTP,468 PSIG IA,230 PSIG OA ~2N-305 113:24 ,13:54 I 0.50 7.90 25 BBLS CEMENT AWAY, SWAP TO FRESHWATER FOR 5 BBLS 12N-305 ' 13:54. ' 14:06 i 0,20' 1 8.10 5 BBLS FRESHWATER AN/AY,SWAP TO COIL PUMP WITH'BIOZAN 12N-305 ~ 14:06 114:12 0.10 8.20 CEMENT AT NZL, REDUCE RATE TO .5 BPM, 445 PSIG WHP,931 PSIG CTP,453 PSIG IA,230 PSIG 12N-305 OA,CONTINUE LAYIN CEMENT BELOW RETAINER I 114:12 114'18 j 0.101 8.30 3.8 BBLS CEMENT AWAY AND SUMP IS FULL,CONTINUETO PUMP AT .5 BPM 728 PSIG CTP ~2N-305 ~ 114:18 114:24 0.10 8.40 10 BBLS BIO AWAY SWAP TO SLICK SEAWATER '2N-305 14:24 14:54 I 0.50 8.90 9291' CTMD, 15K WTCK, 736 PSIG WHP,921 PSIG CTP, 21;8 BBLS AWAY, PICK UP UNSTING '2N-305 ~ FROM RETAINER WITH U ~ ! , 14:54 14:57 0.05 8.95 PUMPS ON LINE .7 BPM LAY iN REMAINING CEMENT TO 9050' GTMD,CONTINUE PUH LAYING IN ~2N-305 BIOZAN I I www.peloton.com Page 1/2 Report Printed: 2/10/2009 - -----__-- -- - --_ I ___._. __ WSR Historical -FILE COPY- Job: Drilling Stapport -Capital 1-~ Report Date: 2/7/2009 ConocoPhillips 2N-305 Unit: SLB-DS COILED TUBING CTU 4 Rowell, John - CPAI, Wells Supervisor: API ! UWI 5010320349 Well Type Well Services Time Log _ Slart Time End Time Dur (hrs) 14:57 15:00 0.05 15:00 15:12 0.20 15:12 115:18 ( 0.10 TARN PARTICIPATING AREA j 154.73 ~ PROD ~2N-305 11 umDu~ -~ -- - - -- - - - --~ -.- ~_I (hrs) Operation _ ~ Welltiore 9.00 9050' CTMD, WATER AT NZL, CONTINUE PUH, 512 PSiG WHP,834 PSIG CTP, 591 PSIG !A, 247 t2N-305 PSIG OA, LAY IN BIO BEFORE SWAPING TO REVERSE CIRCULATE 9.20SWAP OVER TO DIESEL DOWN BRCK, BEGIN REVERSE CIRCULATE DOWN TO bESIRED TOP 2N 305 ~ !OF CEMENT 9.3019090' CTMD, 1776 PSIG WHP,54 PSIG CTP, REVERSED TO TOP OF CEMENT, 1.5 BPM PUMPING, 2N-305 ',1.4 BPM RETURING 15:18 115:30 0.20 9.5018900' CTMD, 1918 PSIG, 54 PSIG CTP,1749 PSIG IA, REVERSE BACK DOWN TO 9090' CTMD 2N-305 15:30 ,15:36 i 0.101 9.60'9090' CTMD, 1910 PSIG WHP,55 PSIG CTP,1832 PSIG IA,LAST TRIP TO CEMENT TOP, BEGIN 2N-305 POOH i 15:36 15:48 0.20! 9.80!8825' CTMD,1878 PSIG WHP,115 PSIG CTP, DIRTY CEMENT TO TANKS, CONTINUE TO PUH I2N-305 15:48 16:48 1.00 10.80 SURFACE TRAP 500# ON TBG, CLOSE SWAB FLUSH TO TANKS 2N-305 116:48 ~ 19:00 ~ 2.20 i 13.00 RDMO, END TICKET 2N-305 1 ;Well Fluids ---- Fluid _ -- ~DIESEL, SLICK GEL SEAWATER, SLICK To {I 160.0 TBG 50.0 TBG 90.0 TBG Nose www.peloton.com Page 212 Report Printed: 2/10/2009 ~J 1, ~_.. F S" P-° "~.~ •_,a a,~ ~ 1...~ ~:~::~ ~~M.r fi ~.9 ~ l ~~_~_•:~ i_i"l ~. ~~_~~ ~ 11,E ~ ALASSA OII, A1~TD GAS COI~TSER~"ATIOI~T CO1rII-IISSIOI~T Guy Schwartz Wells Group Engineer ConocoPhillips Alaska Inc. PO Box 100360 Anchorage AK 99510 Re: Kuparuk River Field, Tarn Oil Pool, 2N-305 Sundry Number: 308-450 • SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ~o~ J ~~ Dear Mr. Schwartz: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Q~ ~ Chair DATED this U day of January, 2009 Encl. ~Q~~D~ ~~ STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPOVAL 20 AAC 25.280 ~i' ~ ~ `1 ~. O ~0 1. Type Of Request: Abandon ^/ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other `^ Alter casing ^ Repair well ^ Plug Perforations Q Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^/ Exploratory ^ 200-135 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20349-00 7. If perforating, closest approach in pools} opened by this operation to nearest property line 8. Wel! Name and Number: where ownership or landownership changes: Spacing Exception Requires? Y2S ^ NO ^~ 2N-305 9, Property Designation: • 10. KB Elevation (ft): 11. Field/Pool(s): ADL 380053, 380054, 375074 RKB 35', Pad 119' Kuparuk River Field / Tarn Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MO (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10334' . 5682' 10200' 5614' 9374' Casing Length Size MD TVD Burst Collapse CONDUCTOR 118' 16" 118' 118' SURFACE 2990' 7-5/8" 3025' 2296' PRODUCTION 9348' S-1/2" 9383' 5210' PRODUCTION 945' 3-1/2" 10328' ~ 5679' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9724'-9734' 5372'-5377 3.5" L-80 9395' Packers and SSSV Type: Packers and SSSV MD {ft) ~P no packer C~u.4Cr} j~~ ,"t1~~~~C 50T 13. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work: Plugged and Abandoned ~ ' Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat January 15, 2009 Oil ^ Gas ^ Plugged ~ Abandoned Q 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Guy Schwartz @ 265-6958 Printed Name GUV SChWartz Title: Wells Group Engineer Signature C Phone 265-6958 Date ,~ - J S" ~~ Commission Use Onl Sundry Number/ Conditions of approval: Notify Commission so that a representative may witness Plug Integrity ^ BOP Test '~ Mechanical Integrity Test ^ Location Clearance ^ 11 _.~ ry`'~~ Other: 3.~V~ ~ _ •,. ~~ ~ Subsequent Form Required: ~`~°~ APPROVED BY '' 7C Approved by: COMMISSIONER THE COMMISSION Date: UU ((( Form 10-403 Revi§ed 06/7606 '" ', t ~ r t ~ ~ ~ y.~~ Submit in Duplicate ~ 4.~~~ri 11~~1~~ A~i,i,~: !~„ ~ KUP ( Y ' WenotAa I solo3: c«nment CONDUCTOR. 118 NIPPLE. sm -. GAS LIFE, 2.715 8,001.0 9,290.0 9,331.0 9,374.0 9,374.0 ~ 9,375 0 9,383 0 9,395 0 GAS LIFT. 5,899 GAS LIFT. 8,001 SLEEVE-C, 9,290 Depth Depih (ftKe) (ftK6) GAS LIFT, 9,331 NIPPLE.9,376- PLUG.9,374 LOCATOR,. 9.375 PRODUCTION, 9.383 SEAL. 5.3d~ GUIDE, 9,395- -'--- IPERF,_ 9.724-9,736 ~ e FRAC, 5.726 PRODUCTKN, 0,328 \ TD. 10.334 TARN PART ICIPATING AREA '~IH2S IPpn) ,Date 100 7/1/2008 t/ Entl Date Annotation 4/24/2007 Rev Reason' S 121 0.01 9,395.01 commem I'DS' NIPPLE dKBG 2-9/1/DMY/DCK/// Comment: UKBG 2-9/1/DMY/DCK//I Comment: UKBG 2-9/1/DMY/DCK//! Commen[ CMU SLEEVE -CLOSED 4/24/200. 5.5" x 4" Shot Dens .one l:not... Date 4.0 10/15/2000 Comment 41.64 2N-305 10,%!2000 • 2N-305 P & A Sundry Request 12-11-08 • The purpose of the 2N-305 sidetrack is to restore production from that portion of the reservoir lost due to severe casing corrosion in mother well but also to move away from ,i" potentially swept zones in order to capture more reserves. 2N-305A will be a MWAG-supported, fracture-stimulated, gas-lifted producer. The well will be drilled approximately 500 feet ENE from the original 2N-305 bottom-hole location, looking for similar quality rock, targeting slightly better seismic attributes. The intent is to capture more oil from un-swept rock. ~~,~~~/ ~~ Procedure Outline 1. Pre-cement squeeze prep work: 1. Mobilize DHD crew to test tubing and casing packoffs /cycle LDS's. 2. Use pump truck and establish injection (use diesel) into the open `"~ perfs at 1 -2 bpm. Record pressures vs. rate. CMU is shut but there Q ~o~ is a tubing leak at 7830'. ~~ 2. EZSV Setting procedure (using E-line) ~ ~ V Run Halliburton EZSV 3.5" cement retainer on Eline. (*set depth approx. 9350' md) Set just below the bottom GLM at 9331' md. 3. Cement Squeeze Procedure: 1. RU CTU. Notify AOGCC Inspector of date and time of operation. (659-2714 or pager 659-3607). 2. Run hardline from tubing connection to an open-top with an inline choke skid. 3. Rig up CTU and cement unit: Pressure test coil, BOP's and hardline to 3500 psi. 4. RIH with CTU with EZSV retainer stinger assembly (use two "star centralizers" to ensure coil has straight shot at the ID of the retainer) , • stab into EZSV at 9350' md; shift sliding valve open by moving valve downward . Pump slick seawater at approx. 1-2 bpm to establish injection rate and pressure. 5. Pump cement into formation until desired squeeze pressure of 1000 psi is reached. Tota13 '/2" liner volume below the retainer is approximately 3.5 bbls. Attempt to squeeze away at least 5 bbls of cement into the formation if possible. 6. Pull out of retainer, open CT x tubing annulus and lay in cement to 9300' taking 1-1 returns. Swap to biozan and jet out cement while POOH. Freeze protect the last 2,500 ft with diesel. 7. Wait 24 hrs for cement to set. Rig up SL to drift for jet cutter. Drift tubing to PBTD (TOC) with 2.73" gauge. Pressure test cement plug to 1500 psi for 30 min. Record results. (Notify AOGCC of the timing of the post cement plug tag and PT). s. Perform Drawdown test by bleeding any tubing, IA and OA pressure to open-top tank. Tbg and IA should bleed to 0 psi. RIH and pull DV in GLM at 8001' md. 9. Rig up E-line and jet cut 3 %2" tubing at approx. 8500' MD (below GLM #8) at nearest mid joint POOH with E-line, verify the cutter operated properly and rig down E-line unit. (Chemical cutter not needed for this operation) lo. Set BPV and VR plug. Pull wellhouse and prep site for rig. Notify Wells group of well status. 4. Drilling Rig P & A Component 11. MIRU Doyon 15. Pull BPV and VR plug. Circulate brine around tubing and IA through tree. Ensure well is dead. ~------1~ 2~~~~ ~--~,,,a...~ 12. Set Blanking plug and BPV, ND tree , NU BOP's and test. Pull ,~~®~~'-4 ~,~,~~;; BPV/blanking plug and pull tubing hanger to floor. Pull remaining ,,?~ tubing out of well and lay down same. ~~-~ ~( 13. RU Eline. RIH with 5 %2" CIBP and set at approx. 3300' md. 14. RIH with 5 1/2" Jet cutter and cut casing at approx. 3216' md. RD Eline. 15. Pu115 1/2" casing and lay down same. 16. PU openhole whipstock with sidetrack mill and RIH to land out on casing stub. Orient and set whipstock. Shear out and commence sidetrack of well. 2N-305 P & A ~ Page 1 of 1 Maunder, Thomas E (DOA) From: Schwartz, Guy L (Guy.L.Schwattz@conocophillips.com] Sent: Thursday, December 18, 2008 2:11 PM To: Maunder, Thomas E (DOA) Subject: RE: 2N-305 P & A We won't be on the well till February so lots of time. Guy Schwartz Dulling and Wells Engineer office: 907-265-6958 Cell: 240-5696 ATO-1512 guy.I, schwa rtz@conocoph it lips. com From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, December 18, 2008 2:05 PM To: Schwartz, Guy L Subject: RE: 2N-305 P & A Best for the season to you as well. When is the work planned? My last day for 2 weeks is tomorrow. Tom From: Schwartz, Guy L [mailto:Guy.L.Schwartz@conocophillips.com] Sent: Thursday, December 18, 2008 2:02 PM To: Maunder, Thomas E (DOA) Subject: 2N-305 P & A Tom, Just sent in a Sundry P & A request for this well. A little different in that we can't get a CMIT to pass with the. casing corrosion leaks above the packer (at about 3200' and 4700' md) . It is a slow leak to the formation (.25 BPM @ 3000 psi). So even after the P & A is completed it probably will not pass the pressure test. Just wanted to point that out to you if you want to add any remarks to the sundry permit. Hope you are having a great holiday season. Guy Guy Schwartz Drilling and Wells Engineer office: 907-265-6958 Cell: 240-5696 ATO-1512 guy.l. Schwartz@conocoph illips.com 12/2312008 Maunder, Thomas E (DOA) From: Greener, Mike R. [Mike.R.Greener@conocophillips.com) Sent: Thursday, August 21, 2008 2:09 PM To: Maunder, Thomas E (DOA) Subject: whipstock vs. cement plug Attachments: Greener, Mike R..vcf Page 1 of 1 I have a sidetrack well at Tarn coming up in January next year. It is a typical Tarn sidetrack case where they have 7-5l8" surface with a 5.5" x 3.5" long string. The well name is 2N-305. Our normal procedure is to cut the 5.5" about 200' below the surface shoe and spot a cement plug (after properly abandoning the 5.5" string) which we use to time drill off of to create our sidetrack. I am considering instead of using the cement plug in the end of the 5.5" stub I use a whipstock instead that would fit inside the stub and allow me to sidetrack immediately. We would still have a CIBP below the whipstock and we could place cement on top of the CIBP also. The whipstock looks like it could save about 24 hours of rig time in spotting cement, waiting for it to set up, and time drilling off of it. Any opinion? Mike Greener 12/23/2008 • ConocoPh~ll~ps Aiaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 4, 2407 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ate- ice' Enclosed please find a (revised l OJ3/07)spreadsheet with a list of wells from the Kuparuk field (KRL~. Each of these wells was found to have a void in the conductor. These voids were filled with a 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 top jobs were pumped on September 9, 2007 and the corrosion inhibitor/sealant was pumped on September 16-27, 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. This spreadsheet is a revised format for the original submitted on 9/28/07 Please call myself at 907-b59-7506, or M.J. Loveland at 659-7043 if you have any questions. Sincerely, on Arend • ConocoPhillips Well Integrity Field Supervisor r: ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 9/28/2007 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 2L-303 201-239 7' 7" 1.2 18" 9/9/2007 7.5 9/16/2007 2L-309 205-210 13' 3" 2 18" 9!9/2007 7.5 9/16/2007 2N-302 201-115 5' 11" na 5" 11" na 39.5 9/16/2007 2N-313 198-091 5' 0.75 18" 9!9(2007 2N-335 198-204 20" na 20" na 13 9/16/2007 2N-347 200-063 21' 4 18" 9/9!2007 6 9/16/2007 2N-348 201-142 4' 8" 1.5 12" 9/9/2007 4.5 9/16/2007 2N-303 200-169 5" n/a 5" n/a 1 9/27/2007 2N-304 201-130 10" n/a 10" n/a 4.5 9/27/2007 2N-305 200-135 12" n/a 12" n/a 7.5 9/27/2007 2N-307 199-017 14" n/a 14" n/a 4.5 9/27/2007 2N-308 199-010 5" n/a 5" n/a 1 9/27/2007 2N-309 199-021 9" n/a 9" n/a 2 9!27/2007 2N-311 206-179 12" n/a 12" n/a 10 9/27/2007 2N-313 198-091 18" n/a 18" n/a 2 9/27/2007 2N-314 200-193 26" n/a 26" n/a 7 9/27!2007 2N-315 198-190 6" n/a 6" n/a 3 9/27/2007 2N-317 198-143 5" n/a 5" n/a 1 9/27/2007 2N-318 200-100 10" n/a 10" n/a 1 9/27/2007 2N-319 198-197 5" n/a 5" n/a 9.5 9/27/2007 ConocoPhillips ~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 28, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7`~ Avenue, Suite 100 Anchorage, AK 99501 ~~' NCV ~ ~ 2QD7 Dear Mr. Maunder: • ~~CL~1 ~cr VFp A/ask° Di/~ ~a ~ 2 ~Opj ~°~h0 a98 e°~Iissi 0/~ ~~~~~~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRIn. Each of these wells was found to have a void in the conductor. These voids were filled with a 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 top jobs were pumped on September 9, 2007 and the corrosion inhibitor/sealant was pumped on September 16-27, 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call myself at 907-659-7043, if you have any questions. Sincerely, ®r~ ` ~.- M.,I. vel d ConocoPhillips Well Integrity Projects Supervisor • • GonocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date Kuparuk Field 912s/2nn~ 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 a1 2L-~03 201-239 7' 7" 1.2 18" 9/9/2007 7.5 9/16/2007 2L-309 205-210 13' 3" 2 18" 9/9/2007 7.5 9116!2007 2N-302 201-115 5' 11" na 5" 11" na 39.5 9/1612007 2N-313 198-091 5' 0.75 18" 9/912007 2N-335 198-204 9" na 20" na 13 9/16/2007 2N-347 200-063 21' 4 18" 9/9/2007 6 9/18/2007 2N-348 201-142 4' 8" 1.5 12" 9/9/2007 4.5 9116!2007 2N-303 200-169 5" n/a 5" n/a 1 9/27/2007 2N-304 201-130 10" n!a 10" n/a 4.5 9/27/2007 2N-305 200-135 12" n/a 12" n!a 7.5 9/27/2007 2N-307 199-017 14" n/a 14" n/a 4.5 9/27/2007 2N-308 199-010 5" n/a 5" n/a 1 9!27/2007 2N-309 199-021 9" n/a 9" n/a 2 9127/2007 2N-311 206-179 12" n!a 12" n/a 10 9!27!2007 2N-313 198-091 5" n/a 5" nia 2 9/27/2007 2N-314 200-193 26" n/a 26" n/a 7 9/27/2007 2N-315 198-190 6" n/a 6" n/a 3 9/27/2007 2N-317 198-143 5" n/a 5" n!a 1 9/27/2007 2N-318 200-100 10" n/a 10" n/a 1 9/2712007 2N-319 198-197 5" n/a 5" n/a 9.5 9/27/2007 06/08/07 Schlumbel'ger NO. 4286 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 1.001 ~NED JUN 1 4 2007 Kuparuk Well Job # - 6)ro -135 Log Description ~w. Field: BL Color CD Date 2M-13 11665442 SBHP SURVEY OS/28/07 1 1J-105 11632710 GLS OS/26/07 1 2N-305 11632713 SBHP SURVEY OS/29/07 1 1 R-20 11665444 LDL 05/30/07 1 1Q-03 11630480 PRODUCTION PROFILE 06/01/07 1 3S-18 11629016 PRODUCTION PROFILE 06/03/07 1 2M-02 N/A SBHP SURVEY 06/04/07 1 2M-06 11628958 SBHP SURVEY 06/05/07 1 2M-04 11629022 SBHP SURVEY 06/05/07 1 1H·11 11629026 PRODUCTION PROFILE 06/07/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 1J~ . 2N-305 PTD# 200~ 135, production casing leak to formation e e Subject: 2N-305 PTD# 200-135, production casing leak to fonnation From: NSK Problem Well Supv <nI617@conocophillips.com> Date: Fri, 25 May 2007 16:15:54 -0800 To: Thomas Maunder <tom_maunder@admin.state.ak.us>, James Regg <jim~regg@admin.state.ak.us> Gentlemen, 2N-305 PTD # 200-135, surface powered jet pump producer, was first reported for having T X IA communication on 4/29/07. Through diagnostics CPAI has determined that the tubing has a hole between 7648-7850'. Caliper results indicate the tubing to be in good condition. A Magnetic Thickness log was run and indicated areas of significant metal loss from 3267-7814'. A combo MIT with plugs set in the tubing tail resulted in a liquid leak rate of 0.25 bpm at 3000 psi indicating a leak to formation. Immediate action will require a leak detect log to try and confirm the depth(s) of the casing leak(s). The well is secure, plug set at 9374', and will remain secured until repaired. Let me know if you have any questions. Sincerely, Perry Klein Problem Well Supervisor office (907) 659-7224 Cell (907) 943-1244 Pager (907) 659-7000 x909 n 1617@conocophillips.com $~NtJD JUN 1 4 2007 . . . «2N-305.pdf» Content-Description: 2N-305.pdf 2N-305.pdf Content-Type: application/octet-stream Content-Encoding: base64 lofl 6/12/20071:21 PM 2N-305 ptd # 200-135 - T X IA communication e e Subject: 2N-305 ptd # 200-135 - T X IA communication From: NSK Problem Well Supv <nI617@conocophillips.com> Date: Sun, 29 Apr 2007 10:19:14 -0800 To: Thomas Maunder <tom_maunder@admin.state.ak.us>, James Regg <jim_regg@admin.state.ak.us> Tom & Jim, 2N-305 PTD # 200-135 surface powered jet pump producer has T X fA communication. While pulling a jet pump for maintenance, slicklineidentified a tubing lèak between 7648-7850' with the D&D holefinder. Initial T/I/O = 250/250/150 psi A plug has been set in the D nipplè at 9374' in preparation for upcoming diagnostics, caliper and leak detect log. The well has been added to the SCP report. Let me know if you have any questions or comments. Perry Klein Problem Well Supervisor office (907) 659-7224 Cell (907) 943-1244 Pager (907) 659-7000 x909 n1617@conocophillips.com «2N-305.pdf» 5fJo\NNED JUN 1 4 2007 Content-Description: 2N-305.pdf 2N-305.pdf Content-Type: application/octet-stream Content-Encoding: base64 1 of I 6/12/2007 2:06 PM .-r' . WELL LOG TRANSMITTAL "' . ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 1 00 Anchorage. Alaska 99501 (907) 659-5102 RE: Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper / M1T) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services. Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage. AK 99518 Fax: (907) 245-8952 1) 2) 3) 4) 5) 6) 7) Signed: 1 Report 2N - 305 MTT Log 5t;;AN1NED MAY· 2 2 2007 - d()C) .-{ 35 c,d - ~J;¡ (~+i il1.p (Vlt'J1 tIll<,~{A Print Name: 13-May-07 RECEI'JED MAY 2 1 Z007 Date : "ì!aska Oil·1i Gas C.ons. Commission Anchorage PROAcTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHoNE: (907)245-8951 FAX: (907)245-8952 E-MAIL: ?DSANCHORAGE@.MEMORYLOG.COM WEBSITE: WWW.MEMORYLOG.COM D:\Master _copy _ 00 ]DSANC-2OxxIZ_ WordlDistribulionITransmit1al_ SheetslTnmsmit _ Original.do<: I I I I I I I I I I I I I I I I I I I . . Memory Magnetic Thickness Tool L.og Results. Summary Company: ConocoPhillips Alaska, Inc. Well: 2N..30S Log Date: May 13, 2007 Field: Kuparuk Log No. : 6172 State: Alaska Run No.: 1 API No.: 50-103-20349-00 Pipe1 Desc.: 3.5" 9.3 Ib L-80 8RD EUE Top Log Intvl.: 3,080 Ft. (MD) Pipe1 Use: Tubing Bot. Log Intvl.: 9,280 Ft. (MD) Pipe2Desc.: 5.5" 15.5 Ib L-80 LTC MOD Top Log Intvl.: 3,080 Ft. (MD) Pipe2 Use: Production Casing Bot. Log Intvl.: 9,280 Ft. (MD) Inspection Type: Assess Corrosive Damage (Metal Loss) to Production Casing. COMMENTS: This MTT data is tied into the Sliding Sleeve @ 9,285' (Driller's Depth). This is the first log of this well to be made with the 12 Arm Magnetic Thickness Tool (MTT). This log was run to identify external damage to the tubing, with special attention to the Interval between 7,648' and 7,850' (58% isolated metal loss is recorded at 7,814'). The Magnetic Thickness Tool responds to the total thickness of metal of the 3.5· tubing and 5.5" production casing within the logged interval. Due to the concentric pipe strings in the log interval, the MTT response is qualitative - indicating an overall increase or decrease in metal surrounding the tool, but not distinguishing in which pipe string the change in metal thickness occurs. In this log, the MTT was calibrated down hole (9,246'), where the readings are assumed to represent undamaged tubing and casing. All other readings are relative to this reference point, which include influences from the 3.5" tubing and 5.5" production casing. INTERPRETATION OF MTT LOG RESULTS: The MTT log results cover the interval from 3,080' to 9,280'. The recordings do not indicate any intervals of significant overall circumferential metal loss, or areas where overall metal surrounding the tool has decreased by more than 5% relative to the calibration point. However, there are numerous indications of isolated metal loss, or pitting type damage, recorded throughout the interval logged. The vast majority of indications of more severe pitting are recorded over the interval above GLM 2 (3,080' - 5,870'). Indications of localized volumetric metal loss exceeding 40% of total metal volume are recorded in 27 of the 91 joints logged above GLM 2. Below GLM 2, only 3 joints show localized volumetric metal loss events in excess of 40% of the total metal volume. One of these three events is an indication of 58% localized metal loss recorded at 7,814' - within the special interval of interest Graphs illustrating the Average Circumferential Metal Loss and Maximum Localized Metal Loss, on a joint- by-joint basis, are included in this report. Detailed log plots of the intervals of most significant recordings at 3,267',4,707',4,953',5,094', and 7,814' are included in this report. MAXIMUM RECORDED METAL LOSS FROM MTT: Isolated Metal Loss 70% Metal Loss @ Isolated Metal Loss 70% Metal Loss @ Isolated Metal Loss 70% Metal Loss @ Isolated Metal Loss 69% Metal Loss @ Isolated Metal Loss 58% Metal Loss @ 4,707 Ft. (MD) 5,094 Ft. (MD) 3,267 Ft. (MD) 4,953 Ft. (MD) 7,814 Ft. (MD) ProActive Diagnostic Services, Inc. I P.O. Box 1369, Stafford, TX 77497 RECE\VED Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 MAY 2 1 Z007 Alaska Oil & Gas ConS. Commission Anct\Qrage {)ÓO -l3~- I . . The percent isolated metal loss expressed in this summary is a percentage of the total metal that the tool is responding to, which includes influences from the 3.5" and 5.5" pipe. The high frequency nature of a majority of the indications of metal loss recorded point to a high probability that they are features of the 3.5" tubing, but possible areas of isolated metal loss in the 5.5" casing could be influencing the amplitude of any or all of these responses. All % Metal Loss values expressed in this report refer to a localized volume of metal, and are not directly related to % Wall Penetration. Shallow areas of metal loss that cover a broader pipe surface area will give similar responses to deeper areas of metal loss that cover a smaller pipe surface area. I I I I I I I I I I I I I I I I I Field Engineer: D. Cain Analyst: M. Tahtouh / J. Burton Witness: C. Kennedy I I ProActive Diagnostic Services, Inc. I P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorýlog.com Prudhoe Bay Field Office Phone. (907) 659-2307 Fax: (907) 659-2314 I MlT Maximum Recorded Metal Relative to Calibration Point I Pipe 1 3.5 in - 9285.3') Well: Field: Company: Country: Survey Date: 2N-305 Kuparuk ConocoPhiilips Alaska, Ine. USA May 13, 2007 I I I Decrease Increase 100 3139 I 125 3921 I 150 4695 I 175 5477 GlM 2 I (¡; 200 6271 ...0 ¥ E u... ;::¡ .S z I - c: 225 7050 § I 250 7829 GlM 3 I 275 8626 I 295.1 9285 -100% 0 100% I in Metal Thickness (%) I I Bottom of Survey = 295.1 I I I I I I I I I I I I I I I MTT Circumferential Recorded Metal Loss Relative to Calibration Point Pipe 1 I I I I I I GLM 2 ~ (!J ..Q E :;:¡ z ë ..Q, GLM 3 3.5 in (3075.6'. Wen: Field: Company: Country: Survey Date: 2N-305 Kuparuk ConocoPhillips Alaska, ¡ne. USA May 13, 2007 Decrease Increase 100 ~ 1 ¡ 125 9 mil- '" 150 175 [ 200 225 250 275 11Im 295.1 -50% o in Metal Thickness (%) Bottom of Survey = 295.1 3139 3921 4695 5477 6271 7050 9285 50% .,,; u.. .f: 7829 8626 I I I I I I I I I I I I I I I I I I I <12 ~S. Magnetic Thicknes og (10Hz) p~ DIAq"""""lc SERvice. I"". Database File: d :\warrior\data. \2n-305\2n305. db Dataset Pathname: 2n305.1 Presentation Format: 2.2 scale Dataset Creation: Mon May 1413:20:172007 by Calc Sondex Warrior V7.0 Charted by: Depth in Feet scaled 1 :25 0 LSPD (ftlmin) -100 2.2 MTTP01 (rad) 12.2 -50 Delta Metal Thickness (%) 50 -6.6 MTTP12 (rad) 3.4 l )'"~ ;: rn I \ \ \ \ \ II I > 1( I Line Speed ) lJ IJ ( ) I 7810 { I ( (' I tt4ttHt l ~, L ~ ~, l Metal I ¡ ) < E::> } ::: I ') '" þ ~ J < ¡ ( ¡ Joint 250 ~ Jd t ~~ Isolated Metal L~SS ~ .~y J - < ..=: ~ - I l ; ;> :> I ~E J ) I.. i) 1 ) 1 J ~ ¿ '::::> < f ~ J I ? I ¡ < I ) ) ; :;> f' ./ (" / I I 1 \ 1. \ ') \ .~ Metal Loss ~ r: 1 µ~~~ ..1 } ;- ! <:.::::: "" ';> \ ,< 4f i 7820 I ¡ " >1 >I'~ > " ;) "- ) "'- >: ~ ", » "'" ) ~:\: ;;, 1 ~< r:~7 ~~ t < ~7 "'} ~'~, ( 7 '--~ ? f ) l } ) f , 0 LSPD (ftlmin) -100 2.2 MTTP01 (rad) 12.2 -50 Delta Metal Thickness (%) 50 -6.6 MTTP12 (rad) 3.4 I Jrk Magnetic Thickne og I ~ DIJoq_I<: Se....æ.... ¡""". Database File: d: \warrior\data\2n--305\2n305. db Dataset Pathnarne: 2n305.1 I Presentation Format: 2.2 scale Dataset Creation: Mon 1413:20:172007 Calc Sondex Warrior VT 0 Charted in Feet scaled 1 :50 I 0 LSPD (ftlmin) -100 2.2 MTTP01 (rad) 12.2 -50 Delta Metal Thickness (%) 50 -6.6 MTTP12 (rad) 3.4 I "'IV;:JU ¿ ~ l l. I~I ¡~ì I ~7 ~ I, -- I ¡ uœsp! - ~ -.-'" g;:- ¡<= ( ,...'5 I ? ~ -- ~f'-' -- I 4700 ). ~. - t -- ~ tþ I " -- I--- ! ~ - (~ )" ~ ?" I ~> ( I ,~ f--- \. ~=_i~ - \ ~- -:1 :::::==- 70% Metal Loss . k~ l t 1 -~ I Joint 150 If =;,.:¡¡ ¡ { ( - ~ ( ~ è: <> ~? ) I I \'-'> b ~ ~ 11. '1 r-'1 4710 ( ._..J I'? ( r !~\ ( I:¡-/ ¡ ~) <~ ~ ) r) r~i I ..,;5 } t ", ¡ l ) ( ~- » D \ 1]¿> <" I ~ I ) l ~ ~ ; ~ þ R )~ ! I ! \ .1 ( ~~;, ;~ l? ~~ ~ ,). ~) ) ~ t ~ I ( ( \ \.. \,:> t?> \. \ \; I ~¡¡. C r- I A"T"rL- f ( .. 0 LSPD (ftlmln) -100 2.2 MTTP01 (rad) 12.2 I -50 Delta Metal Thickness ('Yo) 50 -6.6 MTTP12 (rad) 3.4 I I I I I I I I I I I I I I I I I I I I <!as. ~D~.,SI!"'!f!I" I""" Magnetic Thickne og o Hz) Database File: Dataset Pathnarne: Presentation Format: Dataset Creation: Charted d:\warrior\data\2n-305\2n305. db 2n305.1 2.2 scale Mon May 1413:20:172007 by Calc Sondex Warrior V7.0 in Feet scaled 1:50 o LSPD (ftlmin) -100 Delta Meta! Thickness (%) 50 ( ( _ UMLt-e- ~- - --.. L 3 > J ,): \ ~j, I" o LSPD (ftlmín) -100 I-50 Delta Metal Thickness (%) 50 2.2 -6.6 ,JuvU Tìf~ f f ;, f It 1 elC rnl. éÞ i ( ( ~ ( 5 _C":;. S 5090 Joint 162 .~, ! 5100 r ) Joint 163 Ii l ( s \ ) : l ). í t~, l 2.2 i-6.6 ..' MTTP01 (rad) MTTP12 (rad) Ir1c:r t f c~ .¿ l) ~ - { ( "" <; .. -----;;; ;;1> ?= ( ) ..;> ( t ) 1 ~ [ 70% Isolated Mi Loss < J? ;;:? i \ ~~ ~} i) ~~ :; ~ _ \ì I lD ~) } ~. ti;f, ~ ~ ' MTTP01 (rad) MTTP12 (red) ~ ( J ( ( 12.2 3.4 ~ ~~ Rr-~ -- ~, : ;> " ( ~ ¡,. ) ~ -\ ~ ( I} ,} ~. ç t ) - - r j\~ kt ~~ h 12.2 3.4 I I I I I I I ~ Magnetic Thicknes og (10Hz) ~ DIAq"""'¡c Sl!lWIc.... INc. Database File: d:\warrior\data\2n-305\2n305. db Dataset Pathname: 2n305.1 Presentation Format: 2.2 scale Dataset Creation: Mon May 1413:20:172007 by Calc Sondex Warrior V70 Charted Depth in Feet scaled 1 :50 0 LSPD (ftlmin) -100 2.2 MTTP01 (rad) 12.2 -50 Delta Metal Thickness (%) 50 -6.6 MTTP12 (rad) 3.4 J¿VU "] ';, ~ .~ ~ ~ " .~) I Joint 103 ) ... -- ~ 3.5" Collar ~ 70% ""'ated Met., <; f--- ~ r=- I -- <; [\~ I. 3270 2> I Ij )- ? , I Line S :>ee ( ( ( ;r-_~/ ~ ~ > 1 \\ ~ -- :? t ) ) ) Joint 104 ~, J I ( C) r 3280 þ l :> ( ):.. ( þ ¡ :;:;. ~t- ~,.~ \. :;: ~ ');,. { > Z S- .- F ~ ? J /j I ~ «; '''í { ( ~: F~ ~ 2 ~~ (> I \ r r f t (:~ ç > ~= I .........,.,"" 0 LSPD (ftlmin) -100 2.2 MTTP01 (fad) 12.2 -50 Delta Metal Thickness (%) 50 -6.6 MTTP12 (fad) 3.4 I I I I I I I I I I I I I I I I I I I I I I I I £s. Magnetic Thickne og (10Hz) p~ DIAq-'¡C SEiIIW::""" I"",. Database File: d:\warrior\data\2n-305\2n305. db Dataset Pathname: 2n305.1 Presentation Format: 2.2 scale Dataset Creation: Man May 1413:20:172007 by Calc Sondex Warrior V70 Charted Depth in Feet scaled 1 :50 - ..~ -.- -. 0 LSPD (ftlmjn) -100 2.2 MTTP01 (rad) 12.2 -50 Delta Metal Thickness (%) 50 -6.6 MTTP12 (rad) 3.4 I I ( ,.1 3 ~ f clilar ) "'" - > I I 1 ''¡; c .- - ( ... 5.5" Collar ¿ .: .- I-- Line 4950 þ ~ <: ç (~ - ( 69% Isolated Mett ~ IS!) 1 } ) I 1Þ .i ~ r ) ~ , -£ .~ ') ;: ~ I l ~ l, j [~ J,. - .., '" .- Joint 158 I I.. ~ t r" >. ~ . ""- ~ ",,- r r (,; ::> rß 4960 )1 ... \ '\ ~= I~ þ j [;> ::c :?' ì j I ( !> ", If ( [) I J ). ì I '" 1 .., ~ c 1'-' .~ - ~? - -~ b-' j...-. 1---- -- I--' C~ > r ~ It r +~1 > I ;: Í ~ f =~f l? 4970 C ;' ! 1<- .<: <; 11i: .~ -= ~ - b ~L..- S ..; 0 LSPD (ftlmin) -100 2.2 MTTP01 (rad) 12.2 -50 Delta Metal Thickness (%) 50 -6.6 MTTP12 (rad) I I I II I I I GasUl! ,nàðlDti~ Valve 1 (2715-2716, OD:4.725) I Ga$Uft màElIDti~ Valve 2 (589!>6000, OD:4.725) I I Gas Uft md'E!IDti~ V¡¡ ve3 (8001-8002, 00:4.725) I I TUBING (0-9395, 00:3500, 10:2.992) I I Gas Uft A and"e!Mive 4 (9331-9332, OD:4.725) I I NIP (9374<)375, 00:3.5(0) I PROD CASING (1).9383, 00:5.500, W!:15.50) I I GUIDE (9395-9396. 00:3.5(0) FRAC (9724-9734) Perf (9724-9734) I I PHilliPS AI a, Inc. A Subsidiary of PHIlliPS PETROLEUM COMPANY KRU 2N-305 . . WELL LOG TRANSMITTAL " ProActive Diagnostic Services, Inc. To: AOGCC Ilen;Jara OldaAa -tlhrl6i-llIle mo..?r.vtl<eIA 333 West 7th Avenue Suite 1 00 Anchorage, Alaska 99501 (907) 659-5102 RE: Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services. Inc. Attn: Robert A. Richey 130 West Intemational Airport Road Suite C Anchorage. AK 99518 Fax: (907) 245-8952 1) 2) 3) 4) 5) 6) 7) 1 Report / EDE 2N - 305 Caliper Report o 1-May-07 srGANNtD MA'í 1 () 2007 RECEIVED Print Name: alL fJhr¡"6fì^l~ lJ1~hlA )((:)Áj '.' MAY 1 0 ZaGl Signed: Date : ~ Oil & Gas C-oos. C,.'"'fOmlssion Aochcmge PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORi.\.GE@MEMORYLOG.COM WEBSITE: WWW.MEMORYLOG.COM D:\Master _ COPL 00_ PDSANC-20xxlZ _ W ord\DistributionITransmittal_ SheetslTransmit_ Original.doc dOC:>- 135 tJ; , 5J I~ I I I I I I I I I I I I I I I I I I I . . Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No, : Run No.: Pipe1 Desc,: Pipe1 Use: ConocoPhillips Alaska, Inc. May 1, 2007 8102 1 3,5" 9,3 Ib, L-80 8RD EUE Tubing Well: Field: State: API No,: Top Log Intvl1,: Bot. Log I ntvl1, : 2N-J05 Kuparuk Alaska 50-103-20349-00 Surface 9,336 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS: This log is tied into the Hanger @ 0' Depth. This log was run to assess the condition of the 3,5" tubing with respect to corrosive and mechanical damages, The 3,5" tubing logged appears to be in good condition, with the exception of a 24% wall penetration in joint 296 at 9,304'. The damage appears mainly in the forms of shallow pitting and shallow corrosion, No significant areas of cross-sectional wall loss or ID restrictions are recorded, 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, A graph illustrating the correlation of recorded damage to borehole profile is included in this report, MAXIMUM RECORDED WALL PENETRATIONS: Line Corrosion Jt. 9,304 Ft. (MD) ( 24%) 296 @ No other significant wall penetrations (> 17%) are recorded, MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 7%) are recorded, MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D, restrictions are recorded, I Field Engineer: R. Richey Witness: C, Fitzpatrick I Analyst: M. Tahtouh PmÞ-,ctive Diagnostic Services, Inc, / P.O, Box 1369, Stafford, TX 77497 D Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@mernorylog,com RECEIVE Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 ' MAY 1 0 Z007 d 6D -(35 :It I S1 I C} i\laska Oil & Gas Cons. Commission Anchorage I I I Well: Field: Company: Country: 2 N-305 Kuparuk ConocoPhillips Alaska, Ine. USA I Tubing: Nom,OD 3,5 ins Weigh t 9.3 f Grade & Thread LoBO 8RD EUE I I Penetration and Metal loss ("Ie wall) penetration body metal loss body I 300 250 200 150 100 50 o 20 to 40 to over 40% 85% 85% I o to 1% 1 to 10% 10 to 20% I o o I pene. loss I Damage Configuration ( body ) 40 I 30 20 I 10 o I isolated genera! line ring hole I pass pitting corrosion corrosÎon corrosion ¡ble hole I o I I S Report Overview Body Region Analysis Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st: Nom.lD 2.992 ins May 1, 2007 MFC UW 24 No, 214320 1.69 24 M. Tahtouh Nom. Upset 3.5 ins Upper len. 6.0 ins lower len, 6.0 ins Damage Profile ("Ie wall) penetration body o o GlM3 GlM2 GlM 1 metal loss body 50 100 Bottom of Survey = 296,2 Analysis Overview page 2 I I I I Pipe 1 I I I I I I I I I I I I I I Correlation of Recorded Damage to Borehole Profile 3,5 in (OS - 9333.7') GlM 1 GlM 2 Q:; ...Q E z 1:: 200 Õ GlM 3 296,2 o I Bottom of Survey = 296,2 I I Well: Field: Company: Country: Survey Date: 2N-305 Kuparuk ConocoPhillips Alaska, Inc. USA May 1, 2007 Approx, Tool Deviation Approx, Borehole Profile 25 50 75 100 125 150 175 225 250 275 50 Damage Profile (% wall) I Tool Deviation (degrees) 4 789 1564 2340 3139 3921 4695 5477 +' L1.. ,S; ..r;; 6271 ã. Q) 0 7050 7829 8626 9334 100 I I PDS REPORT JOINT TABULATION SH I Pipe: Body Wall: Upset Wall: Nominal 1.0,: 3,5 in 9.3 ppf L-80 0.254 in 0,254 in 2,992 in Well: Field: Company: Country: Survey Date: 2N-305 Kuparuk ConocoPhillips Alaska, Inc. USA May 1,2007 I Joint Jt Depth Per Pen, Pe I f\,1etal Min, Damag e Profile No, (Fl.) Body I.D, Comments (% wall) ( (Ins,) (Ins,) 0 50 100 ,1 0 n 0.D1 2,94 PUP 1 4 n 0,02 2,93 , 1.1 36 U 0,02 2,92 PUP 1.2 48 n 0,01 1 2.90 PUP 1.3 59 n 0,02 ( n 2,92 PUP 11II 1.4 64 n oni ;; 2,92 PUP f1I 2 69 ~n 0.02 ) 2.93 , 3 101 n 0,02 I 2,92 !II! 4 132 0 0,03 ì 1 2,92 Shallow niHina, 5 163 0 0.03 n n 2,92 6 194 n om 1) ) 2,94 iii 7 226 0 om ··11 ) 2,92 Shallow "ittina, iii 8 257 n 0.03 12 -I 2,92 , 9 289 , 0,04 1, 4 2,91 Shallow "iHina, , 10 320 , om I , 2,93 Shallow n¡Hina, 11 351 r 0,02 q 1 2,91 12 381 0,03 1 P 2,93 r 13 413 I om 1 ) 2,92 14 444 0 om ¡c ., 2,92 Shallow corrosion, ,11II I 14,1 475 n ° u U N/A Ninnle 15 477 n 0,03 11 1 2,93 Shallow "itti[w, 16 509 0,03 4 2,92 17 539 0,03 2,92 Shallow niHina, 18 570 0.03 2,92 19 601 0,03 2,93 20 633 I) 0,03 11 2,92 21 664 0 0,02 H 2,93 22 695 n 0,02 I¡ 4 2,93 23 727 , 0,03 n 2 2,93 Shallow "iHina, 24 758 1 0,03 11 2 2,92 25 789 ( 0,02 q l 2,92 26 820 ( 0,02 n 2,93 27 851 ( 0,03 I) 2,93 28 882 n 0,02 q 2,94 29 914 n 0,04 .1' I 2.93 Shallow corrosion, 30 945 () 0,03 1 i5 2,93 31 977 n 0,03 1 2,92 32 1008 () 0.03 1 2,94 33 1037 () 0.04 2,Q? Shallow corrosion, 34 1068 n 0,03 2,93 35 1099 0 0.03 2,93 36 1131 0 Ii 1 2,92 37 1162 0 11 4 2,92 Shallow corrosion, 38 1193 n 11 4 2,92 Shallow "ittina, 39 1225 () 4 2,91 Shallow corrosion, 40 1256 n 0,02 2.95 41 1287 0 0,02 q 2,93 42 1319 0 0.03 ') 2,93 43 1348 0 0,04 14 2,93 Shallow corrosion, 44 1378 0 0,02 11 (. 2,94 I I I I I I I I I I I I I Body Metal Loss Body Page 1 I I I PDS REPORT JOINT TABULATION SH I I I Pipe: Body Wall: Upset Wall: Nominal!'D,: 3,5 in 9.3 ppf 1.-80 0,254 in 0,254 in 2,992 in Well: Field: Company: Country: Survey Date: 2N-305 Kuparuk ConocoPhillips Alaska, fne. USA May 1, 2007 I Joint Jt. Depth Ilpl1 Pen, Pel1 \;\etal Min, Damag e Profile No, (Ft.) Body I.D, Comments (% wall) (Ins) (Ins.) (Ins,) ° 50 100 45 1409 I) 0,03 ) 2,92 Shallow nittin2, 46 1439 n 0.ü3 4 2.92 47 1471 I) I 0,03 " 2,93 Shallow oittìn2, 4R 1502 I) 0,03 I h 2,93 49 1533 0 0,03 12 h 2,93 50 1564 0 0,03 13 4 2,92 Shallow corrosion, 51 1594 I) 0,03 ) 2,94 52 1625 I) 0.ü3 2,92 Shallow nitting, 53 1656 I) 0.02 1) 2,91 54 1688 I) 0.02 9 2,92 55 1717 0 0,03 * 2.92 Shallow nittino, 56 1749 0 0.ü3 2,93 57 1777 0 0.03 ?:93 58 1809 0 0,02 2,93 59 1840 I) 0,04 1 2,93 Shallow nittin2, 60 1872 I) 0,03 I 2,93 61 1903 I) 0.ü3 1 2,92 Shallow nittin2, 62 1934 I) 0.03 1 2.92 63 1966 I) 0.ü3 1 2,92 64 1997 0 0,02 n 2,94 65 2028 0 0,02 e 2.93 66 2060 0 0,03 12 ), 2.93 67 2090 I) 0,03 4 2,92 68 2121 () 0.ü2 4 2,94 69 2153 I) 0,02 4 2,92 70 2184 0 0,02 I 2,94 71 2215 0 0.ü2 d. 2,93 72 2247 0 0,02 n ) 2,94 ¡ 73 2278 n 0.ü3 ± ~i 2,92 74 2309 n 0,02 ¡ 2,93 ¡ 75 2340 I) 0,02 1 2,94 76 2371 I) 0,02 2,93 77 2403 0 0,03 2,92 78 2434 0 0.02 2,93 79 2465 0 0.03 ) 2,91 80 2497 n 0.ü3 2 '4 2,94 81 2528 0 0,02 ;I 2,94 I 82 2559 0 0,02 s 2,93 83 2591 0 0,03 ti ) 2,92 84 2622 0 0,03 I: 2,93 I 85 2654 0 0.ü3 ¡; 2,93 85,1 2686 0 0,03 I 2,91 PUP PittímL 85,2 2691 0 ° 0 N/A GLM 1 (Latch @ 6:00\ 85.3 2697 0 0,02 9 -; 2,89 PUP ~ 86 2703 () 0,02 ;; 2,93 87 2735 () 0,02 ) 2,93 88 2765 0 0,02 ) 2,92 89 2796 0 0.02 4 2,94 90 2827 0 0,02 1 2,93 91 2858 0 0,02 1 2,93 ~ I I I I I I I I I I I I Body Metal Loss Body Page 2 I I I I PDS REPORT JOINT TABULATION SH I I Pipe: Body Wall: Upset Wall: Nominall.D,: 3,5 in 9.3 ppf L-80 0,254 in 0,254 in 2,992 in Well: Field: Company: Country: Survey Date: 2N-305 Kuparuk ConocoPhillips Alaska, Inc. USA May 1, 2007 I Joint Jt. Depth F'e Pen, Pen. ;\Aelal Min, Damag e Profile No, (Ft.) (::::";t Body I.D, Comments (% wall) (Ins,) (Ins,) ° 50 100 92 2889 I 0,04 14 4 2,94 Shallow corrosion, 93 2919 ( 0,03 It 4 2,92 Shallow nittinQ, 94 2951 ( 0,02 B 4 2,94 95 2982 ( 0,02 1 2,93 96 3013 0 0,03 j 2,92 97 3044 0 0,02 9 'j 2.92 98 3076 0 0.03 III ) 2,92 99 3107 () 0.01 4 ; 2,94 100 3139 () 0.03 10 4 2.94 101 3170 () 0,04 5 2,93 w nittinQ, 102 3202 {) 0.02 2,93 103 3233 {) ~ 2,94 104 3264 {) 3 2,93 Shallow "ittin\!, 105 3295 0 2,95 106 3326 {) 0,02 B It 2.94 107 3357 0 0,03 13 :f 2,94 Shallow corrosion, 108 3389 {) 0.03 I F) ;.> 2.90 109 3420 () 0.02 ( 2,94 110 3452 () 0,02 2,94 111 3483 () 0,01 2,94 112 3512 () 0.03 11 2,94 113 3544 0 0,02 B my 2,95 114 3575 0 0,02 B ;I 2,94 115 3605 0 0,03 I 4 2,93 116 3637 {) 0,03 2.92 117 3668 0 0,02 2.92 118 3700 ( 0,03 2,93 119 3734 ( 0,03 2,95 ~ 120 3765 0 0,04 2,93 ShaHow nittin<=>, 121 3796 0 0,03 1 () 2.93 122 3827 {) 0.03 1 () 2,91 123 3859 0 0,03 ¡ 2,93 I Shallow nittinQ, ) 124 3890 0 0,03 1 2,93 125 3921 () 0,03 1 2,95 126 3952 () 0.03 1 2,93 ShaHow nittinQ, 127 3983 0 0,03 1 2,94 Shallow corrosion. 128 4013 0 0,02 ß 2,94 129 4044 0 0.03 12 1 2,92 130 4076 () 0,02 ) 2,93 131 4107 0 0,02 ;.> 2,92 132 4138 0 0,02 1 2,94 133 4168 ii=tli 2 2.93 134 4199 1 2,94 135 4230 II ;.> 2,93 13fì ! 4262 o 0.02 I 2,93 137 4293 ( 0,03 1 2,94 138 4324 ( 0.03 2 2,92 139 4355 ( 0,02 2,93 140 4387 ( 0,02 2,94 141 4419 0 0,03 2.93 I I I I I I I I I I I I I Body Metal Loss Body Page 3 I I I PDS REPORT JOINT TABULATION S I I Pipe: Body Wall: Upset Wall: Nominall.D,: 3.5 in 9.3 ppf 1.-80 0.254 in 0,254 in 2,992 in Well: field: Company: Country: Survey Date: 2 N-305 Kuparuk ConocoPhillips Alaska, Inc. USA May 1, 2007 I Joint Jt. Depth Pc' Pen, Pen. I~ Min, Damag e Profile No, (Ft.) '1 Body I.D, Comments (% wall) (Ins) (Ins,) (Ins,) ° 50 100 142 4448 0 0,03 10 2,91 143 4479 0 0,04 14 2,92 Shallow oittirm, 144 4510 0 0.02 ;;' 2,93 145 4542 0 0.ü2 1 2,94 146 4571 í1 0,02 ) 2,92 147 4603 0,02 ) 2,91 148 4634 0,02 ) 2.93 149 4665 0,02 I 2.94 150 4695 0,02 ¡., 2,93 151 4728 0,02 ) 2,94 152 4759 0 0,02 =+=++2,93 153 4790 0 0,02 2,94 154 4821 0 0,02 a 2,93 155 4852 í1 0.ü2 1 2,94 156 4882 I 0,01 ) 2,94 157 4914 0,02 ) 2,92 ¡¡¡g 158 4946 ( 0,03 ') ) 2,92 159 4978 ( 0,02 1 2,92 160 5009 0 0,03 12 1 2,92 Shallow nittìnp, 161 5040 0 0,03 10 ) ? 92 162 5071 í1 0,02 ì ii.JS 163 5103 í1 0,02 ( ) ?9? 164 5134 0 0,02 ¡ 1 2,93 165 5165 0 ~ 2,93 166 5196 0 03 I 2,93 167 5227 0 02 B 2.94 168 5258 0 .0414 2,92 Shallow corrosion. JII 169 5290 0 0,02 9 cl 2,93 170 5321 0 0.ü2 B ;! 2,93 171 5352 í1 0,02 f 'I 2.93 172 5383 0 0,03 1 D ) 2,93 173 5414 0 0.03 1 4 2,91 174 5446 0 0,03 1) , 2,92 , 175 5477 0 0,02 ;;' ) 2,94 176 5509 0 0,03 10 ) 2,93 177 5540 0 0,03 ,1 ) 2,91 178 5572 I 0,02 7 ) 2,92 179 5602 I 0,02 4 2,92 180 5631 ( 0.03 Ii 2,91 181 5663 ( 0,02 1 2,94 182 5694 ( I 0,03 I, 2,92 183 5726 0 0,02 B ) 2.94 184 5757 0 0,02 ß n 2.93 185 5787 0 0,03 12 ,> 2,92 186 5819 í1 0,03 1) ,> 2,92 Shallow nitting. 187 5851 0 0,02 =+ I 2,94 187,1 5879 Ii 0.02 i 2,89 PUP 187,2 5887 0 ° n N/A GlM 2 (latch @ 3:00\ 187.3 5894 ( 0,03 11 I 2,92 PUP !II 188 5899 ( 0.03 I ) 2,92 !II I I I I I I I I I I I I I I Body Metal loss Body Page 4 I I PDS REPORT JOINT TABULATION S EET I I I I Pipe: Body Wall: Upset Wall: Nominal I.D.: 3,5 in 9.3 ppf 1.-80 0,254 in 0,254 in 2,992 in Well: Field: Company: Coun try: Survey Date: 2N-305 Kuparuk ConocoPhillips Alaska, Inc. USA May 1, 2007 I I I I I I Joint jt Depth Pel Pen, Pen. ! tv\¡::t;;T Min, Damag e Profile No, (Fl.) Body 1.1), Comments (% wall) (Ins) (Ins,) (Ins,) 0 50 100 189 5930 0 0.03 () ') 2,92 11III 190 5961 0 0,02 I ! 7,93 191 5991 () 0.02 I 2,95 !III 192 6020 0 0,04 4 4 2,92 Shallow oittín2:, . 193 6052 0 0,04 15 ;; 2.91 Shallow corrosion, I 194 6nRi 0 0,03 13 4 2,92 Shallow corrosion, 195 6114 0 0,02 B 1 m 196 6144 0 0,03 L 197 6177 () 0.03 1 198 6208 () 0,02 199 6239 [) 0,02 2,93 200 6271 [) 0,03 2,92 201 6303 [) 0.03 '1 2,92 202 6335 () 0,03 13 ) 2,91 Shallow nittinp, 203 6366 0,02 ') 2.93 204 6396 0.D1 I 2,95 205 0,03 4 2,91 Shallow nitting, 206 6459 I 0,02 , 2,94 ¡ 207 6490 0 0,02 B ') 2,93 208 6521 0 0,02 ß ) 2,93 209 6552 0 0.02 8 ') 2,91 210 6584 0 0,02 ( ') 2,93 211 6615 I 0,02 2,93 212 6646 I 0,02 2.91 213 6678 I 0,03 I 2,94 214 6708 I 0,02 f 2,93 215 6738 I 0,03 I 2,91 11II 216 6770 0 i ß 2.93 " 217 6801 0 ß I 2,93 . 218 6833 0 ì1 (, 2,92 219 6864 0 ') 2,94 220 6893 0.03 4 2,93 221 6925 I 0,02 I 2.95 222 6957 0.02 ') 2.95 223 6989 0.02 ') 2,92 224 7020 0 0,02 ß ') 2,93 225 7050 0 0,02 ) ') 2,93 226 7082 0 0,02 ') 2,93 227 7114 () 0,02 ') 2,94 228 7144 0 0,02 I 2,95 229 7176 0 0,03 1 ) 2,93 230 7208 0 0,02 ') 2.95 231 7238 0 0,02 I 2,94 232 7270 0 0,02 ß i 2,93 233 7302 0 0,02 ß ;, 2,93 234 7334 n =tI3 1 2.93 235 7364 o 3 2.92 Shallow nitting, 236 7395 o 02 2.93 237 7427 o 0,02 2,93 238 7459 0 0.03 2,93 I I I I I I I Body Metal Loss Body Page 5 I I PDS REPORT JOINT TABU ONSH I Pipe: Body Wall: Upset Wall: Nominall.D,: 3,5 in 9.3 ppf 1.-80 0,254 in 0,254 in 2,992 in Well: Field: Company: Country: Survey Date: 2 N-305 Kuparuk ConocoPhillips Alaska, inc. USA May 1, 2007 I Joint Jt. Depth Pc Pen, Pen. Mi.,!;]1 Min, Damag e Profile No, (Ft.) ,! Body !.D, Comments (% wall) ( .) (Ins,) (Ins,) 0 50 100 239 7490 0 0,02 9 ;: 2,93 240 7521 n 0.03 1) ) 2,93 241 7552 n 0,03 II 2,92 242 7582 n 0,02 5 2,93 243 7614 0 0.02 2 2,93 244 7645 0 0,02 2 2,93 245 7676 0 0.ü2 2 2,93 246 7707 l. 0,02 2 2,93 247 7738 U 0,02 ;: 2,93 248 7769 n 0.03 13 ;: 2,92 Shallow pitting. 249 7798 0,03 11 (, 2,93 Shallow corrosion. 250 7829 0,03 1 2 2.93 251 7860 0.03 2 2,94 Shallow pittimL 252 7892 0.03 II 2,93 253 7924 n 0,03 13±+ 2,90 Shallow pitting, 254 7955 U 0.03 =tlH Shallow pitting, "" 254,1 7985 () 0.03 2, PUP Shallow pittimI, 254,2 7992 () ° ° 0 N/A GLM 3 (Latch @ 3:30\ 254.3 7998 n 0,03 13 2 2,91 PUP Shallow oittim!:, 255 8005 () 0,02 9 2 2,93 256 8036 0 0,03 2 2.92 Shallow pittim!, 257 8068 () 0,03 2,93 258 8098 U 0.04 2,93 Shallow pitting, 259 8129 U 0,02 2,94 260 8161 () 0,03 2,94 261 8193 n 0,04 15 II 2,91 Shallow corrosion. 262 8224 () 0,03 11 II 2,92 Shallow oittimI. 263 8254 0 0,03 10 II 2,92 264 8286 0 0,03 2,92 265 8318 0 0,03 2,93 266 8347 ( 0,03 2,92 267 8378 0 0,03 2,92 268 8410 0.03 13 2,93 Shallow oitting, 269 8441 0,04 17 () 2,92 Shallow corrosion, 270 8472 ( 0,03 2,92 271 8503 ( 0.03 2,93 272 8534 ( 0,04 2.94 Shallow corrosion, 273 8565 0 0.03 2,93 274 8595 0 0,03 2,93 275 8626 0 0,02 9 2,93 276 8658 0 0,02 9 1 2,94 277 8689 i) 0,03 12 3 2.91 I 278 8721 0 0,04 4 3 2,92 Shallow oittim!., 279 8752 0 0.04 II 2,91 Shallow pitting. I 280 8783 0 0,03 3 2.92 Shallow corrosion, 281 8815 0 0,02 1 2.93 282 8845 () 0,02 ;: 2,91 283 8878 () 0,02 ( ;: 2,93 284 8909 () 0,04 I:> II 2,92 Shallow pittim!., 285 8941 0 0,02 8 2 2,92 I I I I I I I I I I I I I Body Metal Loss Body Page 6 I I I I PDS REPORT JOINT TABULATION 5 I I Pipe: Body Wall: Upset Wall: Nominall.D,: 3,5 in 9.3 ppf 1.-80 0.254 in 0,254 in 2,992 in Well: Field: Company: Country: Survey Date: 2N-305 Kuparuk ConocoPhillips Alaska, Ine. USA May 1, 2007 I Joint Jt. Depth Pen. Pen, Pen. ,vle'!al Min, Damage Profile No, (Ft.) ,! Body ID, Comments (%wall) ( (Ins,) (Ins,) ° 50 100 286 8972 () 0,02 9 4 2,90 287 9004 () 0.02 :' 2,93 288 9035 0 0,02 2 2,95 289 9067 0 0,02 2 2,94 290 9098 D~ 2 2.93 291 9129 CI ,03 2,93 292 9160 II 0,02 2,94 293 9191 0 0,03 I 2,91 294 9223 U 0,02 9 2,93 295 9254 0 0.04 '¡ 2.91 Shallow corrosion, 295,1 9285 0 ° 0 N/A SLIDING SLEEVE 296 9288 0 0,06 4 3 2,92 line corrosion. 296,1 9323 U ° 0 N/A PACKER 296,2 9334 0 0,00 2 2,94 PUP I I I I I I I I Body Metal loss Body I I I I I I Page 7 ............ .............. .. .... .. .. .. PDS Report ross Secti ns Well: field: Company: Country: Tubin : 2 ,"i-305 Kuparuk ConocoPhillips Alaska, Inc. USA 3,5 ins 9.3 f L-80 Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st: May 1, 2007 MFC UW 24 No, 214320 1.69 24 M. Tahtouh Cross Section for Joint 296 at depth 9304.083 ft Tool speed = 43 Nominal 10 = 2.992 Nominal 00 = 3.500 Remaining wall area = 98 % Tool deviation = 82 0 Finger 8 Penetration 0.062 ins Line Corrosion 0.06 ins = 24% Wall Penetration HIGH SIDE = UP Cross Sections page 1 I PHilliPS Alaska, Inc. A SUbsidiary of PHilLIPS PETROLEUM COMPANY 2N-305 I I GasUft In<ièlDumm; Valve 1 (2715-2716, 004.725) I Gas Uft ,n<ièlDumm; Valve 2 (5899-5900, 004.725) I I Gas Uft Ind'èlDumm; Valve 3 (8001-<JOO2, 004.725) I I TUBING (0-9395, 003500, 102.992) I I GasUft A and'ell\fflIV€ 4 (9331-9332, 004725) I I NIP (9374-9375, 003.500) I PROD CASING (0-9383, 00:5.500, Wt15.50) I I I GUIDE (9395-B396, 003.500) I FRAC (9724-9734) Perf (9724-9734) I I KRU Rev Reason: Grade H-40 L-BO LBO L-BO Thread WELDED STCM BTC MOD BRD EUE Ç) 11/10106 Sc~luInbepger NO. 4034 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth NOV :1 3 2006 P. G~~ COOS, (Xl\Ylmi~.,ioil Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 eCO-/3S- Field: Kuparuk Well Job# Log Description BL Color CD Date 1 R·26 11416225 INJECTION PROFILE 10/23/06 1 1 R-22A 11416224 PROD PROFILE W/DEFT 10/22/06 1 2K.28 N/A INJECTION PROFILE 10/19/06 1 3G-09 11415642 PROD PROFILE W/DEFT 10/24/06 1 3G~16 11416226 INJECTION PROFILE 10/24/06 1 2P.-427 11415637 INJECTION PROFILE 10/20/06 1 2P-429 11415640 INJECTION PROFILE 10/22/06 1 1J"101 11445123 GLS 11/06/06 1 2P-432 11415644 INJECTION PROFILE 10/26/06 1 3G-09 11415645 PROD PROFILE WIDEFT 10/27/06 1 3K-19 11415648 INJECTION PROFILE 10/30/06 1 2W-12 11445122 PROD PROFILE W/DEFT 11/05/06 1 1R-19A 11416228 INJECTION PROFILE 10/27/06 1 3J'05 1141630 INJECTION PROFILE 10/28/06 1 1 D-04 11445121 PROD PROFILE W/DEFT 11/04/06 1 30-07 11416222 INJECTION PROFILE 10/20/06 1 2N..305 11416223 FLOWING BHP SURVEY 10/31/06 1 3A-12 11445120 GLS 11/03/06 1 2L-311 11415649 FLOWING BHP SURVEY 10/31/06 1 2l:-313 11445119 FLOWING BHP SURVEY 11/02/06 1 2Kr27 11416234 FLOWING BHP SURVEY 11/02/06 1 2L-307 11296734 FLOWING BHP SURVEY 11/04/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . Schlomberger NO. 3443 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth 08/03/05 ~()"O- t~ SC,i'\NNECc $EP (1 2, 2005 Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job# Log Description Date BL i./2N-305JOO·/)S- 11047348 SBHP SURVEY 07/25/05 1 J2N-308 1 t(<\ -Ojt. 11047344 SBHP SURVEY 07/24/05 1 j 2N-317 I q ~A N? 11047345 SBHP SURVEY 07/24/05 1 v 2G-06 I 3 ~( - Co ).. 11022913 FLOWING BHP 07/20/05 1 J 1 Y -04 ì ~f~ - fj ~ l 11047351 INJECTION PROFILE vie. 07/27/05 1 J.3J-10 i\'i-J-çõ 11058227 MULTI-FINGER CALIPER LOG 07/18/05 1 /2U-10 ~)- tY{ 11047352 PRODUCTION PROFILE WIDEFT 07/28/05 1 ~1C-178 ~3-l<11 11022908 PRODUCTION PROFILE WIDEFT 07/14/05 1 SIGNED: ; "Î /~' ;'''':''' I / j /' . ,I I ~ .t' ! J I /1 / f if . ;I:/No (/ ít,if..--d I DATE: Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Kuparuk Color CD '-.-' '-~ /; \ ~_\ \.) s.~( /"- ~ ~~ F:\LaserFiehe\CvrPgs _I nserts\M ierofi I m _ Marker.doe MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE .'I~,It... '\ , ) Re: Je[ Pumped Wells Subject: Re: Jet Pumped vVeIls From: "NSK Problem Well Sup"" <n 1617(@eonoeophillips.eom> Date: Sat, 7 Dee 2002 14:07:01 -0900 To: TOtTI Maunder <tom_nlaunder@'admin.state.ak.us> CC: "n 1617" <n 1617@eonoeophillips.eonl> Tom: I requested a lIst of surface powered jet pump wells from our PEls. The following should be the current total for the Kuparuk area: West Sak wells: lC-123 (PTD 2010840) was recently S1 for high watercut lC-135 (PTD 2012200) is a huff and puff well and was recently put on water injection cycle CPF 2 are as follows: 2L-307 (PTD 1982560) 2 L - 3 13 (PTD 1982190) 2 L - 3 15 (PTD 1 98 2 18 0 ) 2L-321 (PTD 1982620) 2L-325 (PTD 1982090) 2N-303 (PTD 2001690) 2N-304 (PTD 2011300) '~~2N-305 (PTD 2001350) 2N-318 (PTD 2001000) 2N-319 (PTD 1981970) 2N-332 (PTD 2000790) 2N-337 (PTD 1981220) 2N-339 (PTD 1981000) 2P-415 (PTD 2012260) There are no surface powered jet pump wells at CPF3. 1 hope this answers your question. Let me know if you need more information. Jerry Dethlefs ConocoPhillips Problem Well Supervisor Tom Maunder <tom maunde.t-';¡;'adrnin. state. ak. us> 12/06/2002 09:00 þ~ To: NSK Problem Well Supv/PPCO@Phillips cc: Subject: Jet Pumped Wells Pete and or Jerry, I have some emails fr h'l b om aWl e ack regarding the wells out there on Jet pumps. Would you please provide an updated listing of the wel18 presently on jet pumps In greater KRU?? Thanks in advance. Tom DATA SUBMITTAL COMPLIANCE REPORT 111612003 Permit to Drill 2001350 Well Name/No. KUPARUK RIV U TARN 2N-305 Operator CONOCOPHILLIPS ALASKA INC APl No. 50-103-20349-00-00 MD 10334 TVD 5682 Completion Dat 10115/2000 · Completion Statu 1-OIL Current Status 1-OIL UIC N ................................... '-~ .......................... . "'-;..--.-.. '..-. ~ ~--~'.'~',:.7__. .--'.- 'i, -'i- ~i- -.'-' . i .................... - -.'.'7 ~ . .~-..' ...................... ---.'.'T-. - -~.' ............ , ..................................... _. REQUIRED INFORMATION Mud Log No Sample No Directional Survey ............... __ .................. :~ .' - ~_~__~____'."-'~'~-'__~..~'-__-' "" '~.~'~'."';' £'-'__- .... '~.-~.:~-- - .-~-7.:'--'~--". ....................... -.7..-.-~. -T'.'.'~.- - ..~-__-_'£_-~"-~--2_"- -~.~.'~'.'7'~ ..... -- ................... DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt (data taken from Logs Portion of Master Well Data Maint Interval Log Log Run OH I Dataset Name Scale Media No Start Stop CH Received Number Comments D D L L L L L L L L R R D D D D R R D D R R T L L R R Directional Survey FINAL CH 6/14/2001 Directional Survey, Digital Data .~I~GR/RES 2/5 FINAL 0 10334 OH 7/2/2001 0-10334 BL, Sepia /~D/j~t;/h(~/-6-~334/'C''~''~L, Sepia~-""~5 FINAL 0 10334 OH 7/2/2001 0-10334 EL, Sepia '~u.t~"~/O'GR/DEN/.NEU 2/5 FINAL 0 10334 OH 7/2/2001 0-10334 BL, Sepia ,..~R/DEN/NEU 2/5 FINAL 0 10334 OH 7/2/2001 0-10334 LIS Verification FINAL 2930 10273 OH 6/14/2001 2930-10273, Paper Copy ~ FINAL 2930 10273 OH 6/14/2001 10245~'9'~0-10273 Digital Data (;)i~ctional Survey FINAL OH 6/14/2001 IIFR Survey, Digital Data ~O~rectional Survey FINAL OH 6/14/2001 Dir Survey, Paper Copy ,[~ectional Survey FINAL Oh 6/14/2001 MWD Survey, Digital Data .,,~mctional Survey FINAL OH 6/14/2001 ../Dir Survey, Paper Copy .~2-930 10273 Open 8/20/2001 10245 ' 2930-10273 s~P/SBHT ' 5 FINAL 11900 12350 CH 1/3/2001 11900-12350 BL, Sepia ,,Directional Survey FINAL CH 6/14/2001 Directional Survey, Paper Copy Well Cores/Samples Information: Name Start Interval Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Permit to Drill 2001350 MD 10334 TVD Well Cored? Y ~) Chips Received? ~ Analysis ~ ,~u_ R~.n~.iv~.d'~ DATA SUBMITTAL COMPLIANCE REPORT 111612003 Well Name/No. KUPARUK RIV U TARN 2N-305 Operator CONOCOPHILLIPS ALASKA INC 5682 Completion Dat 10/15/2000 Completion Statu 1-OIL Current Status 1-OIL Daily History Received? ~)N Formation Tops ~'/ N APl No. 50-103-20349-00-00 UIC N Comments: Compliance Reviewed By: Date: ........... PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 995100360 R. Thomas Phone (907) 265-6830 Fax: (907) 265-6224 January 16, 2002 Cammy Oechsli Taylor Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Kuparuk Area Annular Disposal, Fourth Quarter, 2001 Dear Commissioner: Please find attached the report with the volumes disposed into surface casing by production casing annuli during the fourth quarter of 2001, as well as total volumes disposed into annuli for which' disposal authorization expired during the fourth quarter of 2001. Please call mc at 265-6830 should you have any questions. Sincerely, R. Thomas Greater Kupamk Team Leader RT/skad · Marty LemOn Mike Mooney Paul Mazzolini Chip Alvord Kupamk Environmental: Engel / Snodgrass B. Morrison and M. Cunningham Sharon Allsup-Drake . Well Files Annular Din ,osal durin ~ the fourth !:m__rter of 2001: h(l) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes CD2-42 2193 100 0 2293 385 31314 33992 June October CD2-15, CD2-24, CD2-33 2001 2001 2P-417 5331 100 0 5431 0 627 6058 Sept 2001 December 2P-420, 2P-448 2001 CD2-24 2981 100 0 3081 375 30543 33999 July 2001 October CD2-15, CD2-33, CD2-39, 2001 CD2-14 1C-16 12338 100 0 12438 0 19679 32117 Sept 2OOl October 1C-131, 1C-125, 1C-102 ~ 2001 CD2-39 27400 100 0 27500 379 0 27879 October November GD2-15,.CD2-47 2001 2001 CD2-14 14359 100 0 14459 376 0 14835 November December ~D2-45, CD247 2001 2001 1C-14 22389 100 0 22489 0 0 22489 Oct 2OOl Nov 2001 1C-109 2P~38 30331 100 0 30431 212 0 30643 Oct2001 Dec 2OOl 2P-420, 2P-415, 2P-429 CD2.1~ 0 0 0 0 371 0. 371 NA* NA* · *.Freeze protect CD2-15 only ~'~ CD247 10315 100 0 10415 375 0 10790 Dec2001 Dec2001 CD2-34' Total Volumes into Anr_,_di for which Disposal Authorization ~xptrea aunn$ me lourtn {,uaner ztn~ : Freeze Protect Total Volume Start End Source Wells Total h(l) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status Of Annulus 21.-3!3 26290 100 0 0 26390 Open, Freeze'Protected March 1999 Dee 2000 2L-317, 2L-307 1D-36 30104 100 0 0 30204 Open, Freeze Protected Oct 2000 Nov 2000 1D-42, ID-34 CDI-31 6698 100 0 392 7190 Open, Freeze Protected Feb 200'1 March CDI-14 2001 2N-305 0 0 0 380 380 Open, Freeze Protected NA** NA** ** h~eze protect volumes only 1D-34 31915 100 0 218 32233 Open, Freeze Protected Nov 2000 Dec 2000 ID-32, 1D-40A 2N-349A 0 0 0 0 0 Open, Freeze Protected ...... 1D-42 32040 100 0 265 32405 Open, Freeze Protected Dec 2000 Jan 2001 1D-37, 1D-39 'Z Annular Disoosal durin the fourth quarter of 2001: h(l ) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes CD2-42 2193 100 0 2293 385 31314 33992 June October CD2-15, CD2-24, CD2-33 2001 2001 2P-417 5331 100 0 5431 0 627 6058 Sept 2001 December 2P-420, 2P-448 2001 CD2-24 2981 100 0 3081 375 30543 33999 July 2001 October CD2-15, CD2-33, CD2-39, 2001 CD2-14 1C-16 12338 100 0 12438 0 19679 32117 Sept 2001 October 1C-131, 1C-125, 1C-102 2001 CD2-39 27400 100 0 27500 379 0 27879 October November CD2-15, CD2-47 2001 2001 CD2-i4 14359 100 0 14459 376 0 14835 November December CD2-45, CD2-47 2001 2001 IC-14 22389 100 0 22489 0 0 22489 Oct 2001 Nov 2001 1C-109 - 2P-438 30331 100 0 30431 212 0 30643 Oct2001 Dec2001 2P-420, 2P-415, 2P-429 CD2-15 0 0 0 0 371 0 371 NA* NA* *Freeze protect CD2-15 only CD2-47' 10315 100 0 10415 375 0 10790 Dec 2001 Dec 2001 CD2-34 t otat votumes mto nnnuu,lor wntcn ~,tsposat ,autnorlzatton ~.xptrea aunng tnefourtn ~ruarter zeal1: Freeze Protect Total Volume Start End Source Wells Total h(l) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus 2L-313 26290 100 0 0 26390 Open, Freeze Protected March 1999 Dec 2000 2L-317, 2L-307 ID-36 30104 100 0 0 30204 Open, Freeze Protected Oct 2000 Nov 2000 1D-42, 1D-34 CDI-31 6698 ' 100 0 392 7190 Open, Freeze Protected Feb 2001 March CDI-14 2001 "' 2N'305 0 0 0 380 380 Open, Freeze Protected NA** NA** ** freeze protect __, ~, ,, volumes only I !)-34 31915 100 0 218 32233 Open, Freeze Protected Nov 2000 Dec 2000 1D-32, ID-40A 2 N-.M9 A 0 0 0 0 0 Open, Freeze Protected ...... ......... 11.)-4~ 32040 100 0 265 32405 Open, Freeze Protected Dec 2000 Jan 2001 1D-37, 1D-39 3-Aug-01 AOGCC 333W 7th Ave Suite 100 Anchorage, AK, 99501 To whom it may concern, Included in this package are disks for the following final surveys as requested. · 2N-303, IFR and MWD · 2N-305, IFR and MWD · 2N-349, IFR and MWD · 2N-349A, IFR and MWD If you have any questions or concerns please do not hesitate to call. Regards, -Vic Eppler SSDS IFR/SMS (907) 273-3564 RECEIVED AUG0 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 June 29, 2001 RE: MWD Formation Evaluation Logs 2N-305, AK-MM-00189 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 2" x 5" MD Resistivity & Gamma Ray Logs: 50-103-20349-00 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-103-20349-00 . 2"x 5".MD Neutron & Density Logs: 50-103-20349-00 2" x. 5" TVD Neutron & Density Logs: .50-103-20349-00 1 Blueline . 1 Rolled Sepia 1 Blueline' 1 Rolled SePia 1 Blueline 1 Rolled Sepia' 1 Blueline ' 1 Rolled.Sepia RECEIVED Jill 0'2: 13-J un-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definitive Survey Re: Distribution of Survey Data for Well 2N-305 Dear Dear SidMadam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 'MD 10,334.00' MD (if'applicable Please call me at 273-3545 if you have.any questions or concerns. Regards,' .William T. Allen Survey Manager Attachment(s) RECEIVe.,... JUN 1 4 2001 WELL LOG TRANSMITTAL To: State of Alaska June 7, 2001 Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 MWD Formation Evaluation Logs 2N-305, AK-MM-00189 1 LDWG formatted.Disc with verification listing. API#: 50-103-20349-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND .RETURNING THE ATTACHED COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: RECEIVED JUN 14 2001 Almlm Oil & Gas ~ons. Commbeion 13-Jun-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 2N-305 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 'MD 10,334.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED JUN 1 4 2001 Alaska Oil & Gas Cons. Commission Ancha~e PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 January 23, 2001 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conse .rvation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Kuparuk Area Annular Disposal, Fourth Quarter, 2000 (Revision 1) Dear Ms. Mahan: Please find the revised report below with the volumes disposed into surface casing by production casing annuli during the fourth quarter of 2000, as well as' total volumes disposed into annuli for which disposal authorization expired during the fourth quarter of 2000. The revision is for the annulus of Well 1D-42. An annular disposal report for 12/26/00 of 2437 barrels was not counted in the total for the Quarter. The revised total for Well 1D-42 is 15,118 from 12,681 barrels as noted in the table below. ,. Annular Disposal durin~ th, ;fourth quarter, of 2000: 'h(1)" 'h(2)" h~3) Total for Previous New Well Name Volume Volume Volume Quarter Total Total ~ 2N-343 13713 100 0 13813 17995 31808 2L-313 9017 100 0 9117 17273 26390 CD1-45 26735 100 0 26835 5501 32336 CD1-42 . 26447 100 0 26547 4807 31354 - CD1-44 22410 100 0 22510 0 22510 2N-347 16434 100 0 16534 15106 31640 1D-30 1030 100 0 1130 30592 31722 2N-318 " 1199 100 0 1299 320 1619 1D-36 30104 100 0 30204 0 30204 2N-305 280 100 0 380 0 380 1D-34 32133 100 0 32233 0 32233 1D-42 15018 100 0 15118 0 15118 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office BOX 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 3anuary 19, 2001 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Kupamk. Area Annular.Disposal, Fourth QUarter, 2000 Dear Ms.'Mahan: Please find reported below the volumes injected into surface casing by. production casing annuli during the fourth quarter of 2000, as well as total volumes injected into annuli for whiCh disposal authorization expired during the fourth quarter of 2000. '! ~g-'oq 2.. I.qg - z.~ q .. Annular Disposal.during .the.fourth quarter of 2000: lO.q- ~,o°- 1'5o " h(1)' h(2)' hi3) Totalfor Previous New Well Name Volume Volume Volume Quarter 'Total 'Total 2N-343 13713 100 0 13813 17995 '31808 2L-313 9017 100 0 9117 17273 .26390 CD1-45 26735 .100 . 0 26835. 5501 32336 CD1,42 26447 100 0 26547 4807 3'1354 . CD1-44 22410' 100 0 22510 0 22510 .2N-347 16434 100 0 16534 15106. 31640' 1D-30 1030 '100 0 1130 30592 ' 31722'. 2N-318 1199 .100 0 1299 320' 1619 · 1D-36 . 30104 100 0 30204. 0 30204. 2N-305 280 100' 0 380 0 380. 1D-34 32133 100 0 32233 0 32233' 1D-42 12581 100 . 0 12681. 0 12681 Ms. Wendy Mahan AOGCC Fourth Quarter 2000 Annular Disposal Report Page Two Total Volumes into Annuli for which Disposal Authorization Expired during the fourth quarter 2000: Total Total h(1) Total h(2) Total h(3) Volume Well Name Volume Volume Volume Injected Status of Annulu~ CDI-16 28950 100 0 29050 Open, Freeze Protected ,,. CD1-45 32236 100 0 32336 Open, Freeze Protected CD 1-32 33413 1 O0 0 33513 Open, Freeze Protected CD1-42 31234 100 0 31334 Open, Freeze Protected CD 1-36 33567 100 0 33667 Open, Freeze Protected )99- I~ ! Please call me at 263-4603 should you have any questions. Sincerely, 'Paul Mazzolini Drilling Team Leader CC: Marty Lemon Mike Mooney Paul Mazzolini Randy Thomas Chip Alvord Scott Reynolds Kuparuk Environmental': Engel / Snodgrass B. Morrison and M. Winfree Sharon Allsup-Drake Well Files PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Poet Office Box 100360 Anchorage, Alaska 99510-0360 J. Trantham Phone (907) 265-6434 Fax: (907) 265-6224 November 29, 2000 Mr. Daniel T. Seamount, Jr. Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Completion Report for 2N-305 (200-135) Dear Mr. Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the recent drilling operations on 2N-305. If you have any questions regarding this matter, please contact me at 265-6434 or Brian Noel at 265- 6979. Sincerely, J. Tranthamt Drilling Engineering Supervisor PA1 Drilling JT/skad 30 t000 Alaska 0it & ~as Cons. Commissio~ AnChOrage STATE OF ALASKA ( ' ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1: Status of well Classification of Service Well 0,, E] ~ D S,,,an~d D ~ando.~ D s~co D 2. Name of Operator 7. Permit Number Phillips Alaska, Inc. 200-135 / 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50-103-20349-00 4. Location of well at sudace ~ ......................... : 9. Unit or Lease Name ~ .... "'" ....... ; Kuparuk River Unit 6' FNL, 529' FEL, Sec. 3, T9N, R7E, UM (ASP: 461064, 5912001) At Top Pmdudng Interval ~/_'(-~'/_~'.C-'-'-'-'-'-'-'-'-~ ~ 10. Well Number 2155' FSL, 324' FWL, Sec. 26, T10N, R7E, UM (ASP: 461944, 5919437 ) i'. ' ~"~" ~'~ 'i 2N-305 At Total Depth ..... ~ 11. Field and Pool 2552' FNL, 345' FWL, Sec. 26, T10N, R7E, UM (ASP: 461967, 5920010) ~- ...................... Kuparuk River Field 5. Elevation in feet (Indicate KB, DF, etc.) 16. Lease Designation and Serial No. Tarn Pool RKB 35', Pad 119 feetI ADL 380053, 380054 & 375074, ALK 4601 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., ,S.j~p. O,~Aband. ~15. Water Depth, if offshore 16. No. of Completions September 19, 2000 October 3, 2000 Octob..q~, 20~ 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Suwey 120. Depth where SSSV set 21. Thickness of Permafrost 10334' MD /5682' TVD 10200' MD 15614' TVD YES r~! No DI NIA feet MD 1249' 22. Type Electric or Other Logs Run GR/Res/Den/Neu, CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 16" 62.5~ H-40 Surface 118' 24" 8 cu yds High Early 7.625" 29.7# L-80 Surface 3026' 9.875" 330 sx AS III Ute, 240 sx Class G 5.5" X 15.5# L-80 Surface 9383' 7.5" 17o sx Class G & 520 sx Class G 3.5" 9.3# L-80 9383' 10328' 7.5" (Included above) 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD intewaJ, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5' 9396' 9383' (CSR) 9724'-9734' MD 5372'- 5377' TVD 4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. RECEIVED DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9724'-9734' Pump 170M#s pmppant behind pipe, N0V :5 0 .000 ,e, 530# proppant in wellbore 27. AlasKa UII ~. ;c~o u ....... 1~l~l~)'50b-TIOU TEST Date First Production Method~b~t1~Pa~ (Flowing, gas lift, etc.) October 25, 2000 Gas Lift Oil Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO 11/24/2000 6.0 Test Pedod > 421 304 0 100I 748 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (coif) press 429 psi 1093 !24-Hour Rate > 1353 1013 2 not available 28. CORE DATA Brief description of Ilthology, porosity, fractures, apparent dips and pmssence of oil, gas or water. Submit corn chips. N/A Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE ORIGINAL Submit In duplicate NAME Include interval tested, pressure data, all fluids recovered and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. T-3 9592' 53O7' T-2 9746' 5381' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Brian Noel 265-6979 Signed ~~'~'~~ Title Ddlllng EnRlneerin.q Supervisor Date ti (2_=1 f=,~ ~ James Trantham Prepared by Sharon AIIsup-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. 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 the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Shut-in, Other-explain. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Item 28: If no cores taken, indicate 'none". Form 10-407 RECEIVED NOV 000 Alaska 0il & Gas Cons. Commission Anchorage Date: 11/15/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: WELL:2N-305 STATE:ALASKA COUNTY: NORTH SLOPE WEST FIELD: TARN PARTICIPATING AREA SPUD:09/19/00 START COMP: RIG:NABORS 19E BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20349-00 09/19/00 (D1) MW: 9.9 VISC: 98 PV/YP: 24/33 APIWL: 7.0 TD/TVD: 293/0 (293) DRLG 9 7/8" HOLE @ 622' (RIG BACK ON HI LINE POWER SUPV:DEARL W. GLADDEN Move rig and spot rig module on well 2N-305. Accept rig @ 0330 hrs. 9/19/00. N/U diverter and function test. Hold pre-spud meeting. PJSM. Tag ice $ 55', wash and ream 55' to 118'. Drilling from 118' to 293' 09/20/00 (D2) MW: 10.0 VISC: 55 PV/YP: 21/23 APIWL: 7.2 TD/TVD: 1510/1437 (1217) DIR DRLG 9 7/8" HOLE @ 1815' ( RIG ON HI LINE POWER LA SUPV:DEARL W. GLADDEN Dir drilling from 293' to 1510'. 09/21/00 (D3) MW: 10.2 VISC: 60 PV/YP: 25/30 APIWL: 6.0 TD/TVD: 2597/2098 (1087) DRLG 9 7/8" HOLE $ 3008' - (RIG TRIPPED OFF HI LINE PO SUPV:DEARL W. GLADDEN Dir drilling 1510' to 2395'. Power failure. Dir drilling from 2395' to 2597'. 09/22/00 (D4) MW: 10.2 VISC: 50 PV/YP: 20/15 APIWL: 6.2 TD/TVD: 3033/2299 (436) CIRCU & CONDITION TO CMT ( RIG ON RIG GENERATORS LAST SUPV:DEARL W. GLADDEN Dir drilling from 2597' to 3033' MD. Monitor well, circ hole clean. Monitor well, pump dry job. TOH to jars $ 313', tight spots. Wiped all tight hole until clean. TIH, no tight hole, no problems. Pump high vis sweep, circ and condition to run casing. PJSM. Run 7-5/8" casing. 09/23/00 (D5) MW: 9.5 VISC: 48 PV/YP: 10/10 APIWL: 5.2 TD/TVD: 3033/2299 ( 0) CIRCU FOR CAS TEST SUPV:DEARL W. GLADDEN Continue running 7-5/8" casing to 2288', not getting displacement. R/U & circ bttm up. Continue running 7-5/8" casing. Circ and condition to cement. Break circ slow. Pump cement. Bumped plug, floats held. N/D diverter system. NU and test BOPs to 250/3500 psi. No failures. RECEIV'ED NOV 2000 Naska Oil & Gas Cons. Commission Anchorage Date: 11/15/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 09/24/00 (D6) MW: 9.6 VISC: 46 PV/YP: 12/10 APIWL: 5.8 TD/TVD: 3603/2550 (570) DRLG 7 1/2'' X 6 1/2" HOLE @ 3887' ( RIG ON RIG GENERA SUPV:DEARL W. GLADDEN TIH to 1128'. TIH and tag cement @ 2914'. Test casing to 2000 psi. Drilling 2914' to cement, float collar, cement, float shoe and 20' new hole to 3053'. CBU. C/O mud to LSND system. Circ and condition for LOT, Perform LOT, EMW 14.7 pg. Dir drilling 3053' to 3603'. 09/25/00 (D7) MW: 9.6 VISC: 45 PV/YP: 15/15 APIWL: 5.8 TD/TVD: 4802/3106 (1199) DIR DRLG 7 1/2" X 6 1/2" HOLE @ 4885' ( RIG ON RIG GEN SUPV:DEARL W. GLADDEN Dir drilling 3603' to 4486'. ECDs increased slowly to 11.1 ppg, pump sweep while drilling. Circ hole clean. Dir drilling from 4486' to 4802'. Pump sweep, circ hole clean for wiper trip. 09/26/00 (DS) MW: 9.6 VISC: 48 PV/YP: 19/18 APIWL: 5.6 TD/TVD: 5600/3206 (798) DRILLING @ 5907' SUPV:R.W. SPRINGER Monitor well, POH to shoe. BOP drill while tripping. RIH. Circ and ream from 4762' to 4802'. Drilled from 4802' to 5600'. 09/27/00 (D9) MW: 9.6 VISC: 48 PV/YP: 17/16 TD/TVD: 6565/3206 ( 965) DRILLING @ 6700' SUPV:R.W. SPRINGER Drilled from 5600'-6565'. APIWL: 5.8 09/28/00 (D10) MW: 9.6 VISC: 47 PV/YP: 17/13 APIWL: 5.8 TD/TVD: 7299/3206 (734) DRILLING ~ 7516' SUPV:R.W. SPRINGER Drilled from 6565'-7299'. Circulate bottoms up. Wiper trip to 6309', no drag, tight spots. RIH. Pump low and high vis sweep and circ hole clean. 09/29/00 (Dll) MW: 9.6 VISC: 43 PV/YP: 15/13 APIWL: 5.8 TD/TVD: 8130/3206 (831) DRILLING @ 8410' SUPV:R.W. SPRINGER Drilled from 7299' to 7963'. Change out wash pipe packing assembly. Drilled from 7963' to 8130'. 09/30/00 (D12) MW: 9.6 VISC: 44 PV/YP: 17/13 APIWL: 5.8 TD/TVD: 8658/4881 (528) WAITING ON SPERRY RESISTIVITY TOOL (24 HR HI-LINE POWE SUPV:R.W. SPRINGER Drilled from 8130' to 8658'. Pump weighted high vis sweep and circ hole clean. POH. Wash clay from BOP's, test floor safety valve to 250/3500. RECEIVED NOV 2000 Alaska Oil & Gas Cons. Commission Anchorage Date: 11/15/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 10/01/00 (D13) MW: 9.6 VISC: 42 PV/YP: 13/15 APIWL: 5.6 TD/TVD: 8960/4881 ( 302) DRILLING ~ 9140' SUPV:R.W. SPRINGER Test BOPE. Orient BHA, change out pilot bit. Sperry LWD density tool not communicating. PJSM. RIH. Test Sperry tools. RIH, break circ ~ shoe. Drilled from 8658' to 8960'. 10/02/00 (D14) MW: 9.7 VISC: 46 PV/YP: 16/17 TD/TVD: 9764/4881 ( 804) DRILLING @ 9941'. SUPV:R.W. SPRINGER Drilled from 8960' to 9764'. APIWL: 4.9 10/03/00 (D15) MW: 9.7 VISC: 41 PV/YP: 13/10 APIWL: 4.8 TD/TVD:10334/4881 ( 570) POH, L/D HWDP (24 HR HI-LINE) SUPV:R.W. SPRINGER Drilled from 9764' to 10334'. Pump low vis and weighted high vis sweeps and circ bottoms up, monitor for flow. Short trip from 10334' to 8491' and RIH. No fill, no tight spots. Pump high vis sweep and circ hole clean. 10/04/00 (D16) MW: 9.7 VISC: 43 PV/YP: 12/10 APIWL: 4.8 TD/TVD:10334/4881 ( 0) RUNNING CASING (24 HR HI-LINE) SUPV:R.W. SPRINGER Circ and condition hole, pump pill. POH. PJSM. Set test plug. Rig up to run casing. PJSM and run casing. Circ bttm up @ 2975'. Continue running 5.5" casing. 10/05/00 (D17) TD/TVD:10334/4881 ( SUPV:R.W. SPRINGER MW: 9.7 VISC: 38 PV/YP: 10/ 7 APIWL: 3.8 0) FINISHED CEMENTING PROD CSG AND 2N-305 CONDUCTOR.(24 H Continue running 5.5" casing from 3273' to 5580' Circulate. Run 5.5" casing to 8119'. Circulate bottoms up. Run 5.5" to casing point. Circ and condition mud for cementing. PJSM. Pump cement. Unable to pump cement from one of two batch mixers to pumping unit. Timing to critical on cement setting time w/Dowell pumping malfunction. Abort job w/o pumping cement downhole. 10/06/00 (D18) MW: 8.5 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD:10334/4881 ( 0) RUNNING 3-1/2" COMPLETION (24 HR HI-LINE) SUPV:R.W. SPRINGER Circulate and batch mix cement. PJSM. Pump cement, drop plug, bump plug, floats held. Set test plug above packoff. PJSM. Run 3.5" completion. 10/07/00 (D19) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD:10334/4881 ( 0) FINISH TESTING TREE, SET BPV, RELEASE RIG. (15.5 HR HI SUPV:R.W. SPRINGER Run 3.5" tubing completion. Circ hole clean w/clean seawater. Test casing to 3500 psi. Freeze protect well. RECEIVED NOV 30 2000 011 & 6ms Cons. Commi;sior~ Anchorage 10/08/00 (D20) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD:10334/4881 ( 0) RIG RELEASED & MOVED TO 2N-326 SUPV:R.W. SPRINGER N/D BOPE. Install tree and test. Secure well. Rig released @ 0700 hrs. Move to 2N-326. RECEIVED NOV ;50 2000 Alaska 0il & ~as Cons. Commissior~ Anchorage ~ommissiien i I I ' ~ I ;iI i~--i0 ri~ . ~ i ~ i cZ: 03 :~ ~ i ~ ~ o , , z- ~ ~z ~ I i ~ ~ m ~ ~ ........... . ~ ~ ~ o o ~ o o ' ~ ' ~ o o ~ , I o ~ ~ .- ' _=om I ~ ~ i . . ~. , e ~ . , .. z ~ ~ ~ ~ ~ = ~ o d ,o ~ ,' ._ o ~ ~ o ~ ~ ~ ~ o , ~ --~ ~ ~ ~ ~ ~ m m ~ o ~ ~ ~ ~ ~ o >~I ' ' ' -- ~ - . m o o ~ o ~ ~ ~ .o ............... : . . . . ~ ~.~ ~ ~ ~ .... , k~g I I "'~ ~ ~ ~ I ' ; ~ ~ ~ ~ Al~s Oil& G~s Cms. Cor~'mis Joni · · § = i Arrcho~e · - u:---- ,f,' .......... ~ I ~ ~ , , ~ ~ ~ -= . ......... ~ ~ q ~ q ; . .... ~ ~ ~ ~ o.~ ~ ............... o . . ~ ~ ~ 0 0 0 . . ~ . . . ~ m ~ g ~ ~ . ~ ~ ~ ~ ~ ~ ~ -. z s~,~ , , ~ o I. " ,. ...... ~ o ~ 8 8 ~ . ~ .- . . ....... ~ ~ ~.R ~ ~ ~ ~ ~8 ~ ~ . ,. ~ ~ · i, " il PHILLIPS Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(2N-305(W4-6)) WELL JOB SCOPE 2N-305 PERFORATIONS-E-LINE(260) DATE DAILY WORK 10/15/00 PERFORATE 9724-9734 FT - BIGHOLE 35B UP @ 4 SPF DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON I YES I YES SW$-SPENCER 'nitial Tbg Press I Fina'Tbg Press I 'nitia' 'nner Ann0 PSI 200 PSI 50 PSI Fine' 'nner Ann150 PSI DAILY SUMMARY JOB NUMBER 1011002110.5 UNIT NUMBER 2145 SUPERVISOR GOBER Initial Outer Ann I Final Outer Ann 0 PSII 200 PS1 TAG PBTB AT 10094' RKB - TUBING TAIL AT 9389' RKB - PERFORATE 9724'-9734' FT WITH 2.5" HSD, BIGHOLE CHARGES, 35B UP RDX, 4 SPF, 180 DEG PHASED - PRESSURED UP WHP TO 3800 PSI BEFORE PERFORATING - WHP DROPPED TO 950 IMMEDIATELY AFTER PERFORATING[Perf] TIME LOG ENTRY 15:30 LEFT 2X-09 FOR 2N-305 16:15 CALLED 2N DSO - MIRU - SAFETY MEETING 17:00 READY TO ARM GUN, AWAITING ARRIVAL OF TRI-PLEX 17:45 TRI-PLEX ARRIVED - ARM GUN 17:55 PT LUBRICATOR TO 300 PSi 18:00 PT LUBRICATOR TO 4000 PSI 18:15 RIH TOOLSTRING = HEAD/AH38/SWIVEL/PGGT-C/FLEX JOINT/SAFE HEAD - ESIC/SAFE HEAD ADAPTER/10 FOOT'GUN/BOTTOM NOSE = 25.6 FEET X 2.5" MAX OD 19:20 LOG A JEWELRY-TIE IN PASS UP FROM TD AT 10094 TO 9024 FT MD 20:30 APPLIED 3600 PSI TO WELL WITH A TRIPLEX, LOGGED UP INTO POSITION TO SHOOT - CCL DEPTH AT 9716.7 FT MD/CCL TO TOP SHOT = 7.3 FT / INTERVAL = 9724 - 9734 FT 20:40 BUMPED UP WHP TO 3800 PSI - SHOT GUN - PRESSURE DROPPED OFF TO 950 PSI QUICKLY. 22:00 AT SURFACE - ALL SHOTS FIRED - BEGIN RD 22:45 CALLED DSO - LEFT PAD RECEIVED NOV 5 0 ~000 Alaska 0ii & Gas Cons. Commission Anchorage PHILLIPS Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(2N-305(W4-6)) WELL 2N-305 DATE 10/18/00 DAY 1 JOB SCOPE FRACTURING.(255) DAILY WORK INITIAL FRACTURE TREATMENT OPERATION COMPLETE I SUCCESSFUL YESI YES Initial Tbg Press 350 PSI DAILY SUMMARY I JOB NUMBER 1017001916.2 UNIT NUMBER KEY PERSON SUPERVISOR DS-GALLEGOS ODELL Final Inner Ann I Initial Outer Ann 500 PSI 255 PSI 375 PSI Final Tbg Press I Initial Inner Ann 800 PSII 350 PSI IPUMPED INITIAL FRACTURE TREATMENT WITH BRACKETFRAC STAGE. PLACED 170M# PROPPANT BEHIND PIPE, 8 PPA ON I PERFS, 103% OF DESIGN. FLUSHED TO COMPLETION, LEFT 530# PROPPANT IN WELLBORE. [Frac-Refrac] I TIME LOG ENTRY 06:30 MIRU DS EQUIPMENT. 09:30 PREJOB SAFETY MEETING. (13 DS, 1 APC, 2 LRS, 1 PAl). JOB REVIEW, MUSTER AREA, SLICK SPOTS, RIG ACTIVITY, TIGHT PAD. 09:45 PRIME UP AND WARM UP LINES. 10:15 SET TREE SAVER, PT LINES TO 9900 PSI, REPLACE NEEDLE VALVE ON PRESSURE TRANSDUCER. PT LINES TO 10200 PSI, GOOD TEST. 10:50 START BREAKDOWN STAGE. 237 BBLS SLICK WATER, 35 BPM. SAW PRESSURE BREAK BACK FROM 8500 PSI TO 5050 PSI. PERFORMED SDT. XS FRIC = 1950 PSI @ 35 BPM, 1050 PSI @ 25 BPM, ALL PERF FRIC. ISIP = 741 PSI, FG - 0.58 PSI/FT. MIX GEL. 11:20 START SCOUR STAGE. 100 BBL PAD, 50 BBL 1 PPA SCOUR, 136 BBL FLUSH. PERFORM SDT, XS FRIC = 1215 PSI @ 35 BPM, 625 PSI @ 25 PSI. ISIP = 747 PSI, FG = .58 PSI/FT. MAKE GEL FOR DATAFRAC. 12:05 START DATAFRAC. 300 BBLS 50# XL GEL, 87 BBL FLUSH. 35 BPM, 4700 PSI. PERFORM DECLINE ANALYSIS. ISIP = 980 PSI, FG = .63 PSI/FT, TC = 6.7 MIN, PC = 852 PSI, PNET = 123 PSI, EFFC = 36.7%. REDESIGN FRAC, PAD VOLUME = 500 BBLS. MAKE GEL AND BATCH UP BRACKET FRAC SLURRY. 13:40 START BRACKETFRAC. DS FRAC CAT COMPUTER STOPPED TOTALIZING, FLUSH XL GEL FROM TUBING, REBOOT COMPUTER. PUMPED 275 BBLS IN FALSE START. 14:10 RESTART BRACKETFRAC. 350 BBLS 35# XL PAD, 35 BPM, 4400 PSI. 253 BBLS 20# LINEAR BRACKETFRAC SLURRY, 32 BPM, 4500 PSI. FLUSH WITH 20# LINEAR GEL, 780 BBLS, 22 BPM, 2825 PSI. ADJUSTED RATE DURING FLUSH TO MAINTAIN 2800 - 2850 PSI. 15:05 START PAD FOR PROPPED FRAC. PUMP FRAC W/500 BBL PAD, THEN PROPPANT STAGES AS PER DESIGN TO 4 PPA STAGE. EXTENDED 4 PPA STAGE TO 450 BBLS IN ATTEMPT TO REACH TSO. SAW TSO -55 MINUTES INTO JOB. FLUSHED TO COMPLETION. 16:15 SHUT DOWN, MONITOR PRESSURE FOR 15 MINUTES. NOV 50 000 ~aska Oil & Gas Cons. Commission Anchorage TIME LOG ENTRY 16:30 RIG DOWN DS EQUIPMENT. ALL TREESAVER RUBBERS RECOVERED. 18:00 DS RIGGED OFF OF WELL, WELL SECURED. IU/~%I '=A .,__ A I,..I.- A · .,.o,~ uu a ~as Cons. C0~mJBsj{:)ll ~ulGhorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _ Suspend _ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ Other_X Annular Injection 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 5. Type of Well: Development _X Exploratory _ Stratigraphic _ Service ~ 4. Location of well at surface 6' FNL, 529' FEL, Sec. 3, T9N, R7E, UM (ASP: 461063.88, 5912001) 6. Datum elevation (DF or KB feet) RKB 35 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2N-305 At top of productive interval 2207' FSL, 317' FWL, Sec. 26, T10N, R7E, UM At effective depth At total depth 2727' FSL, 333' FWL, Sec. 26, T10N, R7E, UM (per APD) 9. Permit number / approval number 200-135 10. APl number 50-103-20349-00 11. Field / Pool Kuparuk River Field/Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 10334 true vertical 5682 Effective depth: measured 10200 true vertical 5614 Casing Length Size Conductor 83' 16" Surface 2991' 7.625" Intermediate 9369' 5.5" x Production 924' 3.5" feet Plugs (measured) feet feet Junk (measured) feet Cemented 8 cu. Yds High Early 330 sxAS III Lite, 240 sx Class G 170 sx Class G, 520 sx Class G (included above) Measured Dep~ True vertical Depth 118' 118' 3026' 2301' 9404' 5220' 1O328' 5679' Perforation depth: measured true vertical Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) ORIGINAL, 3.5', 9.3~, L-S0 e 9396' ~ 4 Casing Se~ Recep~cle ~ 9383' MD, No SSSV ~ ~ 13. Attachments Description summary of proposal__ Detailed operations program _ BOP sketch _ LOT test, surface cement details and casing detail sheets .._X 15. Status of well classification as: 14. Estimated date for commencing operation November 6, 2000 16. If proposal was verbally approved Name of approver Date approved Oil __X Service __ Gas __ Suspended __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ Title: Drilling Engineering Supervisor Jame~ n Questions? Call Brian Noel 265-6979 Prepared by Sharon AIIsu~Drake FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance ~ Mechanical Integrity Test _ Subsequent form required 10-/~/~-~ o tOtt t- s G EO BY _ Approved by order of the Commission ~. ta. 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Z...J...J .... ,...,...,...,...,..., .... ~.-.L...~ ~ · ~1~ ~ ~z~ = Io ~ o~~z ~ I -- , ~ .~ Z ~ I-- iii I- E I'q I-! E 0 "-' 4.--' o ~ o m .c: m 0 LU CM L~ 0 3© (' Phillips Alaska Drilling Cementing Details Well Name: 2N-305 Report Date: 09/23/2000 Report Number: 4 Ri~l Name: Nabore 19E AFC No.: AK0115 Field: Tarn " I Centrellzere State type used, intervals covered and spacing Comments: Gemeco Bow Spring Cent on Jta # 1 thru 12 & #15,18,21,24,27,30,33,36,39,42,45,50,53,56,59,62,65 &68 = 32 Total Mud Weight: PV(prior cond): PV(after cond): I YP(prior cond): YP(after cond): Comments: 10.2 20 18I 15 8 Gels before: Gels after: Total Volume Circulated: 9/19 6/14 1164 bbls (11526 stks) Wash 0 Type: Volume: Weight: Comments: ARCO Wash 20 bbl 8.4 spacer 0 Type: Volume: Weight: Comments: ARCO B45 40 10.2 Lesdcem,nt 0 Type: I Mix wtr temp: No. of Sacks: I Weight: Yield: .. Comments:.' "' ~ 'i..'. AS III Ute 75 330 10.7 4.44 I I . . " ' . ... Additives: . ., i.. ''.' . .i' ' .... . .' D053 30.0%,D046 0.696%,D079 1.5%,S001 1.5%,D124 50.0%,D044 9.0% c0~mentsi · . . :. .:'. '.' G 75 240 15.0 1,17 Additives: ii. D046 0.2% , D065 0.3 %, Sool 1.0% Pl~i~J~iit 0 ' ::"::.' "i'"';'. :" Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: ~h~i :' ' ': 6.82 bpm 7.03 bpm 85K . ' :'~ ' ' '. Reciprocation length: Reciprocation speed: Str. Wt. Down: : :,.!.":.:...:::'; .':. :.., '.'::'.:.. 10'tO12' 3Ofpm 58K Theoretical Displacement: Actual Displacement: Str. Wt. in mud: ':~ ::'~ :.:~': '. :.':.'.' ': :' '...' . .i ....": '.. :".:'i '? ::1 135,3 135,2 75K Calculated top of cement: CP: Bumped plug: Floats held: CMl' to Surface Date: 9/23/OO Yes Yes Time:9:lSAM Remarks:Job went well - Reclped pipe until last 300 stks of displacement - Full returns thru complete Job - Vac Trucks were used to suck from conductor outlets- Had 432 stks (43.6 bbls) 10,7 ppg CMT to surface, , i ICement Company: Rig Contractor: Approved By: Dowell NABORS Dearl W. Gladden Casing Detail 7-5/8" surface casina WELL: 2N-305 PHILLIPS Alaska, Inc. DATE: 09/22/00 ! OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Nabors 19E RT to GL = 34.50' TOPS 7 5/8" Landing Joint (38.97 total) RK 34.50 7 5/8" FMC GEN IV FLUTED MANDREL HANGER 2.58 34.50 its.48-70 7 5/8", 29.7#, L-80 BTC-MOD 986.61 37.08 Tam Port Collar 2.44 1023.69 its 3-47 7 5/8", 29.7#, L-80 BTC-MOD 1910.63 1026.13 Gemeco Float Collar 1.35 2936.76 its 1-2 7 5/8", 29.7#, L-80 BTC-MOD 86.18 2938.11 Gemeco Float Shoe 1'.46 3024.29 BTM OF SHOE @ ..... >>>>> 3025.75 TD 9 7/8" H~ 3033.00 32 TOTAL, Gemeco Bow Spring Centralizers 4, Centralizers in center of its. ! & 2, 47 and 48 over stop collars 28 ,Centralizers over collars of its., 3-12, 15, 18, 21,24, 27, 30, 33 36, 39, 42, 45, 50, 53, 56, 59, 62, 65 & 68 Remarks: String Weights with Blocks: 92k Up, 58k Dn, 15k Blocks. Ran 70 joints of casing. Drifted casing with 6.750" plastic rabbit. Used Best-o-Ufe 2000 thread compound on all connections. Eight joints surplus. Nabors 19E Drilling Supervisor: Dead W. Gladden PHILLIPS ALASKA INC CASING TALLY PAGE: 1 of 2 WELIc 2N-305 Kuparuk Unit RIG: Nabors 19E TUBING DESCRIPTION: 7 5/8", 29.7#, L-80, BTC-M DATE: 09/22/00 Column 1 Column 2 Column 3 Column 4 Column 5 Column 6 Column 7 Column 8 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet 1 ~ 26 41.52 51 43.05 76 101 1126 151 176 2 .~ ',':.:::: i':': '~:~ '""::' ".~' .'.~-: ::~.:.~ ,~ 27 ~~ 52 43,31 77 102 127 152 177 ~'%" :~ ~.~;~' ' '~:'~' 3 ~~~'~" '"'i~ 28 41.90. 53 ~!~ 78 103 128 153 178 4 ~ 29 43,13 54 43,16 79 104 129 154 179 5 ~ ~ 30 ~~ 55 43,07 80 105 130 155 180 6 ~._ ~ 31 43.03 56 ~~ 81 106 131 156 181 7 ~ 32 42.29 57 43,19 82 107 132 157 182 10~~ 35 42.29 60 43.14 85 110 135 160 185 11 ~~ 36 ~~ 61 42,61 86 111 136 161 186 ~,- -.-~- -~,~.~ ~,--,-~;.;. -- -~.~ 13 42,36 38 43.31 63 43,08 88 ~113 138 163 188 14 42,47 39 ~~ 64 41,53 89 114 139 164 189 ~s ~ 40 42.99 68 ~;~ 90 115 ~40 165 190 16 42.95 41 43,14 66 42,46 91 116 141 166 191 17 40,40 42 ~~ 67 43,23 92 117 142 167 192 ~0 ~.83 ~~ 70 43.15 95 120 145 170 195 21~~i ~s a3,0~ 71 ~?~~~s 121 ~ 171 22 a~,s8 47 ~~~ 72 ~~ 97 122 147 172 ~7 ,': ~','"::"",' ,.~ 24 ~~ 4~ a3.20 74 ~[?~,~?~~9 ~24 148 174 ,199 :-,~~ 25 43.47 50 ~~~ 75 ~.~?~ 100 125 150 175 Tot 1054.05 Tot 1071,54 Tot 1065.99 Tot Tot Tot Tot Tot TOTAL LENGTH THIS PAGE = 3191.58 TOTAL JOINTS THIS PAGE = 75 DIRECTIONS: Joints # 71 thru 75 ("OUT'9 Stay in Shed Float Shoe = 1.46 Float Collar = 1.35 Stage Collar = 2.50 Fluted Hanger = 2.58 20-Oct-00 AOGCC Lori Taylor 3001 Pomupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 2N-305 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD 0.00' MD 10,334.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, Kenneth W. Allen. Survey Manager Attachment(s) OCT 24 000 _ ! ~'~'~o dddd ,,:c,'J~:~ai ~,:Faid ,,-:ai0,i44 .,.:d~o, ic,,i I.,,I.3 o:~ ~ wwwwwwwwwwwwwwwwwwwwwwww~~~ ~ ~ ~ ZZZZZ ZZZZZ ZZZZZ ZZZZZ ZZZZZ 00000 00000 00~ ~~ ~~ o. ~.~. zz~=~ z~zzz ~zz~zz~z= 0 Z ogooo ooooo g~ooo ooooo 00000 00000 00000 00000 '0 .,..v E t,/) o 00000 00000 00000 00000 00000 0 ~ o~fi~ ~o~o.o~ oooo~ ooooo ooooo 0 Z ~Z --0,-,-,- ~0~0~ 0000~-- ~ 0 0 2: '0 ~WWW~ ZZZZZ ZZZZZ ! I~ CDCDCDr,,OtO '~ 0 ZZZZZ ZZZZZ ~ .~ ~ CO O~ C~ ~ 0 0 ~ 0 I,- ,-. 00~00 ~0~00 ZZZZZ ZZZZZ ZZZZZ ~0~ ~0~ ~0~0~ ZZZZZ ZZZZZ ZZZZZ ~~oo~ ~ooo ooooo ooooo ooooo 00000 00000 00000 00000 00000 0 Z '0 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: FROM: Dan Seamount Commissioner DATE: October 1, 2000 Blair Wondzell 01~.~ P.I. Supervisor lo/'~ ~ John Crisp , Petroleum Inspector NON- CONFIDENTIAL SUBJECT: Blowout Preventer Test Nabors 19E Phillips Alaska Inc. 2N 305 200-135 Kuparuk River Field Operator Rep.' ,Ray Sprin.qer Contractor Rep.' Jerry Otto Op. phone: 263-3140 Rig phone: 263-3140 Op. E-Mail: Rig E-Mail: Test Pressures Rams: 3500 Annular: 2500 Choke: 3500 TEST DATA MISC. INSPECTIONS: FLOOR VALVES: MUD SYSTEM: Visual Alarm PIF P/F Quantity PIF Trip Tank OK OK Location Gen.' Good Sign: Yes Upper Kelly 1 P Pit Level Indicators OK OK Housekeeping: Good Rig cond: Good Lower Kelly 1 F Flow Indicator OK OK PTD On Location Yes Hazard: Yes Ball Type 1 F Meth Gas Detector Tested Tested Standing Order: Yes Inside BOP 1 P H2S Gas Detector Tested Tested BOP STACK: Quantity Size PIF ACCUMULATOR SYSTEM: Annular Preventer 1 11" P CHOKE MANIFOLD: Time/Psi P/F Pipe Rams 1 4" P Quantity P/F System Pressure 3100 Lower Pipe Rams 1 4" P No. Valves' 14 P After Closure 2100 Blind Rams 1 11" P Man. Chokes 1 functioned 200 psi Attained 23 sec. Choke Ln. Valves 1 3" P Hyd. Chokes 1 functioned Full Pressure 2 min. 23 sec. HCR Valves 2 3" P Blind Covers (All Stations): Yes Kill Line Valves ,. 1 3" P N2 Bottles (avg): 4 btls. 2000 ave. Check Valve Test's Details I traveled to Phillips Alaskas Tam Field in the Kuparuk River Unit to witness thc weekly BOP test on Nabors 19E. Thc low? K~l_y_v~ye ,fail~,., to pass the pressure test. Th,_e spare_ flo~or safe~, valve was tested to replace the lower kelly valve & failed the pressure test. Both valves w~ced & t~ed OK. ' ......... Total Test Time: $ hrs. Number of failures: _2 CC: ~ Attatchments: none BOP Nabors 19E 10-01-00jc.xls ALASI~A OIL AND GAS/~' James Tram~a~ONSERYATION CO~ISSION / Drilling Engineering Supervisor Phillips Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Kupamk River Unit 2N-305 Phillips Alaska, Inc. Permit No: 200-135 Sur Loc: 6'FNL, 529'FEL, Sec. 3, T9N, R7E, UM Btmholc Loc. 2540'FNL, 374'FWL, Sec. 26, T10N, R7E, ~ TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Dear Mr. Trantham: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill application for Kuparuk River Unit Well No. 2N-305. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on Drill Site 2N must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space ora single well or to use that well for disposal purposes for a period longer than one year. Annular disposal of drilling wastes will not be approved for this well until sufficient data is. submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface easing confirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to the Commission on form 10403 prior to the start of disposal operations. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. ~~. ~'/,l~aniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this / ~_~-~ day of September, 2000 dlf/Enclosurcs CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ('" ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work: Drill [~] Redrill [--] I lb. Type of well. Exploratory ~] Stratigraphic Test D Development Oil r'~ Re-entry [~] Deepen [~]I Service D Development Gas D single Zone r~ Multiple Zone 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool Phillips Alaska, Inc. RKB 35 feet 3. Address 6. Property Designation ,~'-~'O'~ ~ Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-0360 cu~JADL 380053 ALK 4601 5~..~:5~,, ~ Tarn Pool 4. Location of well at surface 7. Unit or property Name " 11. Type Bond (see 2O AAC 25.0251) 6' FNL, 529' FEL, Sec. 3, T9N, R7E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 2207' FSL, 317' FWL, Sec. 26, T10N, R7E, UM 2N 305 #U-630610 At total depth 9. Approximate spud date Amount 2540' FNL, 374' FWL, Sec. 26, T10N, R7E, UM September 12, 2000 $200,000 12. Distance to nearest property line I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) 374 @ TD feetI 2N-307 29.9' @ 0' feet 2560 10332' MD / 5667' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 2S.035 (e)(2)) iKickoff depth: 300 MD Maximum hole angle 62.5 Maximum surface 1861 psig At total depth (TVD) 2400 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of Cement Hole Casinc, I Weight Grade Couplin~l Len~h MD TVD MD TVD (include sta~le data) 24" 16" 62.5# H-40 Weld 83' 35' 35' 118' 118' 9 cy High 'E~r'ly 9.875" 7.625" 29.7# L-80 BTCM 3006' 35' 35' 3041' 2300' 320 sx AS III L & 240 sx Class G 6.75" 5.5" x 15.5# L-80 LTC Mod 9320' 35' 35' 9355' 5216' 710 sx Class G .~,.. 6.75" 3.5" 9.3# L-80 8rd EUE 977' 9355' 5216' 10332' 5667' see above 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured feet Plugs (measured) true vertical feet Effective Depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Conductor Surface Intermediate RECEIVED Production SEP 0 6 2000 Perforationdept,: measured ORIGINAL Alaska 0i{ & Gas Cons. Commission true vertical Anchorage 20. Attachments Filing fee [~] Property Plat D BOP Sketch r'~ Diverter Sketch r~ Drilling program r~ Drilling fluid program r~ Time vs depth plot [--]Refraction analysis [~] Seabed report [~ 20 AAC 25.050 requirements 21. I hereby cer{ Iy that the~ and correct to the best of my knowledge Questions? Call Torn Brassfield265-637;, Signed ~alm~{sTrantharn I~~ Title:Dril/ingEngineeringSupe~vi$or Prepared bv Torn Rrassfielc Commission Use PermifNumbe~_.~,~) /'~1 APInumber __.. ISeecoverletter " 50- //(~)~..~ "~'~)(~"'4~)1 Approvaldate~;~..,/~,~ ~ I,°r°therrequirements Conditions of approval Samples required D Yes [] No Mud Icg required D Yes '[~i~ No Hydrogen sulfidemeasures [~] Yes [] No . Directional surveyrequired ~] Yes D No Required working pressure for BOPE D2M; D 3M; D 5M; D 1OM;El D by order of Approved by ORIGINAL SIGNEL:" ~:: Commissioner the commission Date ~'"' D Taylor Seamoun~ Form 10-401 Rev. 12/1/85 · Submit in triplicate 10. 11. 12. 13. (' Phillips Alaska, Inc. GENERAL DRILLING AND COMPLETION PROCEDURE KUPARUK RIVER FIELD - PRODUCER/Injector KRU 2N-305 1. Move in and rig up Nabors 19e. 2. Install diverter system. 3. Drill 9.875" hole to 7-5/8" surface casing point according to directional plan. Run open hole logs for USGS. 4. Run and cement 7-5/8" 29.7#, L-80 BTC-Mod casing string to surface. Employ lightweight permafrost cement lead slurry to assure cement returns to the surface. Adequate excess cement will be pumped to ensure cement reaches the surface. If cement does not circulate to surface, a Top Job will only be performed after consulting with the AOGCC. Install and test BOPE to 3,500 psi. Test casing to 2,000 psi. 5. Drill out cement and 20' of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe per 20 AAC 25.030 (0.5 ppg less than the FIT or LOT EMW). 6. Drill 6-3/4" or 6-1/2"x7-1/2" hole to TD according to directional plan. Run LWD logging equipment with density and porosity tools. Note: If significant hydrocarbon zones are present above the Tarn, sufficient cement will be pumped for isolation in accordance with 20 AAC 25.030(d)(3)(C). 8. Run and cement 5-1/2" L-80 LTC Csg X 3-1/2" L-80 8rd EUE-Mod tapered production casing string with Baker casing seal receptacle at crossover point. 9. Pressure test casing to 3,500 psi. Run 3-1/2" L-80 8rd EUE-Mod completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus to 3,500 psi. Set TWC, ND BOPE and install production tree. Secure well. Rig down and move out. Handover well to Operations Personnel. RECEtVED [ '~. Phillips Alaska, Inc. DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRILLING AREA RISKS Well KRU 2N-305 Drilling Fluid Properties: Density PV YP Funnel Vis Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to surface casing point 9.5-10.2 ppg 16-26 25-35 50-120' 10-20 15-40 7-15 9.5-10 +_10% Drill out to TD 9.0 - 11.0 ppg 6-20 5-20 35-50 2-6 4-8 <6 through Tarn 9.0-10 <11% Drilling Fluid System: Triple Derrick Shale Shakers Desander, Desilter, Mud Cleaner Centrifuge Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid. Flow Sensor Degasser Fluid Agitators *Spud mud should be adjusted to a FV between 100-120 sec/qt to drill gravel beds Drilling fluid practices will be in accordance with the regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Maximum anticipated surface pressure (MASP) while drilling the production hole is calculated using a reservoir pressure of 2400 psi at a target mid-point of 5388' TVD. Gas gradient is anticipated to be 0.1 psi/ft. Using this data, the MASP is calculated to be: MASP=((2400/S388)-0.1)'5388 MASP=1861 psi Therefore PAl will test the BOP equipment to 3500 psi after setting surface casing. Based on offset well data, reservoir pressures in the Tarn sands in the vicinity of 2N pad are expected to be -2,400 psi (0.49 psi/ft). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.10 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 5388'. Target (Midpoint T2 T3) (2400+150)/(0.052'5388)=9.10. Phillips Alaska, Inc. Well Proximity Risks: The nearest wells to 2N-305 are 2N-307 & 2N-308. The 2N-305 & 2N-307 wells are 29.9' from each other at surface. 2N-305 & 2N-308 are 42.8' from each other at 433' MD. These wells do meet with the Phillips ellipse separation criteria. Drillinq Area Risks: One identified risk in the Tarn 2N-305 drilling area is the shallow gas hydrates below the permafrost. To date the hydrates encountered while drilling the Tarn Phase 3 wells 2N 347, 2N 332, 2N 316, & 2N 318 have been minimal. Standard SOP's have been developed to minimize the hydrate impacts i.e. maintaining Iow mud viscosities, pre-treating with Driltreat (Lecithin) and DriI-N-Slide, using cold make-up water for the mud, control drilling, and optimized flow rates. The surface hole will be drilled with weighted mud (9.5- 10.2 ppg) to avoid underbalancing the hole. Another observed problem in the area is possible lost circulation at approximately 3,300' TVD and in the Tarn formation. Analysis of pressure data from offset wells shows that a mud weight of 9.0-10.0 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement the well through the reservoir. The 7-5/8" casing shoe will be tested to leak-off, or to a maximum equivalent mud weight of 16.0 ppg upon drilling out of the casing. Recent information has indicated the possibility of gas migration from the reservoir to a shallower sand interval. However, NO overpressured zones were encountered while drilling 2N-347, 2N-332, 2N-318, or 2N-316 wellbores. Log, tracer, pump-in test, and offest BHPBU evaluations indicate migration has not occurred outside of the wellbore interval and is most likely isolated below the TOC and/or below the Iceberg interval. In the event gas migration has occurred into the Iceberg interval at 4688' TVD, the highest required MW would be 9.8 ppg. Annular Pumping Operations: Incidental fluids developed from drilling operations will be either injected into. an approved annulus on the same pad or hauled to the nearest permitted Class II disposal well. (Note that cement rinseate will not be iniected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 2N-305 surface/production casing annulus will be filled with diesel after setting production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. Following drilling operations, Phillips Alaska, Inc. will submit application for approval of 2N-305 for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoe will be set a minimum of 200' ve?tically below the base of the West Sak into the heart of the shales. Phillips Alaska, Inc. (~' The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2,300') + 1,500 psi Max Pressure = 2,935 psi This pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and production casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 7-5/8" 29.7 L-80 3 BTC 4,790 psi 4,072 psi 6,450 psi 5,483 psi 5Y2" 15.5 L-80 3 LTC-Mod 4,990 psi 4,242 psi ~7,000 psi 5,950 psi 31~'' 9.3 L-80 2 8rd EUE Mod 10,530 psi 8,951 psi 10,160 psi 8,636 psi Fluids to be disposed of in the annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (h), LEAK OFF TEST PROCEDURE Tarn After cementing casing and nippling up BOPE, RIH to top of cement and pressure test the casing to 2000 psi for 30 minutes and record on chart (AOGCC required casing integrity test). Record the information on the PAl LOT form (you can locate on the drilling web page). Plot Casing Pressure Test (volume vs. pressure and time holding pressure on casing). Verify that the test indicates a linear line and that there is no air entrained in the mud. Repeat Casing pressure test if needed. 2. Drill 20' to 50' of new hole below the casing shoe. Circulate the hole to establish a uniform mud density throughout the system (required for a good FIT or LOT). PU into the shoe. 4. Close the blowout preventer (ram or annular). 5. Pump down the drill stem at 1/4 to 1/2 bpm. . . On the LOT form, plot the fluid pumped (volume or strokes) vs. drill pipe pressure until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. Note: If 16.0 ppg EMW is reached, shut down and hold the pressure there. This becomes the data for a formation integrity test (FIT) instead of a LOT At leak off pump 3 bbls of mud into formation prior to shutting down the pump. Shut down when the leak-off point is clearly seen and 3 bbls of mud has been pumped into the formation. Record initial shut-in pressure. With the pump shut down monitor, record and report the shut -in pressures for a minimum of 10 minutes or until the shut -in pressure stabilizes. Record time vs. pressure in 1-minute intervals and plot information. Bleed the pressure off and record the fluid volume recovered. Forward the data to the Drilling Engineer in Anchorage. The Drilling Engineer will forward the information to the Agencies. TJB 5/19/00 RECEIVED SEP 06 2000 Alaska Oil & Gas Cons. Commi~ion Anchorage Phillips Alaska, nc. c~..,.d~,;.oh For: B Noel [ Structure : Tarn Drill Site 2N Well : 30 Dote plotted: 1-Sap-2000 .,at.., ..... ~.~o~v.,.~o.~5. Fie d : T~rn Development Field Loc~fion : No~h Slope, Alosk~ C~rd;natea om in feet releren~ T ..... .;cal .p ........~GKB (Nob .... 9[). East (feel) -> 5500 5000 2500 2000 1500 1000 500 0 500 1000 1500 2000 2500 5000 .3500 4000 4500 8500 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I RSO0 8000 7500 7OOO 6500 6000 5500 5000 I 45oo .-I-- .,- 4000 '~ .3500 0 Z .3000 250O 2OOO 1500 10oo TD LOCATION: 2540' FNL, 374' FWL SEC. 26, TION, R7E TARGET LOCATION: J 2207' FSL, 517' FWL SEC. 26, TI ON, RTE 6.37 AZIMUTH 7540' (TO TARGET) ***Plane of Proposal*** TRUE SURFACE LOCATION: 6' FNL, 529' FEL SEC. 5, T9N, R7E 500 o TD - Coslng Pt 5 rget- Mid Bermuda g RECEIVED SEP 06 ;~000 Alaska ~ & Gas Cons. Commission I Comp SS And~orage ~/l~, 7 5/8 Casing I EOC lBose W Sok Zap W~Sok . , ~ase ~'ermoTrost Be(31n Turn Port Collar 500 ~ i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i 3500 3000 2500 2000 1500 1000 500 0 500 1000 1500 2000 2500 3000 .3500 4000 450( East (feet) -> 8000 7500 7000 6500 6000 5500 ,5000 4500 4000 3500 3000 250O 2OOO 1500 1000 500 500 /X I Z 'i RECEIVEE 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ~ 0 r,O r'O r~ r,O r,o r~ 0 0 0 0 0 0 0 0 0 0 0 0 C~ ~ ~ 0 0 ~ 0 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 0 ~ ~ 0 ~ ~ 0 0 ~ 0 0 0 ~ 0 0 0 0 0 0 0 0 0 0 0 0 ~ 0 0 0 0 0 0 ~ 0 0 0 0 0 0 0 0 0 0 0 0 ~ oo®~~oo~®~~o~®~® ~ 0 0 0 L.O 0 ~ O~ 0') 0'~ 0'~ 03 O~ O~ 0'~ (7) 0~ 0'~ 03 O~ ~ 0 0 0 ,-- ~ (%1 0 O~ ~' 0 6~1 O0 ~ O~ ,-- ro O0 ~- r--- r'-,. '~ o i~ o ~ o ~ r,0 I'o 00 0 r42 00 ~ 00 04 r.~ 00 ,-.- 0 0 0 r~0 0 00 0 0 0 ,-- ,-- ~ 0 0 04 r,D I'0 ~ 00 04 04 c~ 0 0 0 0 ~t' r"-. ,-- 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ~ 0 LO 0 *~' O~ 0 LO I~ LO LO LQ LO LO 1.0 LO LO LO LO LO LC) SEP 0 6 2000 An~orage c~tN by ,n,h For: B Noel D~t~ plottec~: ~-Sep.2OQO PL~t Refere~ca b 305 Vam~n i$. Phillips Alaska, Inc.] Structure: Torn Drill Site 2N Well : 505 Field : Tern Development Field Locof|on: North Slope, A usk~3 310 520 330 340 TRUE NORTH 350 0 10 2O 3O 4O 5O 300 6O 290 7O 280 8O 270 9O 260 100 250 700, 110 230 22O 1900 2OO Normal Plane Travelling Cylinder - Feet 190 180 170 120 150 160 130 All depths shown are Measured depths on Reference Well RECEIVED SEP 0 6 2000 Alaska ~ ~ ~a~ ~;ons. Uommission Anchorage Phillips Alaska, Inc. c,~.t.~,;.c. For: B Noel[ Structure : Tarn Drill Site 2N Well : 505 Dote p~ottad: 1-See-2000 P,o,.., ...... ~osv.,.~. Is. I Field : Tarn Development Field Location : North Slope, Alaskc Coo~;ncte~ °re ;n ~eet reference slot ~1305. ...... ri;col Dep ........ ~KB ( ......9D 160 140 120 100 80 60 40 20 300 i i i i i i i . i i i i i i i 1800 280 26O 240 220 20O 180 160 I 14o -I-, ,.,- 120 ~- 100 0 Z 300 e ~3oo 1700 <- West (feet) · Eost (feet) -> 0 20 40 60 80 1 O0 120 140 160 1600 1500 1100 1000 1400 1300 I I I I I I 1500 6 1500 1200 / 1400. I ,, I I ~ 900 / II I f~ 800 iI iI ,~ 700 1100 I i1 600 1000 ~ 500 900 (~ 400 300 I~ I I I I [ I j~ I I // ~ 1300 I ~ 1300 iI / iI ii II iI Iii iI / I ii ~ 1200 ~ 1200 I / iI / /I iI I iI II I I 1100 ~ 100 ii I iI iI ~1000 I /I I II ~ 900 iI iI I ~/800 iI iI 300 280 ~ 700 I iI /~ 600 ,~1500 / (~ 300 RECEIVED 260 240 220 2OO 180 80 160 1~0 I Z 0 120 ~ 100 [1) V 300 SEP 06 2000 20 Alaska ~ & Gas Cons. Commismo~ · ~~e 4o I I I I I I I [ I I I I I I I I I I I I I [ I I I I I I I I I ~0 60 '[ 40 1 ~0 '1 O0 80 ~0 40 20 0 20 40 60 80 1 O0 120 140 1 ~0 <- West (feet)' East (feet) -> Phillips Alaska, nc. For: It Noel / · ~v,.,~.~s. ~ [Field : Torn Development F~eld Locofion : North Slope. Alosko [ 680 640 600 56o 960 ~ i ~ 800840880760 2000 1900 200 72O 21 O0 2000 520 480 440 400 360 320 East (feet) -> 200 160 120 80 40 0 40 80 120 160 200 240 280 320 360 400 I , I , , , , I I I , , I , , ____, , I I , I , I I , -- , 1900 280 240 1600 ,2000 ~ 1500 1500 t 1900 1800 ti I ~ 1400 1700 iI 1800 I ~ 1300 i /2100 1900 /2000 II , iI 800 /~ 1900 i/ I iI I ,~l 1800 I 700 600 1300 iI I I ii ~/1700 / I II I I I et 1600 i1 / iI / I ~/1500 / i1 / iI ~/1400 / / I // / ~ 1300 / RECEIVED 96O - - 920 880 840 800 760 . - 720 680 /x 640 I Z o 600 '-~ 560 520 200 160 120 80 40 0 40 80 120 160 200 240 280 320 360 400 East (feel) -> SEP 06 2000 =o Alaska Oil & Gas Cons. Commission Ancho~e 2~o 360 240 4O0 440 480 (' Phillips Alaska, nc. ..... m-.. ~, ,~ml / STuc~u--r.-T T or--~ or~,,-s,. ~-7 .... -w.%-Z ~. ~o- .... Dot. plofl~d: 1-s~p-2ooo J .~:.., ..... ~3o~v.=~.~s. ~ /Field : Tarn Development Field Location : North Slope, Alaska Coo~dlnole~ ore ;n / 4200 4000 3800 3600 3400 3200 3000 2800 I '"" 2600 2400 -,I-. O Z 2200 2000 1800 1600 1400 1200 lOOO 800 East (feet) -> 1400 1200 1000 800 600 400 200 0 200 400 600 800 1000 1200 1400 1600 1800 I I I I I I ~1 I I I I I I I I I I I ~ I I I I I I I I I I I I 100 5700 3300 3900 5700 3100 2900 ,2700 3300 3100 3500 3300 5100 29OO 3500 2700 ,2500 2300 ~[ 3500 ,3300 /4 5500 I , I I :5300 I ' ~ 31oo ,'~ 5:00 I e/ 49 O0 I I I I ~ 4700 I , ~ 2900 ~4500 ~ , I ~ ~ .~oo ~ ~ 4100 ~ 2700 ~ I ~ ~ ~.oo ~ ~ 5700 2500 ~ 3~00 ~ ~00 ~00 iI /,,oo RECEIVED ~ 2700 I 2100 ~ 2500 I ~ 2300 I /~oo 900 4200 4000 - -3800 . -3600 . -3400 3200 -3000 2800 Z 26OO O 2400 ~ .-,i- 2200 ~ 2OOO 1800 1600 1400 SEP 0 6 ?.00012oo Alaska ~ & Gas Cons. Commission 1ooo Anchorage 800 1400 1200 1000 800 600 400 200 0 200 400 600 800 1000 1200 1400 1600 1800 East (feet) -> Phillips Alaska, nc. ~ ..... ~ ,~.. l'or: 1~ Noel I Structur.-----~' T-~r-~ Dr---ill--Site 2---~-'~ ~.1~ ~ ~ '-- - I ..,.., ..... ~=v,.~.~,. I LField : Tarn Development Field Location: Noflh Slope, Alaska ~inotes o~ ~ I~ reference ~lot ~. ....... ,cm~ ......... E~KB ( ..... gE). I ~ ~'t'~:q I East (feet) -> 2000 1600 1200 800 400 0 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 8400 I I I I I I I I I I I I I I I I I I I II I I I I I I I I II 8400 8000 ~ 8000 I ~ 5500 7600 7600 ~ 5300 - 7200 I -7200 /5100 6800 ~ 6800 ¢ 4900 6400 [ 6400 · 4700 5500 6000 [ 6000 ,5500 ~ 4500 5100 i 4500 4900 4100 4700 ~ 3900 4500 4400 4300 ~ 5700 ~ 4000 4000 4100 ~ 3500 3600 5900 ~ 0 -3600 ~ 3300 ~ 5500 '4500 3700 / ;5300 ' 3200 4 31oo /51oo -32oo 4500 3500 ~ ~ 4900 2800 4100 4700 3300 ~ 2900 ~4500 2800 ~ ~ 4300 - 2400 ,5100 · 2700 ~ 4100 -2400 I !~9oo . ~ ~ 3700 2000 2900 ~ 2500 ~3500 -2000 ~ ~ 3300 1600 % 2100 4 3100 1600 2000 1600 1200 800 400 0 400 800 1200 1600 2000 2400 2800 3200 5600 4000 4400 East (feet) -> RECEIVED 5600 ' 41oo 5200- . 3900 4800- 4400 3700 56OO -52oo 4800 :3' =-i- SEP 06 2000 ,~as~a O~ & Gas Cons. Commissk' And~omge PhilliDs Alaska, Inc. Tarn Drill Site 2N 3O5 slot #305 Tarn DeveloDment Field North Slope, Alaska SUMMARY CLEARANCE REPORT Baker Hughes INTEQ Your ref : 305 Version Our ref : prop2831 License = Date printed = 1-Sep-2000 Date created : 23-Feb-1998 Last revised = 1-Sep-2000 Field is centred on nT0 12 49.742,w150 18 33.414 Structure is centred on nT0 10 13.955,w150 18 32.772 Slot location is n70 10 13.902,w150 18 48.111 Slot Grid coordinates are N 5912000.641, E 461063.875 Slot local coordinates are 5.37 S 529.47 W Projection ty~e: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath PMSS <0-11197'>,,315,Tarn Drill Site 2N PMSS <0-10655'>,,337PB1,Tarn Drill Site 2N PMSS <7090-10245'>,,337,Tarn Drill Site 2N PMSS <0-9690'>,,329,Tarn Drill Site 2N PMSS <0-9134'>,,313,Tarn Drill Site 2N PMSS <0-7431'>,,345,Tarn Drill Site 2N PMSS <9483 - 9631'>,,343,Tarn Drill Site 2N PMSS <0-12339'>,,341,Tarn Drill Site 2N PMSS <288-8750'>,,309,Tarn Drill Site 2N PMSS <0-8960'>,,307,Tarn Drill Site 2N PMSS <0-10520'>,,308,Tarn Drill Site 2N PMSS <8085-8239'>,,339,Tarn Drill Site 2N PMSS <9235 - 10028'>,,32IA, Tarn Drill Site 2N PMSS <5303 - 11526'>,,321,Tarn Drill Site 2N PMSS <266'-11061'>,,320,Tarn Drill Site 2N PMSS <0-7039'>,,319,Tarn Drill Site 2N PMSS <0-9553'>,,323,Tarn Drill Site 2N PMSS <0-13692'>,,316,Tarn Drill Site 2N PMSS <0-12077'>,,335,Tarn Drill Site 2N PMSS <0-8500'>,,317,Tarn Drill Site 2N PMSS <7387 - 8182'>,,325,Tarn Drill Site 2N PMSS <0-8683'>,,332PB1,Tarn Drill Site 2N PMSS <6209 - 12026'>,,332,Tarn Drill Site 2N PMSS <10920 - 11225'>,,331,Tarn Drill Site 2N PMSS <0-12735'>,,347,Tarn Drill Site 2N PMSS <0-11456'>,,318,Tarn Drill Site 2N Closest approach with 3-D Minimum Distance method Last revised Distance 18-Jul-2000 149.9 27-Jun-2000 27-Jun-2000 10-May-2000 4-Aug-1998 21-Ju1-1998 28-Feb-2000 30-Sep-1998 30-Mar-1999 S-Mar-1999 24-Feb-1999 9-0ct-1998 21-Dec-1998 29-Feb-2000 9-Feb-1999 9-0ct-1998 15-Aug-2000 10-Aug-2000 27-0ct-1998 14-Aug-1998 21-Dec-1998 6-Jul-2000 18-Jul-2000 10-May-2000 7-Jun-2000 1-Sep-2000 479.3 479.3 359.2 119.9 599 9 569 3 540 4 60 0 29 9 42 8 507 0 240 3 240 3 222 9 210 0 270 1 1647 448.9 179.9 300.0 405.0 405.0 389.9 629.8 194.4 M.D. Diverging from M.D. 100.0 100 280.0 280 280.0 280 322.2 322 100.0 100 100.0 100 300.0 300 100.0 100 0.0 0 0.0 0 433.3 433 322.2 322 20.0 20. 20.0 20. 344.4 344. 100.0 100. 20.0 20. 300.0 300. 322.2 322. 180.0 180. 20.0 20. 100.0 100. 100.0 100. 20.0 20. 200.0 2O0.0 220.0 220.0 PhilliDs Alaska, Inc. Tarn Drill Site 2N 305 slot %305 Tarn DeveloDment Field North SloDe, Alaska 3-D M I N I M U M D I S T A N C E C L E A R A N C E R E P O R T INCLUDING POSITION UNCERTAINTIES Baker Hughes INTEQ Your ref : 305 Version Our ref : Drop2831 License : Date printed : 1-Sep-2000 Date created : 23-Feb-1998 Last revised : 1-Sep-2000 Field is centred on nT0 12 49.742,w150 18 33.414 Structure is centred on n70 10 13.955,w150 18 32.772 Slot location is nT0 10 13.902,w150 18 48.111 Slot Grid coordinates are N 5912000.641, E 461063.875 Slot local coordinates are 5.37 S 529.47 W Projection t~loe: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ReDort is limited to clearances less than 500 feet Proximities will incorDorate elliDses - when survey tools are defined for both wells. ElliDse seDaration in reverse brackets, e.g. )10.2(, where available. DECREASING CLEARANCES of less than 1000 feet are indicated Object wellpath PMSS <0-11197'>,,315,Tarn Drill Site 2N PMSS <0-10655'>,,337PB1,Tarn Drill Site 2N PMSS <7090-10245'>,,337,Tarn Drill Site 2N PMSS <0-9690'>,,329,Tarn Drill Site 2N PMSS <0-9134'>,,313,Tarn Drill Site 2N PMSS <0-7431'>,,345,Tarn Drill Site 2N PMSS <9483 - 9631'>,,343,Tarn Drill Site 2N PMSS <0-12339'>,,341,Tarn Drill Site 2N PMSS <288-8750'>,,309,Tarn Drill Site 2N PMSS <0-8960'>,,307,Tarn Drill Site 2N PMSS <0-10520'>,,308,Tarn Drill Site 2N PMSS <8085-8239'>,,339,Tarn Drill Site 2N PMSS <9235 - 10028'>,,32iA,Tarn Drill Site 2N PMSS <5303 - 11526'>,,321,Tarn Drill Site 2N PMSS <266'-11061'>,,320,Tarn Drill Site 2N PMSS <0-7039'>, 319,Tarn Drill Site 2N PMSS <0-9553'>, 323,Tarn Drill Site 2N 322 Version %35, 322,Tarn Drill Site 2N PMSS <0-13692'>, 316,Tarn Drill Site 2N PMSS <0-12077'>, 335,Tarn Drill Site 2N PMSS <0-8500'>, 317,Tarn Drill Site 2N PMSS <7387 - 8182'>,,325,Tarn Drill Site 2N PMSS <0-8683'>,,332PB1,Tarn Drill Site 2N PMSS <6209 - 12026'>,,332,Tarn Drill Site 2N PMSS <10920 - 11225'>,,331,Tarn Drill Site 2N PMSS <0-12735'>,,347,Tarn Drill Site 2N 349 Version #3,,349,Tarn Drill Site 2N 326 Version #2,,326,Tarn Drill Site 2N 303 Version %5,,303,Tarn Drill Site 2N PMSS <0-11456'>,,318,Tarn Drill Site 2N Closest approach with 3-D Last revised Distance 18-Jul-2000 )149.1 27-Jun-2000 )477.7 27-Jun-2000 )477.7 10-May-2000 )357.5 4-Aug-1998 )118.9 21-Ju1-1998 )598.7 28-Feb-2000 )567.2 30-Sep-1998 )539.7 30-Mar-1999 )59.1 S-Mar-1999 )29.3 24-Feb-1999 )38.8 9-0ct-1998 )504.7 21-Dec-1998 )239.9 29-Feb-2000 )239.9 9-Feb-1999 )220.5 9-0ct-1998 )209.1 15-Aug-2000 )269.6 22-Aug-2000 )253.7 10-Aug-2000 )163.1 27-0ct-1998 )447.1 14-Aug-1998 )178.6 21-Dec-1998 )299.8 6-Jul-2000 )404.4 18-Jul-2000 )404.4 10-May-2000 )389.0 7-Jun-2000 )628.5 17-Jul-2000 )658.4 30-Aug-2000 )313.1 31-Aug-2000 )28.0 1-SeD-2000 )192.6 by an asterisk, e.g. 487.4* Minimum Distance method M.D. 220 0 311 1 311 1 344 4 220 0 311 1 322 2 140 0 322 2 200 0 1133 3 344 4 100 0 100 0 366 7 240 0 180 0 160 0 300 0 344 4 311 1 60 0 120 0 120.0 220.0 260.0 311.1 260.0 444.4 260.0 Diverging from M.D. 6760 311 311 344 8700 311 322 311 7800 20O 9820 344 8212 7260 366 300 7640. 160. 8860. 344. 10260. 60. 9840. 9840. 220. 260. 311. 260. 444. 8980. Phillips Alaska, Inc. Tarn Drill Site 2N 305 slot %305 Tarn Development Field North Slope, Alaska PROPOSAL LISTING INCLUDING POSITION UNCERTAINTIES Baker Hughes INTEQ Your ref : 305 Version Our ref : prop2831 License : Date printed : 1-Sep-2000 Date created : 23-Feb-1998 Last revised : 1-Sep-2000 Field is centred on n70 12 49.742,w150 18 33.414 Structure is centred on nT0 10 13.955,w150 18 32.772 Slot location is nT0 10 13.902,w150 18 48.111 Slot Grid coordinates are N 5912000.641, E 461063.875 Slot local coordinates are 5.37 S 529.47 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North PhilliDs Alaska, Inc. Tarn Drill Site 2N,305 Tarn DeveloDment Field,North SloDe, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R DeDth Degrees Degrees Depth C 0 0 R D I N A T E S 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 0.00 400.00 3.00 12.00 399.95 2.56 500.00 6.00 12.00 499.63 10.23 600.00 9.00 12.00 598.77 23.00 PROPOSAL LISTING Page 1 Your ref : 305 Version %5 700.00 12.00 12.00 697.08 40.82 800.00 15.00 12.00 794.31 63.66 900.00 18.00 12.00 890.18 91.43 1000.00 21.00 12.00 984.43 124.08 1016.70 21.50 12.00 1000.00 130.00 1100.00 24.00 12.00 1076.81 161.51 1200.00 27.00 12.00 1167.06 203.61 1248.51 28.44 11.51 1210.00 225.70 1300.00 29.97 11.04 1254.94 250.34 1300.06 29.97 11.04 1255.00 250.37 1400.00 32.94 10.24 1340.24 301.61 1500.00 35.91 9.56 1422.72 357.30 1600.00 38.89 8.97 1502.16 417.24 1700.00 41.87 8.46 1578.32 481.27 1800.00 44.85 8.00 1651.02 549.22 1900.00 47.84 7.58 1720.04 620.90 2000.00 50.83 7.20 1785.20 696.11 2100.00 53.81 6.86 1846.32 774.65 2200.00 56.80 6.54 1903.23 856.30 2240.42 58.01 6.41 1925.00 890.14 2300.00 59.79 6.24 1955.77 940.84 2390.60 62.50 5.98 1999.49 1019.74 2500.00 62.50 5.98 2050.01 1116.25 3000.00 62.50 5.98 2280.89 1557.34 3041.39 62.50 5.98 2300.00 1593.85 3491.84 62.50 5.98 2508.00 1991.23 3500.00 62.50 5.98 2511.77 1998.43 3507.00 62.50 5.98 2515.00 2004.61 4000.00 62.50 5.98 2742.65 2439.52 4500.00 62.50 5.98 2973.52 2880.61 5000.00 62.50 5.98 3204.40 3321.70 5500.00 62.50 5.98 3435.28 3762.79 6000.00 62.50 5.98 3666.16 4203.88 6430.62 62.50 5.98 3865.00 4583.76 6500.00 62.50 5.98 3897.04 4644.97 6930.88 62.50 5.98 4096.00 5025.09 7000.00 62.50 5.98 4127.92 5086.06 7500.00 62.50 5.98 4358.80 5527.15 8000.00 62.50 5.98 4589.67 5968.24 8212.94 62.50 5.98 4688.00 6156.09 8500.00 62.50 5.98 4820.55 6409.34 8656.89 62.50 5.98 4893.00 6547.74 9000.00 62.50 5.98 5051.43 6850.43 9393.21 62.50 5.98 5233.00 7197.31 9500.00 62.50 5.98 5282.31 7291.52 Last revised : 1-SeD-2000 Dogleg Vert Deg/100ft Sect N 0.00 E 0.00 0.00 N 0.00 E 0.00 0.00 KOP N 0.54 E 3.00 2.61 N 2.18 E 3.00 10.41 N 4.89 E 3.00 23.40 N 8.68 E 3.00 41.53 N 13.53 E 3.00 64.76 N 19.43 E 3.00 93.02 N 26.37 E 3.00 126.24 N 27.63 E 3.00 132.27 Port Collar N 34.33 E 3.00 164.32 N 43.28 E 3.00 207.16 Begin Turn N 47.87 E 3.00 229.62 Base Permafrost N 52.78 E 3.00 254.65 N 52.79 E 3.00 254.68 ToD W Sak N 62.41 E 3.00 306.68 N 72.11 E 3.00 363.09 N 81.89 E 3.00 423.75 N 91.69 E 3.00 488.47 N 101.51 E 3.00 557.09 N 111.31 E 3.00 629.41 N 121.06 E 3.00 705.24 N 130.74 E 3.00 784.37 N 140.32 E 3.00 866.58 N 144.16 E 3.00 900.63 Base W Sak N 149.78 E 3.00 951.65 N 158.22 E 3.00 1030.99 EOC N 168.32 E 0.00 1128.03 N 214.52 E 0.00 1571.52 N 218.34 E 0.00 1608.23 7 5/8" Casing N 259.96 E 0.00 2007.78 C80 N 260.71 E 0.00 2015.01 N 261.36 E 0.00 2021.22 Camp SS N 306.91 E 0.00 2458.51 N 353.10 E 0.00 2902.00 N 399.30 E 0.00 3345.49 N 445.49 E 0.00 3788.99 N 491.68 E 0.00 4232.48 N 531.47 E 0.00 4614.43 C50 N 537.88 E 0.00 4675.97 N 577.69 E 0.00 5058.15 C40 N 584.07 E 0.00 5119.46 N 630.27 E 0.00 5562.96 N 676.46 E 0.00 6006.45 N 696.14 E 0.00 6195.32 Iceberg N 722.66 E 0.00 6449.94 N 737.15 E 0.00 6589.11 T7 N 768.85 E 0.00 6893.44 N 805.18 E 0.00 7242.21 T3.1 N 815.05 E 0.00 7336.93 Ail data is in feet unless otherwise stated. Coordinates from slot %305 and TVD from RKB (Nabors 19E) (153.00 Ft above mean sea level). Bottom hole distance is 8074.96 on azimuth 6.34 degrees from wellhead. Total Dogleg for wellpath is 62.72 degrees. Vertical section is from wellhead on azimuth 6.37 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ o Phillips Alaska, Inc. ~ Tarn Drill Site 2N,305 Tarn Development Field,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S PROPOSAL LISTING ~e 2 Your ref : 305 Version Last revised : 1-Sep-2000 Dogleg Vert Deg/100ft Sect 9555.63 62.50 5.98 5308.00 7340.60 N 820.19 E 0.00 7386.28 T3 9728.88 62.50 5.98 5388.00 7493.44 N 836.19 E 0.00 7539.95 Target %6 Rvsd 1-Sep-00 9902.14 62.50 5.98 5468.00 7646.27 N 852.20 E 0.00 7693.62 T2 10000.00 62.50 5.98 5513.19 7732.61 N 861.24 E 0.00 7780.42 10032.07 62.50 5.98 5528.00 7760.90 N 864.20 E 0.00 7808.87 C35 10332.07 62.50 5.98 5666.53 8025.55 N 891.92 E 0.00 8074.96 TD - Casing Pt Ail data is in feet unless otherwise stated. Coordinates from slot %305 and TVD from RKB (Nabors 19E) (153.00 Ft above mean sea level). Bottom hole distance is 8074.96 on azimuth 6.34 degrees from wellhead. Total Dogleg for wellpath is 62.72 degrees. Vertical section is from wellhead on azimuth 6.37 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Phillips Alaska, Inc. Tarn Drill Site 2N, 305 Tarn Development Field,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : 305 Version #5 Last revised : 1-SeD-2000 Comments in wellpath MD TVD Rectangular Coords. Comment ........................................................................................................... 300.00 1016.70 1200.00 1248.51 1300.06 2240.42 2390.60 3041.39 3491.84 3507.00 6430.62 6930.88 8212.94 8656.89 9393.21 9555.63 9728.88 9902.14 10032.07 10332.07 300 1000 1167 1210 1255 1925 1999 2300 2508 2515 00 3865 00 4096 00 4688 00 4893 00 5233 00 5308 00 5388 00 5468 00 5528.00 5666.53 00 00 06 00 00 00 49 00 00 0.00 N 130.00 N 203.61 N 225.70 N 250.37 N 890.14 N 1019.74 N 1593.85 N 1991.23 N 2004.61 N 4583.76 N 5025.09 N 6156.09 N 6547.74 N 7197.31 N 7340.60 N 7493.44 N 7646.27 N 7760.90 N 8025.55 N 0.00 27.63 43.28 47.87 52 79 144 16 158 22 218 34 259 96 261 36 531 47 577 69 696 14 737 15 805 18 820 19 836 19 852 2O 864 20 891 92 KOP Port Collar Begin Turn Base Permafrost Top W Sak Base W Sak EOC 7 5/8" Casing C80 Camp SS C50 C40 Iceberg T7 T3.1 T3 Target #6 Rvsd 1-Sep-00 T2 C35 TD - Casing Pt ToD MD Top TVD Casing positions in string 'A' Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 3041.39 2300.00 1593.85N 0.00 0.00 0.00N 0.00E 10332.10 5666.53 8025.55N Target name 218.34R 7 5/8 Casing 891.92E 5 1/2 Casing Targets associated with this wellpath Geographic Location T.V.D. Rectangular Coordinates Revised Target #6 Rvsd 1-Sep 461938.000,5919489.000,0.0000 5388.00 7493.44N 836.19R 3-Mar-2000 Phillips Alaska, Inc. Diverter Schematic Nabors 19e Flowline 211~" HYDRIL MSP 2,000 psi WP ANNULAR PREVENTER 16" 200 psi WP HYDRAULIC KNIFE VALVE 21 lA" 2,000 psi WP DRILLING SPOOL w/16" Outlet 16" OD DIVERTER LINE 16-3/4" 2M SOW Starting Head 16-3/4" x 21-1/4" x 2M Psi DSA Flange 16" 62 ppf PEB CONDUCTOR PIPE set at 80' (GL) RECEIVED SEP 0 (:, 2:000 Alaska 0it & Gas Cons. Commission Anchorage Phillips Alaska, Inc. Nabors 19e 11" 5,000 PSI BOP COMPONENTS 3" 5,000 psi WP OCT MANUAL GATE KILL LINE 3" 5,000 psi wP Shaffer GATE VALVE ~-- w/hydraulic actuator / / DSA 13-5/8" 5,000 psi WP x 11" 3,000 psi WP 11" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER w/companion flange to bell nipple DOUBLE 11" 5,000 psi WP, HYDRIL Magnum BOP w/pipe rams on top and blind rams on bottom 3" 5,000 psi wP Shaffer GATE VALVE r_j [~Fm~~raulic actuator 11" 5,000 psi WP L-~~ DRILLING SPOOL w/two 3" 5M psi WP outlets J SINGLE 11" 5,000 psi WP, f HYDRIL MPL BOP w/pipe rams Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 September 5, 2000 RECEIVED Robert Christenson, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re: SEP 06 2000 Alaska & Gas Cons. Commmion Anchorage Application for Permit to Drill KRU 2N-305 Surface Location: 6' FNL, 529' FEL Sec 3 T9N R7E, UM or ASP4, NAD 27 coordinates of X=461,064 & Y=5,912,001 Target Location: 2207' FSL, 317' FWL Sec. 26, T10N, R7E, UM Bottom Hole Location: 2540' FNL, 374' FWL Sec. 26, T10N, R7E, UM Dear Commissioner Christenson, Phillips Alaska, Inc. hereby files this Application for Permit to Drill a development well in the Tarn area, KRU 2N-305, located approximately seven miles southwest of the Kuparuk River Unit's 2M Drillsite. The well is accessed via a new gravel road originating at 2M Pad. Nabors Rig 19e will drill the well. If commercial, the well will also be completed with Nabors 19e. Attached is the information required by 20 AAC 25.005(c). There will be no reserve pit for this well. Waste drilling mud will be disposed of down the annulus of an existing well on Drillsite 2N (subject to AOGCC approval), or hauled to a KRU Class II disposal well. All cuttings generated will be preferentially ground at the on-site ball mill and injected down an approved, existing well annulus on 2N pad or stored temporarily onsite or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. The TD of this well will be in the Tarn formation. H2S has not been encountered in this region in any stratum shallower than the Lisburne Formation. Therefore, Phillips has not included an H2S contingency plan with this Application, and requests an exemption from the H2S requirements. However, all drilling mud, cores and produced fluids exiting the wellbore will be monitored for detectable levels of H2S. The following are Phillips' designated contacts for reporting responsibilities to the Commission: 1) Completion Report Sharon AIIsup-Drake, Drilling Technologist 263-4612 (20 AAC 25.070) 2) Geologic Data and Logs Doug Hastings, Geologist 265-6967 (20 AAC 25.071) If you have questions or require additional information, please contact Tom Brassfield at 265-6377 or me at 265-6434 in our Anchorage office. Si~cerely,_....~ L James Trantham Drilling Engineering Supervisor Attachments cc: KRU 2N-305Well File Phillips Alaska, Inc. is a Subsidiary of Phillips 66 "': ' ',:, ',.: '.'"i:.'i COU ' FIELD & POOL ~ INIT CI_ASS ~~)//_. GEOL AREA ' o. .................. Y,'N 4. Well located in a defined pool .................. ,5. Well located prope~ distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... N 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ .~~I~,~,E~ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... (~ .. 16. CMTvoladequatetocirculateonconductor&surfcsg ..... ' ~f~ ~-.~' 17. CMT vol adequate to tie-in long string to surf csg... ...... ~,.~,,,3~. \ 18. CMT will cover all known productive horizons .......... ' 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... ~ ~',,3j'~. ' 22. Adequate wellbore separation proposed ............. ~ N ~,~ ~.~ ~c~o~.-~c~¢~,~ ,..-~'~:~ ~,,St-~-L~'c_~ " 23. If diverter required, does it meet regulations .......... '~Y~N 24. Drilling fluid program schematic & equip list adequate ..... ~N . · 25. BOPEs, do they meet'regulation ................ Y~N' i ,~j~jip~ DATE 26. BOPE press rating appropriate; test to '~,,~'O(_-'3 psig. .~2~i '.~,~C3C'3 ,., ~, ~-e~_,,~ %,'~e,.c..~ . _~'J)-~ <3,,J_c.- 27. Choke manifold complies w/APl RP-53 (May 84) ........ ~__.)N ¥ -- Ir . · ~ 28. Work will occur without operation shutdown ........... (~jr) N ' ~ ~ 29. Is presence of H2S gas probable ................. ~_' N~,.._ GEOLOGy 30. Permit can be issued wlo hydrogen sulfide measures ..... (~)~~,'//.~..~,~ ' · ~ ~. ' t" J/ 31. Data presented on potent,al overpressure zones ....... .,~-'/N ,.~./~.,/ 32. Seismicanalysisofshallowgaszones. ' , A / y N ~ .... j · · · ' ..... ' ..... ~ ~,-f,-~.- AP~rl~ _.DA.'I'E 33. Seabed cond~bon survey (~foff-shore). . _.. ~//~1 Y N [,I ..w g,.. :..,.. ;,,,.,, '_.~'~Z''''~--' t' _ ~y~-.=~ ~'~ ~ ~ 34. Contact name/phone for weekly progres; re~(~rt;~ ~'e~/;~ol~, only] Y N ,/..~"~.,z'"~/~.L~.~.//4 ./-~,... ANN__.__ULAR DIS.___POSAL35. With proper cementing records, this plan ' ~'~~ ~ ~"'~'"; /'~ '~'/:~ ~'"~"~'~"~'~"/~',,~.~.~"~'3¢'~ ~ '" (A) will contain waste in a suitable receiving zone; ....... ~N V~,, A PR -- -- P DATE (B) will not.contaminate freshwater; or cause drilling waste... [,Y.)N 1~J i,'~lr_3 to surface; ' · -- W r~ o o .(C) will not impair mechanical integrity of the well used for disposal; ~'r~ ~. 4~a, ll.l,-~.~. ' (D) will not damage producing formation or impair recovery from a . pool; and (E) will not circumvent 20 MC 25.252 or 20 MC 25.412. {~') N ENGINEERING: UlClAnnular COMMISSION: Comments/Instructions: , c:~'nsoffiCe\wordian~diana~checklist (rev. 02/1W00) .. 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 APPEN. DIX~ .. No'special'effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Thu May 17 15:33:09 2001 Reel Header Service name ............. LISTPE Date ..................... 01/05/17 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 01/05/17 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kup~ruk River, Unit (Tarn Pool) MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 2 AK-MM-00189 J. MARTIN R. SPRINGER 2N-305 501032034900 Phillips Alaska Inc. Sperry Sun 17-MAY-01 MWD RUN 3 AK-MM-00189 J. MARTIN R. SPRINGER 3 9 N 7 E 6 529 154.73 153.40 119.30 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 16.000 117.0 7.500 7.625 3025.0 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 WAS DIRECTIONAL ONLY AND IS NOT PRESENTED. 3. MWD RUNS 2 & 3 WERE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED THERMAL NEUTRON POROSITY (CTN),AND STABILIZED LITHO-DENSITY (SLD). 4. THE SLD RAPID-SAMPLE MEMORY FILLED AT 7944'MD / 4543'TVD SENSOR DEPTH. THEREFORE, CONVENTIONAL DENSITY DATA ARE PRESENTED FROM THAT POINT TO THE END OF RUN 2. RUN 3 IS ALL RAPID-SAMPLE DATA. 5. MWD DATA ARE CONSIDERED PDC PER E-MAIL FROM D. SCHWARTZ, PHILLIPS ALASKA, DATED 12/29/00. 6. MWD RUNS 2 & 3 REPRESENT WELL 2N-305 WITH API9:50-103-20349-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10334'MD / 5681.64'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVIT (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 7.5" MUD WEIGHT: 9.55 - 9.8 PPG MUD SALINITY: 450 - 1100 PPM CHLORIDES FORMATION WATER SALINITY: 19,149 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/05/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE NPHI NCNT GR FCNT ROP RPX RPS RPM RPD RHOB DRHO PEF FET $ START DEPTH 2930.0 2930 0 2930 0 2930 0 2940 0 3015 5 3015 5 3015 5 3015 5 3020 5 3020 5 3020 5 3025 5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ # REMARKS: STOP DEPTH 10236.0 10236.0 10273.0 10236.5 10334.0 10280 0 10280 0 10280 0 10280 0 10251 5 10251 5 10251 5 10280 0 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 2 2930.0 8659.0 3 8562.0 10334.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name DEPT GR ROP RPX RPS RPM RPD FET NPHI FCNT NCNT RHOB DRHO PEF Service Order Units Size Nsam Rep FT 4 1 68 MWD API 4 1 68 MWD FT/H 4 1 68 MWD OHMM 4 1 68 MWD OHMM 4 1 68 MWD OHMM 4 1 68 MWD OHMM 4 1 68 MWD HOUR 4 1 68 MWD PU-S 4 1 68 MWD CNTS 4 1 68 MWD CNTS 4 1 68 MWD G/CM 4 1 68 MWD G/CM 4 1 68 MWD BARN 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Service Unit Min Max DEPT FT 2930 10334 GR MWD API 43.12 225.25 ROP MWD FT/H 0 308.66 RPX MWD OHMM 0.44 22.92 RPS MWD OHMM 1.28 1230.01 RPM MWD OHMM 0.56 2000 RPD MWD OHMM 0.32 2000 FET MWD HOUR 0.39 28.49 NPHI MWD PU-S 9.8 59.65 FCNT MWD CNTS 93.9 985 NCNT MWD CNTS 12626.9 32280.6 RHOB MWD G/CM 1.31 2.84 DRHO MWD G/CM -0.98 0.58 PEF MWD BARN 1.53 13.86 Mean Nsam 6632 14809 123.57 14687 92.8871 14766 4.26284 14530 4.51858 14530 7.06999 14530 5.52179 14530 1.62649 14510 34.6841 14613 242.604 14614 18977.9 14613 2.26687 14463 0.0257651 14463 2.86119 14463 First Reading 2930 2930 2940 3015.5 3015.5 3015.5 3015.5 3025.5 2930 2930 2930 3020.5 3020.5 3020.5 Last Reading 10334 10273 10334 10280 10280 10280 10280 10280 10236 10236.5 10236 10251.5 10251.5 10251.5 First Reading For Entire File .......... 2930 Last Reading For Entire File ........... 10334 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/05/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/05/17 Maximum Physical Record..65535 File Type ................. LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH NCNT 2930.0 FCNT 2930.0 NPHI 2930.0 GR 2930.5 ROP 2940.0 RPD 3015.5 RPM 3015.5 RPS 3015.5 RPX 3015.5 PEF 3020.5 DRHO 3020.5 RHOB 3020.5 FET 3025.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 SLD STABILIZED LITHO DEN CTN COMP THERMAL NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): STOP DEPTH 8561.5 8562.0 8562.0 8598 0 8659 0 8605 0 8605 0 8605 0 8605 0 8576 5 8576 5 8576 5 8605 0 29-SEP-00 Insite 4.15 Memory 8659.0 58.9 66.6 TOOL NUMBER PB01655GRV4 PB01655GRV4 PB01655GRV4 PB01655GRV4 7.500 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 LSND 9.60 46.0 9.0 45O 5.8 2.700 1.376 3.000 2.500 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD020 API 4 1 68 4 2 ROP MWD020 FT/H 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020, OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 NPHI MWD020 PU-S 4 1 68 32 9 FCNT MWD020 CNTS 4 1 68 36 10 NCNT MWD020 CNTS 4 1 68 40 . 11 RHOB MWD020 G/CM 4 1 68 44 12 DRHO MWD020 G/CM 4 1 68 48 13 PEF MWD020 BARN 4 1 68 52 14 60.0 124.3 60.0 55.0 Name Service Unit Min Max Mean Nsam DEPT FT 2930 8659 5794.5 11459 GR MWD020 API 43.12 225.25 120.22 11336 ROP MWD020 FT/H 0.19 308.66 101.462 11439 RPX MWD020 OHMM 0.44 18.34 4.06857 11180 First 'Reading 2930 2930.5 2940 3015.5 Last Reading 8659 8598 8659 8605 RPS MWD020 OHMM 1.28 1230.01 RPM MWD020 OHMM 0.56 2000 RPD MWD020 OHMM 0.32 2000 FET MWD020 HOUR 0.39 6.07 NPHI MWD020 PU-S 12.43 59.65 FCNT MWD020 CNTS 93.9 751.5 NCNT MWD020 CNTS 12626.9 30261.9 RHOB MWD020 G/CM 1.31 2.84 DRHO MWD020 G/CM -0.98 0.58 PEF MWD020 BARN 1.53 13.86 o 4.36306 11180 7.63258 11180 5.57382 11180 1.36369 11160 36.2281 11265 220.865 11265 18359.2 11264 2.23322 11113 0292054 11113 2.90744 11113 3015.5 3015.5 3015.5 3025.5 2930 2930 2930 3020.5 3020.5 3020.5 8605 8605 8605 8605 8562 8562 8561.5 8576.5 8576.5 8576.5 First Reading For Entire File .......... 2930 Last Reading For Entire File ........... 8659 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/05/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name'. ............ STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation..i .... 01/05/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH NCNT 8562.0 NPHI 8562.5 FCNT 8562.5 PEF 8577.0 RHOB 8577.0 DRHO 85'77.0 GR 8598.5 RPM 8605.5 RPS 8605.5 RPD 8605.5 FET 8605.5 RPX 8605.5 ROP 8659.5 STOP DEPTH 10236.0 10236 0 10236 5 10251 5 10251 5 10251 5 10273 0 10280 0 10280 0 10280 0 10280 0 10280 0 10334 0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 SLD STABILIZED LITHO DEN CTN .COMP THERMAL NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY '(LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE' (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION ,(IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 03-OCT-00 Insite 4.15 Memory 10334.0 59.5 64.3 TOOL NUMBER PB01655GRV4 PB01655GRV4 PB01655GRV4 PB01655GRV4 7.500 LSND 9.70 41.0 10.4 3OO 4.8 3.000 1.485 3.250 2.300 63.0 134.2 65.0 65.0 Depth Units ....................... Datum Specification Block sub-type.. Name DEPT GR ROP RPX RPS RPM RPD FET NPHI FCNT NCNT RHOB DRHO PEF Service Order Units Size Nsam Rep FT 4 1 68 MWD030 A?I 4 1 68 MWD030 FT/H 4 1 68 MWD030 OHMM 4 1 68 MWD030 OHMM 4 1 68 MWD030 OHMM 4 1 68 MWD030 OHMM 4 1 68 MWD030 HOUR 4 1 68 MWD030 ?U-S 4 1 68 MWD030 CNTS 4 1 68 MWD030 CNTS 4 1 68 MWD030 G/CM 4 1 68 MWD030 G/CM 4 1 68 MWD030 BARN 4 1 68 .0 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Service Unit Min Max DEPT FT 8562 10334 GR MWD030 API 69.99 194.39 ROP MWD030 FT/H 0 170.95 RPX MWD030 OHMM 1.26 22.92 RPS MWD030 OHMM 1.28 24.23 RPM MWD030 OHMM 1.34 22.41 RPD MWD030 OHMM 1.35 20.48 FET MWD030 HOUR 0.8 28.49 NPHI MWD030 ?U-S 9.8 46.61 FCNT MWD030 CNTS 156.2 985 NCNT MWD030 CNTS 16316.1 32280.6 RHOB MWD030 G/CM 1.61 2.72 DRHO MWD030 G/CM -0.1 0.41 PEF MWD030 BARN 1.89 7.1 Mean 9448 134.923 63.4047 4.9112 5.0376 5.19244 5.34815 2.502 29.4887 315.728 21058.7 2.3785 0.0143522 2.70777 Nsam 3545 3350 3327 3350 3350 3350 3350 3350 3348 3349 3349 3350 3350 3350 First Reading 8562 8598.5 8659.5 8605.5 8605.5 8605.5 8605.5 8605.5 8562.5 8562.5 8562 8577 8577 8577 Last Reading 10334 10273 10334 10280 10280 10280 10280 10280 10236 10236.5 10236 10251.5 10251.5 10251.5 First Reading For Entire File .......... 8562 Last Reading For Entire File ........... 10334 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/05/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ........ ' ............. 01/05/17 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Reel Trailer Service name ............. LIST?E Date ..................... 01/05/17 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Library. Scientific Scientific Technical Technical Services Services Physical EOF Physical EOF End Of LIS File
