The URL can be used to link to this page

Home My WebLink About203-160 e e Image Project Well History File Cover Page 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. cQ Q 3 - 1 bo Well History File Identifier Production Scanning Stage 1 Page Count from Scanned File: <i5 y- (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES ~ Ma,;a ) Date (pl'q /0(, If NO in stage 1, page(s) discrepancies were found: Organizing (done) ~WO-Sided 1111111111111111111 R~CAN '\¢' Color Items: D Greyscale Items: DIGITAL DATA D Diskettes, No. D Other, Noffype: D Poor Quality Originals: D Other: NOTES: Date {g:'¡o/ jfJ0 Date. (g ,19/0 fp ~ x 30 = ~O Date 1o/lq/o(P BY: ~ Project Proofing BY: ~ Scanning Preparation BY: C Maria ") BY: Stage 1 BY: Maria Date: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: Comments about this file: D Rescan Needed III 11111111 1111I111 OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) D Logs of various kinds: D Other:: 151 VV1P "' 111/11111111111I 151 V\1f <63 + ~3 = TOTAL PAGES (Count does not include cover sheet) 151 mP 11111111111111 "III 151 NO VV1P YES NO 151 11/1111111/11111111 1111111111111' "III 151 Quality Checked III 111/1111I111111I 10/6/2005 Well History File Cover Page. doc • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. June 17, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Whipstock Setting Record: 3H -10B Run Date: 6/8/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3H -10B Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 103 - 20087 -02 1 ul e ? 9 ;— PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood ` .> *' ,V N SEP 12 2011 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 ::::•? • - ,urton.com Date: 0.. Signed: 6W1 2,6 -I 6 III STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned Q Suspended ❑ 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development 0 Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: y® ,. ConocoPhillips Alaska, Inc. orAband.: July 11, 2011 203 - 160 / 311 - 193 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 May 10, 2004 50 103 - 20087 - 02 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 1322' FNL, 281' FWL, Sec. 12, T12N, R8E, UM May 12, 2004 3H - 10B Top of Productive Horizon: 8. KB (ft above MSL): 28' RKB 15. Field /Pool(s): 941' FNL, 896' FWL, Sec. 12, T12N, R8E, UM GL (ft above MSL): 67' AMSL Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): 836' FNL, 4250' FEL, Sec. 12, T12N, R8E, UM 3368' MD / 3367' TVD Kuparuk River Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x 498655 y 6000335 Zone 4 6410' MD / 6274' TVD ADL 25531 TPI: x - 499270 y - 6000716 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 499404 y 6000821 Zone 4 497' MD / 497' TVD 2657 18. Directional Survey: Yes ❑ No IS 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1591' MD / 1591' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re drill /Lateral Top Window MD/TVD none 4b As O (: ., not applicable 23. d U CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 Surf. 108' Surf. 108' 24" 225 sx AS I 9.625" 40# L -80 Surf. 3024' Surf. 3023' 12.25" 1300 sx AS III, 100 sx AS I, 300 sx Class G 7" 15.5# L -80 Surf. 6264' Surf. 5902' 8.5" 450 sx Class G, 200 sx AS I 1 4.5" 12.6# L -80 3368' 6405' 3365' 6269' 6.125" 115 sx LiteCRETE, 110 sx Class G 24. Open to production or injection? Yes ❑ No 0 If Yes, list each 25. TUBING RECORD Interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET ( MD/TVD) 4.5" 3380' 3379' MD / 3377' TVD perfs plugged off: 6039' - 6059' MD 5943' - 5960' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 6069' - 6089' MD 5969' - 5987' TVD DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 6124' -6144' MD 6018' -6036' TVD 6039' -6200' 10 bbls 15.8 ppg cement 6154' -6164' MD 6045-6054' TVD 6190' -6200' MD 6077' -6086' TVD 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) not applicable plugged Date of Test Hours Tested Production for OIL -BBL GAS -MCF WATER -BBL CHOKE SIZE GAS - OIL RATIO Test Period -> Flow Tubing Casing Pressure Calculated OIL -BBL GAS -MCF WATER -BBL OIL GRAVITY - API (corr) Press. psi 24 -Hour Rate -> ! 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No 0 Sidewall Cores Acquired? Yes ❑ No 0 If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. A.,,,itiMap AUG 242011 NONE RECEIVED D RBDMS AUG 16 2011 AUG 16 2011 Form 10 -407 Revised 12/2009 CONTINUED ON REVERSE Dhaka O; & Gal C'. , mito nly „00,0age 28. GEOLOGIC MARKERS (List all formations and markers Altered): 29. • FORMATION TESTS NAME MD TVD Well tested? ❑ Yes 0 No If yes, list intervals and formations tested, Permafrost - Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Bottom 1591' 1591 needed, and submit detailed test information per 20 AAC 25.071. not applicable N/A Formation at total depth: Kuparuk 30. LIST OF ATTACHMENTS Summary of Daily Operations, schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Gary Eller @ 263 - 4172 Printed Name L. Gmlft 4 Title: CTD Engineering Supervisor _ Signature ` "�+"` �V Phone 265 - 6306 Date \ \8I Sharon Allsup -Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item la: Classification of Service wells: Gas injection, water injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 3H -10B Well Events Summary DATE ' SUMMARY 5/24/11 TAGGED FILL @ 6136' SLM. BRED 4.5" LINER FROM 6000' - 6100' SLM. RIFTED TBG WITH 3.72" x 15' DUMMY WHIPSTOCK. READY FOR E -LINE. 6/1/11 LOGGED 24 -ARM CALIPER FROM 6160' TO SURFACE., DATA SUBMITTED FOR PROCESSING. WELL TURNED OVER TO DSO TO BOL. 6/8/11 SET BAKER 3.625 X 4.5 MONO -BORE EXTENDED WHIPSTOCK (TOWS) AT 6043' W/ HES DPUI, ECCENTERED WEIGHT BARS AT 20 DEGS RIGHT OF HIGHSIDE LOOKING DOWNHOLE. NOTICED ROLL TO LEFT TO 16 DEG ROHS ON ENGAGEMENT AND FINISH AT 11 DEG ROHS AFTER SET PROCESS COMPLETE. ATTEMPT TO POOH AND UNABLE TO DISENGAGE FROM WHIPSTOCK. PUMP 90 BBLS SLICK DIESEL W/ LROS. PULLED OUT OF ROPE SOCKET._" *RA TAG AT 6055' REFERENCED TO K1 MARKER. WELL LEFT SI AND FP. 6/12/11 RECOVERED ELINE FISH @ 5973' SLM. IN PROGRESS. 6/13/11 TAG TOP OF WHIPSTOCK @ 6018' SLM (6043' CORRECTED RKB). 6/14/11 LOG MIT -24 CALIPER ACROSS WHIPSTOCK TO VERIFY DEPTH LOCATION AND ORIENTATION. TOWS= 6043'. Orientation and depth appear same as original E -line set. Orientation to be confirmed with processing. 6/27/11 MEAURED BHP @ 6030' SLM: 3265 PSI. SET 3.812 DB LOCK WITH PX PLUG IN DB NIPPLE @ 3328' RKB. PULLED OV @ 3286' RKB. PUMPED 100 BBL DSL DOWN TBG TAKING RETURNS UP IA. SET DV @ 3286' RKB. MITIA 2500 PSI, PASSED. PULLED PLUG FROM DB NIPPLE. READY FOR CTU. 6/29/11 DISLACE WELL W/ SW AND PERFORM INJECT TEST PR @ 0.25 BLM = 700 PSI PR @ 0.50 BLM = 750 PSI PR @ 1.0 BLM = 855 PSI WELL SI & FP, BACK TOMORROW FOR CEMENT SQL., IN PROGRESS 6/30/11 PERFORM 40 BBL CONTINUOUS RUNNING CEMENT SQZE TO A & C SANDS PERFS, PLACED APPDX ` 10 BBL 15.8 PPG CEMENT BEHIND PIPE, WASHED ALL REMAINING CEMENT TO TANKS, TRAPPED 1575 PSI ON WH, WELL FP, IN PROGRESS 7/2/11 MIT TBG TO 1500 PSI ** PASS LOCATE 3.812 DB- NIPPLE WITH BLB @ 3328' RKB,TAG TOP OF CEMENT Ca. 6024' SLM, READY FOR CTD 7/3/11 (PRE -CTD) PT & DD TEST MV- PASSED; SSV- PASSED; SV- PASSED 7/6/11 MIRU on 3H pad. Nipple up BOPE to release top drive. Lay down PDLs. Secure top drive. 7/7/11 Make repairs to Jib Booms & Reinstall. Test for hydraulic operation String new PDL winch cables 7/8/11 Complete rig up in cellar and Putz, Take on fluids, Stab coil in injector and fill. Total of 39 hours for Mast/Jib repairs. 7/9/11 Complete BOPE Test, Pull BPV , Cut 95' coil to find wire M/U Coil connector 7/10/11 Head up E -line and test, M/U Bighole Window millingBHA. Start milling window 7/11/11 Complete window, P/U Bighole BHA, Drill Ahead. 4 KUP * 3H 10B ConocoP ° llt ° / 1.Wgll Attributes - Max Angle & MD TD AtiSrta, h1C f " W Wellbore APUUWI Field Name W ll Status Ind r) MD (ftKB) Act BM1n (ftKB) Cr.t: xo1'I tH;r. 501032008702 KUPARUK RIVER UNIT PROD 14.43 3,490.58 6,410.0 Comment H25 (p b 1 ) Date Annotation End Dale KB God (ft) Rig Release Da ..___- _WatOsaka- ,3H•10KALW41a _.., S SSV: NIPPLE � 180 11/8/2010 Las[ WO: 42.40 1216/1987 n 9..�..�... -,..: - - ShcmneOC- A13Yek _ Annotation Depth (fl KB) !End Date 'Annotation Last Mod ... End Date Last Ta LM 6,139.0 5/24/2011 Rev Reason: GLV C/O S et Whipstock, Cement Tag ninam 7/15/2011 Casing Strings � - __. _.. Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt ... String ... String Top Thrd HANGER, 23 1 � CONDUCTOR 16 15.062 36.0 108.0 108.0 62.50 H40 WELDED ..arm. Casing Description String 0... String ID ... Top (MB) Sat Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd SURFACE 9 5/8 8.921 35.2 3,024.3 3,023 7 36.00 J - 55 BTC Casing Description String 0... String ID ... Top (NCB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top TAM PRODUCTION Post 7 6.276 32.5 3,560.0 26.00 J -55 BTC Sidetrack Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd 7 6.276 3,539.0 3,549.0 26.00 L Casing Description String 0... String ID ... Top (fH(B) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd I LINER 41/2 3.958 3,367.6 6,405.0 12.60 L-80 SLHT ner Details CONDUCTOR, Top Depth 36-106 (ND) Top Incl N r . To • KB (ftKB) O Item D scri • lion Comment ID (n) NIPPLE, 497 j ' 3,367.6 3,365.2 11.65 TIE -BACK TIE BACK SLEEVE 5.250 ; SLEEVE i1 3,379.1 3,376.5 12.16 PACKER ZXP LINER PACKER w/ HR PROFILE 4.400 3,386.1 3,383.4 12.47 NIPPLE BAKER RS NIPPLE 4.250 3,388.1 3,385.3 12.56 HANGER BAKER FLEX -LOCK HYD ROT HANGER 4.400 3,398.2 3,395.1 12.80 XO BUSHING CROSS OVER BUSHING 3.958 Tubing_Stnngs Tubing Description String 0... I String ID Top (ftKB) Set Depth (i Set Depth (ND) .. String Wt... 'Siring String Top Thrd SURFACE, �;: TUBING I 4 1/2 I ,3 958 ...I Top 23.3 3,380 1 l 3,377A 12 60 I L I IBTM 35 -3,024 Corn • letion Details IkI' Top Depth �- (ND) Top Inc! Bond... GAS LIFT, To• (ftKB (ftKB) 1') Item Description Comment ID (in) 3,2e6 23.3 23.3 0.10 HANGER FMC GEN 5 TUBING HANGER 4.000 F - �- -- 496.9 496.9 0.15 NIPPLE CAMCO DB LANDING NIPPLE NO GO 3.875 3,328.2 3,326.4 9.91 NIPPLE CAMCO DB NIPPLE NO GO 3.812 NIPPLE, 3,328 3 ,367.4 3,365.0 11.64 XO BUSHING XO BUSHING 4.500 fir 3,368.6 3,366.2 11.70 LOCATOR BAKER G -22 LOCATOR SUB 3.938 3,369.4 3,367.0 11.74 SEAL ASSY BAKER PER SEAL ASSEMBLY 4.360 Other In Hole (Wireline retrievable plugs, valves, pumps, fish,_ etc) X0 BUSHING. ... I Top Depth 3,367 - (TVD) Top Inc! LOCATOR, _ T• • MIME_ (1169) (°) Descrl• on Comment Run Date ID(in) 3 • 6,043 WHIPSTOCK BAKER MONOBORE WHIPSTOCK 6/8/2011 SEAL ASSY. 3.369 Perforations & Slots r ! Shot � - T• • Top 1 (NKB) D) Blm (ND) Dens ftKB 8 (11KB) Zone Date (sh••• Type Comment 6,039 ftKB Btm 6,059 C4, 3H -10 5/27/2004 6.0 IPERF 2 -7/8" HSD PJ, 60 deg ph 6.069 6,089 _ C-4, C -3, 3H -10B 5/27/2004 6.0 IPERF 2 -7/8" HSD PJ, 60 deg ph _ 6,124 6,144 A5, A-3, 3H-106 5/27/2004 6.0 IPERF 2 -7/8" HSD PJ, 60 deg ph 6,154 6,164 A -2, 3H -10B 5/27/2004 6.0 IPERF 2 -7/8" HSD PJ, 60 deg ph 6,190 6,200 A -1, 3H -10B 5/26/2004 6.0 IPERF 2 -7/8" HSD PJ, 60 deg ph WINDOW B. _- - - - -.__ 3,539 -3,549 Notes: General & Safety._ PRODUCTION - - -- -- - - - -- Post Sidetrack, _ E nd Date Annotation 33 5/15/2004 NOTE: WELL SIDETRACKED w/CTD FOR SECOND TIME 11/24/2004 NOTE: WAIVERED WELL: IA x OA COMMUNICATION CEMENT, - - 't 6,028 11/5/2010 NOTE: View Schematic w/ Alaska Schema6c9.0 i Ail-vsTOO<, 6,0 PEW , _ 6,039-6,059 IPERF,_ 6,069 -6,080 PERF, 6,124-6,144 IPER 1 I 6,154-6.164 PER IPERF, II 6,1905,200 I I Intermed Il L inty, 5,301 -6,390 Cti n e Mandrel Details - - / Top Depth Top Pot (TVD) Inc! OD Valve Latch Size TRO Run Stn Top mks) MKS) (°) Make Model (in) Sere Type Type (in) (psi) Run Date Corn... .rra 1 3,286.5 3285.3 8.07 CAMCO KBG - 2 1 GAS LIFT DMY BEK 0.000 0.0 6/27/2011 LINER, 3,368$405 [ - TD (3H -10B), 6,410 1 • • WELL LOG TRANSMITIAL PROACTIVE DIA SERViCES, INC. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659 -5102 RE : Cased Hole /Open Hole /Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : VA 4,11, JUL Q 3 2011 ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 (1.L 1) Caliper Report r'c.-Jun-11 # e. 1 Report/ CD > ✓': F 2) 3 Signed : - -- - Date : Print Name: t --. ' a"L k\o.. . PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAX: (907)245 -8952 E-MAIL : PDSANCHORAGE(CDMEMORYLOG.COM WEBSITE : WWW.MEMORYLOG.COM D:\ Archives\ Distribution\ Transmitta1Sheets \ConocoPhilips_Transmit.docx 1 • • I Memory Multi- Finger Caliper ,i ...___ c k..._71 Log Results Summary 1 Company: ConocoPhillips Alaska, Inc. Well: 3H -10B Log Date: June 1, 2011 Field: Kuparuk I Log No. : Run No.: 10291020 ZX70 State: Alaska 1 API No.: 50- 103 - 20087 -02 Pipet Desc.: 4.5" 12.6 Ib. L-80 IBTM / L-80 SLHT Top Log Intvll.: Surface Pipet Use: Tubing & Liner Bot. Log Intvll.: 6,165 Ft. (MD) 1 Inspection Type : Corrosive & Mechanical Damage Inspection p Yp 9 P 1 COMMENTS : The caliper data is correlated to Schlumberger SCMT cement bond log (May 26, 2004) 1 This log was run to assess the condition of the tubing and liner with respect to corrosive and mechanical damage. The caliper recordings indicate the 4.5" tubing and liner logged appears to be in good to poor condition, with I a maximum wall penetration of 56% recorded in joint 136 (4,287'). Additional wall penetrations ranging from 20% to 53% are recorded in 56 joints of 203 joints analyzed. Recorded damage appears in the form of lines of pits and isolated pitting. No significant areas of cross - sectional wall loss or I.D. restrictions are recorded throughout the tubing and liner logged. 1 This summary report is an interpretation of data provided by Halliburton Energy Services. 4.5" TUBING & LINER - MAXIMUM RECORDED WALL PENETRATIONS: 1 Line of Pits ( 56 %) Jt. 136 @ 4,287 Ft. (MD) Line of Pits ( 53 %) Jt. 139 @ 4,359 Ft. (MD) Line of Pits ( 50 %) Jt. 142 @ 4,480 Ft. (MD) I Line of Pits ( 46%) Jt. 137 @ 4,319 Ft. (MD) Isolated Pitting (38 %) Jt. 69 @ 2,160 Ft. (MD) I 4.5" TUBING & LINER - MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS: No significant areas of cross - sectional wall loss (> 9 %) are recorded throughout the tubing and liner logged. I 4.5" TUBING & LINER - MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded throughout the tubing and liner logged. 1 Mandrel Orientation 3H - 10B ConocoPhillips Alaska, Inc. Kuparuk 2- Jun -11 1 Joint No. Tool Deviation Mandrel No. Latch Orientation 105.2 9 1 1:00 1 Field Engineer: B. Sanders Analyst: C. Lucasan Witness: J. Condio I ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565 -9085 Fax: (281) 565 -1369 E -mail: PDS ©memorylog.com Prudhoe Bay Field Office Phone: (907) 659 -2307 Fax: (907) 659 -2314 1 2- C3_l(D6 1 • • Correlation of Recorded Damage to Borehole Profile 1 N Pipe 1 4.5 in (17.2' - 6151.4') Well: 3H -10B Field: Kuparuk I Company: Country: ConocoPhillips Alaska, Inc. USA Survey Date: June 01, 2011 1 1 ■ Approx. Tool Deviation ■ Approx. Borehole Profile 1 20 1 l i m..... 1 25 771 I 50 i 1548 +•r 1 75 ` 2324 _ E I 100 — 3093 GLM 1 E •` ._ Z s 1 .c p 125 - 3923 1 150 4697 iii 1 211 175 5470 1 197 6151 0 50 100 1 Damage Profile (% wall) / Tool Deviation (degrees) 1 1 Bottom of Survey = 197 1 1 1 • • I PDS Report Overview 11 ,,. Body Region Analysis I Well: 3H -10B Survey Date: June 01, 2011 Field: Kuparuk Tool Type: UW MFC 24 No. 1000429 (HAL) Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 I Country: USA No. of Fingers: 24 Tubing: 4.5 ins 12.6 ppf L -80 IBTM Analyst: C. Lucasan Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom.Upset Upper len. Lower len. 4.5 ins 12.6 ppf L -80 IBTM 3.958 ins 4.5 ins 6.0 ins 6.0 ins 1 Penetration(% wall) Damage Profile (% wall) I 150 Penetration body Metal loss body 0 50 100 0 100 50 II a 0 48 ` - I 0 to 20% 20 to 40 to over 40% 85% 85% Number of joints analysed (total = 203) 1 142 53 8 0 98 1 Damage Configuration ( body) GI M 1 150 I 100 145 50 0 I Isolated General Line Other Hole/ — Pitting Corrosion Corrosion Damage Pos. Hole Number of joints damaged (total = 137) 195 I 137 0 0 0 0 Bottom of Survey = 197 1 1 1 1 1 • 0 PDS REPORT JOINT TABULATION SHEET I Pipe: 4.5 in 12.6 ppf L -80 IBTM Well: 3H -10B Body Wall: 0.271 in Field: Kuparuk I Upset Wall: 0.271 in Company: Country: ConocoPhillips Alaska, Inc. Nominal I.D.: 3.958 in USA Survey Date: June 01, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (°/0 wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 0.1 17 0 0.03 11 2 3.94 Pup 1 20 0 0.05 18 2 3.94 Shallow Pitting. 1.1 51 0 0.04 13 2 3.96 Pup Shallow Pitting. 1.2 57 0 0.01 5 1 3.95 Pup 2 59 0 0.05 18 3 3.94 Shallow Line of Pits. I ■ 3 90 0 0.05 19 3 3.96 Shallow Pitting. a 4 121 0 0.05 17 2 3.95 Shallow Pitting. ■ 5 150 0.04 0.05 20 3 3.95 Shallow Pitting. ■ 6 182 0 0.07 24 3 3.94 Line of Pits. ■ I 7 212 0 0.05 20 3 3.96 Shallow Pitting. • 8 243 0 0.06 21 > 3.95 Line of Pits. ■ 9 275 0.04 0.06 20 3 3.95 Isolated Pitting. ■ 10 306 0 0.05 18 3 3.95 Shallow Pitting. ■ I 1 1 336 0 0.06 20 3 3.95 Isolated Pitting. is 367 0 0.04 16 2 3.95 Shallow Pitting. ■ 13 399 0 0.05 19 2 3.95 Shallow Pitting. 14 430 0 0.04 16 2 3.95 Shallow Pitting. I 15 461 0 0.04 15 3 3.95 Shallow Pitting. 15.1 492 0 0 0 0 3.88 Camco DB Landing Nipple 16 493 0 0.04 16 3 3.96 Shallow Pitting. 17 524 0 0.04 17 3 3.94 Shallow Line of Pits. ■ 18 555 0 0.04 16 3 3.96 Shallow Pitting. is I 19 586 0 0.04 16 2 3.95 Shallow Pitting. • 20 616 0 0.04 17 3 3.96 Shallow Pitting. ■ 21 648 0 0.05 18 3 3.96 Shallow Line of Pits. ■ 22 679 0 0.04 17 2 3.95 Shallow Pitting. is I 23 710 0 0.05 17 3 3.95 Shallow Pitting. is 741 0 0.05 18 3 3.94 Shallow Line of Pits. ■ 25 771 0 0.06 22 3 3.94 Isolated Pitting. is 26 802 0 0.04 15 2 3.95 Shallow Pitting. • 1 27 833 0 0.05 18 4 3.94 Shallow Pitting. ■ 28 863 0.04 0.05 17 3 3.94 Shallow Pitting. ■ 29 894 0 0.03 13 2 3.94 Shallow Pitting. ■ 30 925 0.0 3 0.04 13 2 3.93 Shallow Pitting. • 31 955 0.04 0.05 20 7 3.84 Shallow Pitting. Lt. Deposits. ■ I 32 986 0.03 0.05 18 7 3.82 Shallow Line of Pits. Lt. Deposits. 33 1016 0.05 0.05 19 8 3.84 Shallow Line of Pits. Lt. Deposits. 1 34 1047 0.04 0.06 22 9 3.84 Line of Pits. Lt. Deposits. i 35 1079 0 0.03 11 3 3.86 Lt. Deposits. ■ I 36 1111 0 0.03 12 3 3.88 Shallow Pitting. Lt. Deposits. 37 1142 0 0.06 22 4 3.94 Isolated Pitting. ■ 38 1172 0 0.04 14 3 3.95 Shallow Line of Pits. ■ 39 1203 0.04 0.06 23 3 3.92 Line of Pits. ■ I 40 1235 0 0.07 24 3 3.92 Isolated Pitting. ■ 41 1267 0 0.04 15 3 3.93 Shallow Line of Pits. ■ 42 1298 0 0.05 18 3 3.94 Shallow Pitting. ■ 43 1330 0 0.07 26 5 3.91 Line of Pits. • 44 1361 0 0.08 29 3 3.96 Isolated Pitting. I 45 1392 0 0.06 23 3 3.96 Isolated Pitting. 46 1424 (.1 0.07 24 3 3.93 Isolated Pitting. rt I Penetration BoBody dy I Page 1 1 1 • 0 PDS REPORT JOINT TABULATION SHEET I Pipe: 4.5 in 12.6 ppf L -80 IBTM Well: 3H -10B Body Wall: 0.271 in Field: Kuparuk I Upset Wall: 0.271 in Company: Country: ConocoPhillips Alaska, Inc. Nominal I.D.: 3.958 in USA Survey Date: June 01, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments ( %wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 47 1455 () 0.07 24 3 3.95 Isolated Pitting. ■ 48 1487 0 0.06 21 3 3.95 Isolated Pitting. ■ 49 1517 0 0.07 27 3 3.94 Line of Pits. is 50 1548 0 0.06 24 2 3.93 Line of Pits. ■ 51 1580 0 0.08 28 3 3.94 Isolated Pitting. ■ I 52 1610 (1 0.07 24 3 3.91 Isolated Pitting. ■ 53 1642 0 0.05 19 3 3.91 Shallow Pitting. ■ 54 1673 0 0.05 18 3 3.95 Shallow Pitting. ■ 55 1704 0 0.04 17 4 3.86 Shallow Pitting. Lt. Deposits. ■ I 56 1733 3) 0.06 22 3 3.96 Line of Pits. • 57 1764 0.04 0.05 20 2 3.95 Shallow Pitting. ■ 58 1794 0 0.05 18 3 3.94 Shallow Line of Pits. • 59 1826 0 0.04 15 3 3.95 Shallow Pitting. • I 60 1858 0.03 0.08 28 3.94 Line of Pits. ■ 61 1888 0 0.07 27 .3 3.96 Isolated Pitting. ■ 62 1919 0 0.06 24 2 3.95 Line of Pits. • 63 1950 0 0.08 30 2 3.92 Isolated Pitting. ■ I 64 1981 0.04 0.05 20 2 3.95 Shallow Pitting. 65 2013 0.0 1 0.04 14 3 3.91 Shallow Line of Pits. ■ 66 2045 0.04 0.06 21 2 3.96 Isolated Pitting. ■ 67 2077 0 0.04 14 3 3.95 Shallow Line of Pits. ■ 68 2108 0 0.05 18 2 3.95 Shallow Pitting. ■ I 69 2138 0 0.10 38 4 3.94 Isolated Pitting. ■ 70 2168 0 0.03 12 2 3.96 ■ 71 2201 0 0.04 14 4 3.90 Shallow Pitting. ■ 72 2232 0 0.04 16 2 3.95 Shallow Pitting. • I 73 2264 0 0.08 28 3 3.94 Isolated Pitting. ■ 74 2293 0 0.04 15 1 3.96 Shallow Pitting. IN 2324 0 0.04 16 3 3.96 Shallow Pitting. ■ 76 2354 0 0.05 17 2 3.95 Shallow Pitting. ■ I 77 2385 0 0.05 17 3 3.92 Shallow Pitting. NI 2415 0 0.07 25 2 3.95 Isolated Pitting. ■ 79 2444 0 0.04 16 2 3.96 Shallow Pitting. ■ 80 2475 0 0.03 12 3 3.95 Shallow Pitting. ■ 81 2506 0 0.07 24 3 3.96 Isolated Pitting. • I 82 2538 0 0.03 10 2 3.94 IN 83 2569 0 0.03 10 2 3.93 ■ 84 2599 0 0.03 12 I 3.96 IN 85 2630 0 0.06 22 3 3.96 Isolated Pitting. • I 86 2661 0 0.04 14 .3 3.94 Shallow Line of Pits. IN 87 2691 0 0.07 24 2 3.96 Isolated Pitting. ■ 88 2722 0 0.05 19 2 3.95 Shallow Pitting. ■ 89 2753 0 0.03 10 2 3.95 ■ I 90 2784 0 0.06 23 2 3.95 Isolated Pitting. ■ 91 2815 0 0.04 17 2 3.94 Shallow Pitting. IN 2845 0 0.05 17 2 3.94 Shallow Pitting. ■ 93 2877 0 0.05 18 2 3.96 Shallow Pitting. ■ I 94 2907 0 0.04 17 2 3.95 Shallow Line of Pits. ■ 95 2939 0 0.04 14 2 3.94 Shallow Pitting. ■ 96 2969 0 0.03 10 1 3.95 Bo I Metal Loss Body Page 2 Penetration 1 1 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 4.5 in 12.6 ppf L -80 IBTM Well: 3H -10B Body Wall: 0.271 in Field: Kuparuk Upset Wall: 0.271 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 3.958 in Country: USA Survey Date: June 01, 2011 I Joint Jt. Depth Ik n. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments ( %wall) (fns.) (Ins.) % (Ins.) 0 50 100 I 97 3000 0 0.06 20 3 3.95 Isolated Pitting. 98 3031 0 0.02 6 1 3.95 99 3061 0 0.04 15 1 3.95 Shallow Pitting. 100 3093 t) 0.04 17 1 3.95 Shallow Pitting. 101 3124 0 0.03 10 1 3.94 I 102 3155 0 0.03 11 1 3.94 103 3185 0 0.02 8 2 3.95 104 3217 0 0.02 8 3 3.88 Lt. Deposits. 105 3249 0 0.03 9 3 3.88 Lt. Deposits. I 105.1 3278 0 0.01 6 1 3.96 Pup 105.2 3284 0 0 0 0 3.90 GLM 1 (Latch 1:00) 105.3 3291 0 0.02 9 1 3.96 Pup 106 3297 () 0.04 14 2 3.91 Shallow Pitting. I 106.1 3326 0 0 0 0 3.81 Camco DB Nipple 107.1 3359 0 0.01 6 1 3.95 Pup 107.2 3365 0 0 0 0 4.50 XO Bushing 107.3 3366 0 0 0 0 3.94 Baker G -22 Locator Sub 107.4 3376 0 0 0 0 4.36 Baker PBR Seal Assembly I 107.5 3379 0 0 0 0 4.40 ZXP Liner Packer with HR Profile 107.6 3386 0 0 0 0 4.25 Baker RS Nipple 107.7 3388 0 0.03 12 1 4.41 Pup 108 3398 0 0.10 38 1 3.94 Line of Pits. 109 3430 0.04 0.02 9 1 3.97 110 3461 0 0.02 6 2 3.96 111 3492 0 0.05 18 2 3.97 Shallow Pitting. 112 3522 0 0.02 8 2 3.94 I 113 3553 0 0.02 9 2 3.95 114 3584 0 0.02 8 2 3.96 115 3614 0 0.03 11 1 3.95 116 3645 0 0.03 11 1 3.96 I 117 3676 0 0.03 11 2 3.96 118 3707 0 0.04 13 1 3.96 Shallow Pitting. 119 3738 0 0.02 9 2 3.93 120 3769 0 0.03 12 2 3.96 121 3800 0 0.03 10 2 3.95 I 122 3831 0 0.03 10 2 3.95 123 3861 0 0.02 6 2 3.95 124 3892 0 0.03 9 1 3.94 125 3923 0 0.06 23 2 3.90 Line of Pits. I 126 3955 0 0.02 8 1 3.95 127 3985 0 0.03 132 3.96 Shallow Pitting. 128 4017 0 0.02 8 1 3.93 129 4047 0 0.03 10 2 3.96 I 130 4078 0 0.02 9 1 3.96 131 4109 0 0.03 10 2 3.94 132 4140 0 0.04 13 2 3.95 Shallow Pitting. 133 4171 0 0.03 10 3 3.94 134 4203 0 0.02 9 1 3.96 I 135 4234 0 0.03 10 1 3.96 136 4265 0 0.15 56 3 3.93 Line of Pits. Penetration Bo I Metal Loss Body 1 Page 3 1 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 4.5 in 12.6 ppf L -80 IBTM Well: 3H -10B Body Wall: 0.271 in Field: Kuparuk I Upset Wall: 0.271 in Company: Country: ConocoPhillips Alaska, Inc. Nominal I.D.: 3.958 in USA Survey Date: June 01, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 137 4297 0 0.13 46 3 3.95 Line of Pits. 138 4328 0 0.02 6 1 3.96 139 4358 0.11 0.14 53 3 3.93 Line of Pits. ■ 140 4389 0 0.10 37 2 3.96 Isolated Pitting. 141 4421 0.09 32 2 3.91 Isolated Pitting. iii 142 4452 0 0.14 50 4 3.95 Line of Pits. I 143 4483 0.08 0.03 10 1 3.96 144 4514 O 0.05 18 1 3.93 Shallow Pitting. ■ 145 4545 0 0.04 14 I 3.96 Shallow Pitting. I 146 4576 0 0.02 7 1 3.96 147 4606 0 0.02 8 2 3.96 3 148 4636 0 0.04 17 1 3.95 Shallow Line of Pits. 149 4666 0 0.02 7 1 3.94 I 150 4697 0 0.04 13 2 3.92 Shallow Pitting. ■ 151 472 7 0 0.03 10 2 3.95 152 4757 0 0.01 6 2 3.95 3 153 4789 0 0.03 9 1 3.94 ■ I 154 4820 0 0.03 11 2 3.96 155 4851 0 0.01 6 2 3.95 156 4881 0 0.02 8 2 3.93 157 4913 0 0.03 11 2 3.93 ■ 158 4944 0 0.03 10 2 3.93 I 159 4976 160 5007 0 0.02 9 2 3.93 0 0.03 10 2 3.93 ■ 161 5037 0 0.03 10 2 3.91 ■ 162 5068 0 0.03 11 2 3.90 ■ I 163 5099 0 0.03 13 1 3.93 Shallow Pitting. 164 5131 0 0.02 9 2 3.91 165 5162 0 0.03 11 2 3.90 Lt. Deposits. 7 166 5193 0 0.02 8 2 3.92 I 167 5224 0 0.03 10 2 3.92 ■ 168 5255 0 0.04 14 1 3.92 Shallow Pitting. 15 169 5286 0 0.03 12 2 3.93 Shallow Pitting. ■ 170 5317 0 0.04 13 2 3.92 Shallow Pitting. ■ 171 5348 0 0.04 13 2 3.90 Shallow Pitting. ■ I 172 5379 0 0.04 15 3 3.92 Shallow Pitting. ■ 173 5409 0 0.04 14 2 3.89 Shallow Pitting. Lt. Deposits. ■ 174 5440 0 0.03 12 2 3.92 Shallow Pitting. IN 175 5470 0 0.04 13 1 3.93 Shallow Pitting. • I 176 5501 0 0.04 15 3.90 Shallow Pitting. • 177 5532 0 0.04 14 3 3.94 Shallow Pitting. ■ 178 5563 0 0.05 19 2 3.93 Shallow Pitting. ■ 179 5594 0.09 0.04 14 2 3.92 Shallow Pitting. ■ 1 180 5625 0 0.05 18 2 3.93 Shallow Pitting. ■ 181 5656 0 0.09 33 2 3.93 Line of Pits. ■ 182 5687 0 0.04 13 1 3.96 Shallow Pitting. ■ 183 5718 0 0.06 21 2 3.96 Isolated Pitting. ■ I 184 5749 0.05 0.06 23 3 3.92 Isolated Pitting. ■ 185 5780 0.04 0.07 28 3 3.95 Isolated Pitting. ■ 186 5811 0 0.05 18 2 3.92 Shallow Pitting. rat I Metal Loss ion Body Page 4 Penet 1 1 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 4.5 in 12.6 ppf L -80 IBTM Well: 3H -10B Body Wall: 0.271 in Field: Kuparuk I Upset Wall: 0.271 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 3.958 in Country: USA Survey Date: June 01, 2011 I Joint Jt. Depth Pen. Pen. Pen. Met,rl Min. Damage Profile No. (Ft.) U % pset Body I oss I.D. Comments (% wall) (Ins.) (Ins.) °/, (Ins.) 0 50 100 I 187 5841 0 0.06 23 t 3.96 Isolated Pitting. 188 5872 0 0.05 20 4 3.96 Shallow Line of Pits. IN NI 189 5903 0 0.06 22 4 3.93 Isolated Pitting. ■m 190 5934 0.04 0.07 25 4 3.98 Line of Pits. on 191 5966 0.06 0.07 25 4 3.96 Isolated Pitting. ■ I 192 5996 0.05 0.09 34 5 3.96 Line of Pits. mi 193 6027 0.06 0.20 74 8 3.90 Perforations. Lt. Deposits. imi 194 6058 0.06 0.21 78 15 3.80 Perforations. Lt. Deposits. ■ 195 6089 0.04 0.08 30 3 3.93 Line of Pits. . ■ I 196 6120 0 0.18 67 6 3.97 Perforations. 197 6151 0.03 0.21 76 6 3.94 Perforations. I Prat I Metal Loss ion Body 1 1 1 1 1 1 1 1 1 Page 5 1 1 1 • • 1 PDS Report Cross Sections 111 \. 4 -S. I Well: 3H -10B Kuparuk Survey Date: June 01, 2011 Field: Tool Type: UW MFC 24 No. 1000429 (HAL) Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 1 Tubing: 4.5 ins 12.6 ppf L -80 IBTM Analyst: C. Lucasan 1 1 Cross Section for Joint 136 at depth 4287.097 ft Tool speed = 50 Nominal ID = 3.958 I Nominal OD = 4.5 Remaining wall area = 97% . I Tool deviation = 12° / 1 \ 1 1 — 1 1 \ ......___ / 1 \ ‘,/' 1 I Finger = 9 Penetration = 0.152 ins Line of Pits 0.15 ins. = 56% Wall Penetration HIGH SIDE = UP 1 1 1 1 1 1 • • 1 PDS Report Cross Sections Well: 3H -10B Survey Date: June 01, 2011 Field: Kuparuk Tool Type: UW MFC 24 No. 1000429 (HAL) Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 1 Tubing: 4.5 ins 12.6 ppf L -80 IBTM Analyst: C. Lucasan 1 1 Cross Section for Joint 139 at depth 4358.896 ft Tool speed = 50 Nominal ID = 3.958 I Nominal OD = 4.5 Remaining wall area = 97% �� \ Tool deviation = 11° / 1 1 T 1 I __ / 1 2)/ \ \� � `■• 1 Finger = 9 Penetration = 0.143 ins Line of Pits 0.14 ins. = 53% Wall Penetration HIGH SIDE = UP 1 1 1 1 1 lib KUP ConocoPhillips 014 Weore WI Field Name Weft Status n & MD TD 3H -10B Ind B Act trn ) [oriomfedkps 501032008702 KUPARUK RIVER UNIT PROD 14.43 3,490.58 6,410.0 Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date ••• Weil Confia -3H- 108,5/19/2011 3 38 22 PM SSSV: NIPPLE 180 11/8/2010 Last WO: 42.40 12/6/19$7 I Schematic -Actual Annotation Depth MKS) End Date Amotatlm Last Mod ... End Date Last Tag: SLM 6,142.0 8/29/2010 Rev Reason: FORMAT UPDATE Imosbor 5;19/2011 - Casing Strings Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd i HANGER. 23 �� CONDUCTOR 16 15.062 36.0 108.0 1080 62.50 H -40 WELDED - Casing Description String 0... String ID ... Top (NCB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.921 352 3,024.3 3,023.7 3600 J BTC Casing Description Sting 0... String ID ... Top MKS) Set Depth (f... Set Depth (7VD)... String WL.. String ... String Top Thrd PRODUCTION Post 7 6.276 32.5 3,560.0 26.00 J-55 BTC Sidetrack P Casing Description String 0... String ID ... Top (((KB) Set Depth (f... Set Depth (TVD) ... String Wt... String... String Top Thrd WINDOW B 7 6.276 3,539.0 3,549.0 26.00 L Casing Description String 0... String ID ... Top (RKB) Set Depth (L.. Set Depth (1VO) ... String WL.. String ... String Top Thrd LINER 41/2 3.958 3,367.6 6,405.0 12.60 L-80 SLHT Liner Details t Top Depth (TVD) Top Intl Noni... Top (NCB) MB) PI Rem Description Comment ID tin) I CONDU36 - 106 CTOR, 3,367.6 3,365.2 11.65 TIE -BACK TIE BACK SLEEVE 5.250 SLEEVE 3,379.1 3,376.5 12.16 PACKER ZXP LINER PACKER w/ HR PROFILE 4.400 NIPPLE, 497 1 SO 3,386.1 3,383.4 12.47 NIPPLE BAKER RS NIPPLE 4.250 3,388.1 3,385.3 12.56 HANGER BAKER FLEX -LOCK HYD ROT HANGER 4.400 3,398.2 3,395.1 12.80 XO BUSHING CROSS OVER BUSHING 3.958 Tubing Strings Tubing Description String 0... String ID ... Top (NCB) Set Depth (f... Set Depth (1VD) ... String Wt... String ... String Top Thrd TUBING 41/2 3.958 23.3 3,380.1 3,377.4 12.60 L-80 IBTM • i Completion Details Top Depth (TVD) Top Ind Nonni... SURFACE Top lftiCW (((KB) 19 Item Description Comment ID pry 35-3 23.3 23.3 0.10 HANGER FMC GEN 5 TUBING HANGER 4.000 t 496.9 496.9 0.15 NIPPLE CAMCO DB LANDING NIPPLE NO GO 3.875 I r 3,328.2 3,326.4 9.91 NIPPLE CAMCO DB NIPPLE NO GO 3.812 CAS LIFT, 3 29! 3,367.4 3,365.0 11.64 XO BUSHING XO BUSHING 4.500 3,368.6 3,366.2 11.70 LOCATOR BAKER G -22 LOCATOR SUB 3.938 3,369.4 3,367.0 11.74 SEAL ASSY BAKER PBR SEAL ASSEMBLY 4.360 �PP�E 3x26 1 s Perforations & Slots Dens Top (TVD) Btm (TVD) D arw Shot Top (IIKS) Btrn (rtKe) lRKB) MKB) Zone Date 1 Type Comment 6,039.0 6,0590 C-4, 3H -10 5/27/2004 6.0 IPERF 2 -7/8" HSD PJ, 60 deg ph 6,069.0 6,089.0 C -4, C -3, 3H -10B 5/27/2004 6.0 IPERF 2 -7/8" HSD PJ, 60 deg ph ■ I xo BUSHING. � I,.. 6 6,164.0 A 2, 3H- -106 106 5/27/2004 6.0 IPERF 2 -7/8" HSD PJ, 60 deg Ph 3.367 LOCATOR. 6,190.0 6,200.0 A - 1, 3H - 10B 5/26/2004 6.0 IPERF 2 - 7/8" HSD PJ, 60 deg ph 3,369 SEAL ASSY, Notes: General & Safety 3,369 i i Annotation Date v Annotation I 5/15/2004 NOTE: WELL SIDETRACKED w /CTD FOR SECOND TIME 11/24/2004 NOTE: WAIVERED WELL: IA x OA COMMUNICATION 11/5/2010 NOTE: View Schematic w/ Alaska Schematic9.0 • _ [. 1 MB WINDOW B. I 3.5398.549 PRODUCTION Post Sidetrack, 33-3,560 IPERF, 6039-6059 I IPERF. 6,0698,069 IPERF, 5,124-6,144 IPERF, 6 Mandrel Details IPERF, - Top Depth Top Pont 6,190-6,200 = (1VD) Intl (1p Valve L.atdr Size 1900 Run Stn Top ( NCB) (ERB) P) Make Model (in) Sery Type Type MI (psi) Run Date tom... 1 3,286.5 3,285.3 8.07 CAMCO KBG - 2 1 GAS LIFT OV BEK 0.188 0.0 2/1/2008 I LINER, . \ . j 1 3,3668,405 TD (30 -109), 6,410 e ' • • SlfAll[E AIAZIKKA SEAN PARNELL, GOVERNOR ALASKA OIL AND (AS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMNIISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276-7542 Gary Eller CTD Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3H -10B Sundry Number: 311 -193 Dear Mr. Eller: ` a ,1U 9 2 ( 9 011 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair DATED this day of June, 2011. Encl. a: #1, .1 eti ak , ALAS �� ALASKA AND GAS CONSERVATION OMMISSI - 11 I APPLICATION FOR SUNDRY APPROV ' ii 2 I.1�,; �P , ,Ili , 20 AAC 25.280 1. Type of Request: Abandon r Rug for Redrill 17 • Perforate New Pool r Repair w ell NI 1Vnprg d Pt (a jt Suspend �� +RJR "c�t3� tv 0� u_ " " - (( p r Plug Perforations Perforate r Pull T ubing r Time &tension P Operational Shutdow n f Re -enter Susp. Well r Stimulate r Alter casing r Other: s` ricf rd Cr r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 17,7 Exploratory r 203 -160 • 3. Address: Stratigraphic r Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 - 103 - 20087 - • 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No 3H -10B • 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 25531 • Kuparuk River Field / Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 6410 - 6274 • 6309' • 6183' • Casing Length Size MD TVD Burst Collapse CONDUCTOR 72 16 108' 108' SURFACE 2989 9.625 3024' 3023' PRODUCTION 3528 7 6264' 5902' LINER 3037 4.5 6405' 6269' Perforation Depth MD ( 6039' - 6059', Perforation Depth TVD (ft): 5943'- 5960', Tubing Size: Tubing Grade: Tubing MD (ft): 6069', 6089', 6124'- 6144', 6154'- 6164', 6190' -6200' 5969' - 5987', 6018'- 6036', 6045- 6054', 6077' -6086' 4.5 L -80 3380 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - ZXP LINER PACKER MD= 3379 TVD= 3377 NIPPLE - CAMCO DB LANDING NIPPLE NO GO MD= 497 TVD= 497 12. Attachments: Description Summary of Proposal p"' 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development 17` • Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 6/10/2011 Oil r Gas f WDSPL r Suspended P' 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Gary Eller @ 263 -4172 V .,.._ Printed Name Gary Eller Title: CTD Engineer Signature Phone: 263 -4172 Date SI31' lk Commission Use Only Sundry Number: 3 f f q 3 Conditions of approval: Notify Commission so that a representative may witness f Plug Integrity r BOP Test ic Mechanical Integrity Test r Location Clearance r 03S'00 rsz. 86e IL/— Other: / / A' OD ,, y n r Ices e Z$ YO �,GA /-4-t 44c, z-5-7// 4 ( i Subsequent Form Required: v ti - ` APPROVED BY /7/ / Approved by: THE COMMISSION Date: 7 1 B MAY 09 rib 4..z -11 Form 10 -4 Rev�is ' i 2 01 1 : , R 1 G 1 N A Submit irfDuplicate 44 .._' • KU P • 3H -10B Hs. t C O lli � p asi Well Attributes Max Angle & MD TD Wellbore APIIU WI Field Name Well Status Ind ( °) IMD (ftKB) Ad Btm (ftKB) C.ennmPhOkpS'.. 501032008702 KUPARUK RIVER UNIT PROD 14.43 349058 64100 ' " Comment H25 (ppm) Date Annotation End Date KB -Grd (ft) Rig Release Date SS SV NIPPLE 180 11/8/2010 Last WO ■ 42 40 1216/1987 soornetio - Ad.) A notation Depth (ftKB) End Date Annotation Last Mod End Date Last Tag: SLM I 6,142.0 8/29/2010 Rev Reason FORMAT UPDATE Imosbor 5;19/2011 Casing Stnn s Casing Description - String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd wa;_• CONDUCTOR 16 15.062 36.0 108.0 108.0 62.50 H WELDED HANGER, 23 to C as i ng Description String 0... String ID ... Top (ftl(B) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top That SURFACE 95/8 8.921 35.2 3,024.3 3,023.7 36.00 J - 55 BTC Casing Description String 0... String ID ... Top (BKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top That PRODUCTION Post 7 6.276 32.5 3,560.0 26.00 J -55 BTC Sidetrack Casing Description String 0... String ID ... Top (HKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd I p WINDOW B 7 6.276 3,539.0 3,549.0 26.00 L Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top That . ?'a: LINER 41/2 3.958 3,367.6 6,405.0 12.60 L -80 SLHT .4 Liner Details Top Depth ; (ND) Top Intl Henri... Top (ftKB) ( ( ° ) Item Description Comment ID (in) CONDUCTOR. 3,367.6 3,365.2 11.65 TIE - BAC K TIE BACK SLEEVE - - 5.250 36 SLEEVE 3,379.1 3,376.5 12.16 PACKER ZXP UNER PACKER w/ HR PROFILE 4.400 NIPPLE, 497 C - - -- 3,386.1 3,383.4 12.47 NIPPLE BAKER RS NIPPLE 4.250 ; 3,388.1 3,385.3 12.56 HANGER BAKER FLEX -LOCK HYD ROT HANGER 4.400 ' . i 3,398.2 3,305 1 12 80 XO BUSHING CROSS OVER BUSHING 3958 n Tubing Strings s Tubing Description String O String ID ... Top (ftK8) Set Depth (t... Set Depth (ND) ... String Wt... String Stri g Top Thrd TUBING 4 U2 3 -958 I 23.3 I 3,380 1 3,377.4 12.6 L 80 1 IBTM Completion tion Deta Top Depth 1, (ND) Top Intl N i.. SURFACE, T ep(tKB) (ftK8) (°I Item Description Comment ID (in) 35 - 3,024 23.3 23.3 0 -10 HANGER FMC GEN 5 TUBING HANGER 4.000 496.9 496.9 0.15 NIPPLE CAMCO DB LANDING NIPPLE NO GO 3.875 1 11 3,3282 3,326.4 9.91 NIPPLE CAMCO DB NIPPLE NO GO 3.812 GAS LIFT. 3,2e6 - - - - -- I 3,36 3,365.0 11.64 XO BUSHING XO BUSHING 4.500 3,368.6 3,3662 11 70 LOCATOR BAKER G -22 LOCATOR SUB 3.938 3,369.4 3,367.0 11 74 SEAL ASSY BAKER PBR SEAL ASSEMBLY 4.360 Perforations & Slots NIPPLE, 3,328- x i (1. I ' i Shot .iii‘ Top (TVD) Btm (TVD) Dens Top (ftKB) Bbn (MKS) MKS) (ftK8) Zone Date (ah -- Type Comment 6,039.0 6,059.0 C-4, 3H -10 5/27/2004 6.0 IPERF 2 -7/8" HSD PJ, 60 deg ph hi' 6,069.0 6,089.0 C-4, C -3, 3H -10B 5/27/2004 6.0 IPERF 2 -7/8" HSD PJ, 60 deg ph 6,124.0 6,144.0 AS, A -3, 3H-10B 5/27/2004 6.0 IPERF 2 -7/8" HSD PJ, 60 deg ph XO BUSHING, _ - ' 6,154.0 6,164.0 A -2, 3H -10B 5/27/2004 6.0 IPERF 2 -7/8" HSD PJ, 60 deg ph 3,367 r LOCATOR, 6,190.0 6,200 0 A - 1, 3H - 108 5/26/2004 6.0 IPERF 2 - 7/8" HSD PJ, 60 deg ph 3.369 SEAL ASSY, Notes: General & Safety 3,369 �� End Date Annotation 5/15/2004 NOTE: WELL SIDETRACKED w /CTD FOR SECOND TIME 11/24/2004 NOTE: WAIVERED WELL: IA x OA COMMUNICATION 11/5/2010 NOTE: View Schematic w/ Alaska Schematic9 0 L � WINDOW B, 3,539 -3,549 PRODUCTION Post Sidetrack, 33- 3,560 F, � -6.059 .) • l ND p IPERF. f r �4 6,0696,089 -. IPERF. -': - '- - 6,1246,144 IPERF, 6,1546,164 Mandrel p To p D IPERF, e Top Depth Top Port 6,190 -6,200 (TVD) Intl OD Valve Latch Size TRO Run Ste Top MKS) MKS) e) Make Model (inl Seen Tyne Type ON (Psi) Run Date Corn... 1 3,286.5 3,285.3 8.07 CAMCO KBG -2 1 GAS LIFT OV BEK 0.188 0.0 2/1/2008 I LINER, 3,368- 6,405 i ,N [ TD (3H 6,410 6,410 • • M KRU 3H - 10B CTD Summary for Plugging Sundry (10 -403) Summary of Operations: Well 3H -10B is a Kuparuk C -sand and A -sand production well equipped with 4%2" tubing and 4 production liner. Four proposed A -sand CTD laterals will increase reservoir exposure and offset the planned 3H -12 CTD injection laterals. Prior to rig arrival, a 4%2" mechanical whipstock will be set at the planned kickoff point of 6045' MD in 3H -10B. After setting the whipstock we will down- squeeze around the whipstock to permanently abandon the A -sand and C -sand perfs, which will isolate these zones and help mechanically stabilize the 4 liner in the vicinity of the sidetrack point. ConocoPhillips requests a variance from the requirements of 20 ...__ AAC 25.112(c)(1) to plug the perfs in this manner. The 3H -10C sidetrack will exit the 4Y2" liner at 6045' MD from the mechanical whipstock that was set pre -rig. Initially our BOPE will be equipped for `bighole' CTD operations (i.e. 3" BHA). We will drill through the C- sand into the A -sand with a 4 bi- center bit to a depth of 6397' MD. We will then run 620' of 3 ", 6.6 ppf, L-80 liner with TC -II connections from 5777' to 6397'. The 3 liner will be cemented in place with 7 bbl of 15.8 ppg cement, which will isolate the C -sand behind pipe. After allowing the cement to set and reconfiguring our BOPE for slimhole operations (i.e. 2%" BHA), we will drill out the shoe of the 3 liner with a 3" bi- center bit targeting the A2 sand east of the existing well with a 2328' lateral (measured from shoe of 3 liner). The lateral will be completed with 2%" slotted liner to the TD of 8725' MD with an aluminum billet at 7150' MD. / The 3H -10CL1 lateral will kick off from the aluminum billet at 7150' MD and will target the A3 sand east of the 3H -10B well with a 1660' lateral. The hole will be completed with a 2 slotted liner to the TD of 8800' MD with the liner top inside the 3 liner at 6387' MD. The 311-10CL2 lateral will kick off from a mechanical whipstock set inside the 3 liner at 6230' MD. It will target the A3 sand north of 3H -10B with a 1680' lateral. The hole will be completed with a 2%" slotted liner to the TD of 7910' MD with an aluminum billet at 6500' MD. The 3H- 10CL2 -01 lateral will kick off from the aluminum billet at 6500' MD and will target the A2 sand north of the 3H -10B well with a 1445' lateral. The hole will be completed with a 2%" slotted liner to the TD of 7945' MD with the liner top inside the 3 liner at 6220' MD. After completing the 3H- 10CL2 -01 lateral, we will run a 3 x 4 liner -top packer at 5777' to provide further isolation to the C -sand formation that is behind the 3 cemented liner. CTD Drill and Complete 3H -10B Laterals: July 2011 Pre -CTD Work 1. Positive pressure and drawdown tests on master valve & swab valve 2. RU e -line. Set 4 monobore whipstock at 6045' MD with a highside orientation. RD e-line. 3. RU slickline. Obtain updated static BHP on A -sand. Dummy off all GLMs. RD slickline 4. RU coil. Down - squeeze the A -sand and C -sand perfs with cement. RD coil. - -rte 4, - • 5. RU slickline. Tag top of cement. RD slickline. 6. Prep site for Nabors CDR2 -AC, including setting BPV Mat'", OA f 7k well 4o &vetoe d a r- less r44nn 200 64f® - �i ..I. Co�ew • G t i� Yoe TO 9' '/q 7 -r4 f4f w 0 "0(7 w'' ' ry! t✓a �w 1 Ave lo ^t�P tee// S4oa /d ,`m ►i P 1 of 2 i �`r',► a well Qf rnvl r; wor o� age 1 of 2 ..b' p/ti T Po 0.4 ik ,0°" ev i May 31, 2011, FINAL • • KRU 3H -10B CTD Summary for Plugging Sundry (10 -403) Rig Work 1. MIRU Nabors CDR2 -AC rig using 2" coil tubing. NU 7- 1/16" BOPE, test. BOPE will be configured for `bighole' CTD operations. 2. 3H -10C Intermediate Hole Section a. Mill 3.80" window with high -side orientation at 6045' MD. b. Drill 3.70" x 4'/8" bi- center lateral to TD of 6397' MD c. Run 31/4" blank liner with TC -]I connections from TD up to 5777'inside the 4 %" liner d. Swap from e-coil to e-free coil ql e. Cement 31/4" liner in place with 7 bbl of 15.8 ppg cement using e -free coil �t 3. 3H -10C Sidetrack (A2 sand, east) a. Swap from e-free to e-coil tubing. Reconfigure BOPE for slimhole drilling; retest BOPE as �� needed. b. Mill out 31/4" shoe at 6397' MD with 2.74" mill c. Drill 2.70" x 3" bi- center lateral to TD of 8725' MD d. Run 2 slotted liner with an aluminum billet from TD up to 7150' 4. 3H -10CL1 Lateral (A3 sand, east) a. Kick off of the aluminum billet at 7150' MD b. Drill 2.70" x 3" bi- center lateral to TD of 8800' MD c. Run 2 slotted liner from TD up into the 31/4" liner at 6387' 5. 3H -10CL2 Lateral (A3 sand, north) a. Set a mechanical whipstock inside the 31/4" liner at 6230' b. Mill 2.74" window at 6230' c. Drill 2.70" x 3" bi- center lateral to TD of 7910' MD d. Run 2%" slotted liner with an aluminum billet from TD up to 6500' 6. 3H- 10CL2 -01 Lateral (A2 sand, north) a. Kick off of the aluminum billet at 6500' MD b. Drill 2.70" x 3" bi- center lateral to TD of 7945' MD c. Run 2 slotted liner from TD up to 6220' MD, up inside the 31/4" liner 7. Run 31/4" x 4'/2" liner -top packer at 5777' to further isolate the C -sand 8. Freeze protect. Set BPV, ND BOPE. RDMO Nabors CRD2 -AC. Post -Rig Work 1. Pu11 BPV 2. Obtain static BHP 3. Put well on production Page 2 of 2 May 31, 2011, FINAL i 3H -1OC Proposed CTD Sidetrack Last Updated: 31- May -11 4 -1/2" Camco DB nipple @ 502' MD (ID = 3.875 ") 16" 62.5# H -40 4 -1/2" 12.6# L -80 IBT -Mod Tubing to surface shoe @ 108' MD 9 -5/8" 36# J -55 4 -1/2" Camco KBG -21 gas lift mandrel @ 3291' shoe @ 3023' MD 4 -1/2" DB landing nipple @ 3328 MD (3.812" min ID) K- 1.......— Locator @ 3373' MD Baker seal assembly @ 3375' MD IIII _ _ - Liner top, 7" 26# L -80 window @ Baker 4 -1/2" x 7" ZXP liner top packer @ 3379' MD • 3549' MD Baker Flex -Lock liner hanger @ 3388' MD -, G) 3 -1/4" x 4 -1/2" liner -top i / KB packer at 5777' KOP @ 6045' MD 3H- 10CL2 -01, TD = 7945' ■ 2 %" liner top 6220' 3H -10CL2 TD = 7910' C -sand perfs (sgz'd) 'y :f--- - - ••_ - --- ---- ----- 2 %" liner top 6039' -6059' MD i . a „w,, :::= 6500' • 6069' -6089' A -sand perfs (sgz'd) L. - --- : :- 6124'-6144' MD i/� •- ---• - --: 6154' -6164' -J KOP for CL2 .- 6190' -6200' lateral = 6230' 3 -1/4 ", L -80, TCII 3H- 10CL1, TD = 8800' cemented liner r - :•- -: =' 2%e' liner top 6387 4 -1/2" 12.6# L -80 liner �� 5777' - 6397' MD °/% 3367' - 6405' MD 3H -10C, TD = 8725' 2 %" liner top 7150' • • Page 1 of 1 Subject: FW: INTENT PLUG for RE -DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monday, February 08, 2010 10:52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE -DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE -DRILL WELLS ( IBPRD) Type Work Code in RBDMS 1. When a Form 10 -403 is submitted requesting approval to plug a well for redrill, the initial reviewer (Art or Steve D.) will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 form is checked. If the "Abandon" box is checked, we will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). 2. On the Form 10 -403 if "Abandon" is checked in Box 15 (Well Status after proposed work), Art or Steve D. will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). Instead, we will check the "Suspended" box. Guy and Winton will serve as quality control for steps 1 and 2. 3. When Steve McMains receives the Form 10 -403 with a check in the "Plug for Redrill" box, he will enter the existing code "IBPRD" into RBDMS. This code automatically generates a comment under the History tab stating "Intent: Plug for Redrill." 4. When Steve McMains receives any Form 10 -407, he will check the History tab in RBDMS for this comment. If he sees the "Intent: Plug for Redrill" code, and cannot find any evidence that a subsequent re -drill has been COMPLETED, he will assign a status of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10 -407. Steve will also change the status on the 10 -407 form to SUSPENDED, and will date and initial his change. If Steve does not see the "Intent: Plug for Redrill" comment or code, he will enter the status listed on the Form 10 -407 into RBDMS. 5. When the Form 10 -407 for the redrill is received, Steve M. will change the original well's status from suspended to abandoned. 6. The first week of every January and July, Steve M. and Steve D. will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, Steve M. and Steve D. will also review the list of suspended wells for accu racy. Thanks, Steve D. file: / /F: \Daily_ Document_ Record \Procedures_Instructions \FW INTENT PLUG for RE- DRI... 6/2/2011 r'1 ~ Conoc P ' ' o hillips Aiaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 11, 2009 Mr. Tom Maunder Alaska Qil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ., , , , *. i ;4a ~~~}~;l~;n C`N , ~ ~ ::J i.::..Y . ~x . ~ ~ ~p 3 -, ~v l~ _ j C~~ 3 ~i Enclosed please find a 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 cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped July 30~' 2009 and the corrosion inhibitor/sealant was pumped August 8th, 9~' and 10~` 2009. 'The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please ca11 Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, ~~G%~ MJ Lov land ConocoPhillips Well Integrity Projects Supervisor ~ ~ ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annufus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 08/71/A9 ~~ ~~ ~~. o ~,. ~ ell Name PI # TD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date ....~ Corrosion inhibitor ~ Corrosion inhibitor/ sealant date bbls a~ 3G-12 50103201310000 1900730 24' 4.00 20" 7/30/2009 4.25 8/10/2009 3G-13 50103201370000 1901160 17" Na 17" n/a 2.97 8/10/2009 3G-15 50103201390000 1901210 18" n/a 18" n/a 2.97 8/10/2009 3G-23 50103201440000 1901320 17" n/a 17" n/a 1.27 8/10/2009 3H-02 50103200830000 1871070 21" n/a 21" n/a 3.82 8/8/2009 3H-06 50103200780000 1870780 8'5" 2.00 18" 7/30/2009 5.52 8/8/2009 3H-07 50103200790000 1870790 17" n/a 17" n/a 2.97 8/8/2009 3H-09 50103200860000 1871120 17" n/a 17" n/a 5.52 8/8l2009 3H-10B 50103200870200 2031600 16" n/a 16" n/a 2.55 8/8/2009 3H-12 50103200880000 1871290 2'7" n/a 2'7" n/a 8.92 8/9/2009 3H-15 50103200820000 1871030 19" n/a 19" _ n/a 3.4 8/9/2009 3H-16A 50103200960100 2000220 15' 2.75 17" 7/30/2009 1.7 8/9/2009 3H-18 50103200950000 1880090 SF n/a 17" n/a 5.52 8/9/2009 3H-20 50103200930000 1871340 16' 3.75 16" 7/30/2009 2.25 8/9/2009 3H-22 50103200970000 1880110 27'6" 4.25 21" 7/30/2009 8.5 8/9/2009 3H-25 50103202030000 1990400 30" n/a 30" n/a 7.65 8/9/2009 3H-26 50103202080000 1940290 SF n/a 9" n/a 2.12 8/9/2009 3H-28A 50103202360100 1960370 SF n/a 18" n/a 5.1 8/9/2009 3H-32 50103203220000 2000010 10" n/a 10" n/a 1.27 8/9/2009 3K-102 50029233786000 2071650 n/a Na 5" n/a 1.27 8/8/2009 3Q-01 50029222200000 1911250 15'7" 2.00 17" 7/30/2009 4.25 8/8/2009 3Q-02 50029216880000 1870040 41' 4.75 21" 7/30/2009 5.52 8/8/2009 3Q-04 50029222190000 1911240 4'10" 1.60 16" 7/30/2009 4.25 8/8/2009 3Q-07 50029216820000 1861940 6" n/a 6" n/a 1.7 8/9/2009 3Q-12 50029216770000 1861890 7" n/a 7" Na 2.97 8/8/2009 3Q-13 50029216640000 1861760 44'6" 5.00 21" 7/30/2009 8.92 8/8/2009 3Q-15 50029216660000 1861780 49'5" 4.50 20" 7/30/2009 9.35 8/8/2009 3Q-16 50029216670000 1861790 46' 5.25 30" 7/30/2009 8.5 8/8/2009 • ~ ~~ STATE OF ALASKA ~ ~B ~ ~ ~~d~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATION~aska Oil & Gas Ce;is. (:afrt~r~ission 1. Operations Performed: Abandon ^ Repair Well ^ Plug Pertorations ^ Stimulate ^/ ~ Other fIC aga Alter Casing ^ Pull Tubing ^ Pertorate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Pertorate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Ir1C. Development ~ ' Exploratory ^ 203-160 / 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-103-20087-02 ° 7. KB Elevation (ft): 9. Well Name and Number: RKB 28', AMSL 67' 3H-106 ' 8. Property Designation: 10. Field/Pool(s): a ADL 25531 Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 6410' feet true vertical 6274' feet Plugs (measured) Effective Depth measured 6220' feet Junk (measured) true vertical feet I~~ FEB ~~ ~ ~ 200 ~ Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 108' 16" 108' 108' SURFACE 2957' 9-5/8" 3024' 3023' PRODUCTION 3482' 7" 6264' 5902' LINER 3038' 4.5" 6405' 6269' Perforation depth: Measured depth: 6039'-6059', 6069'-6089', 6124'-6144', 6154'-6164', 6190'-6200' true vertical depth: 5943'-5961', 5969'-5987', 6018'-6036', 6045'-6053', 6077'-6086' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 3385' MD. Packers & SSSV (type & measured depth) ZXP liner pkr @ 337s' Camco landing nipple Q 502' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 6124'-6144; 6154'-6164; 6190=6200' 190300# of 16/20 carbolite Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 176 208 11 -- 151 Subsequent to operation 1028 ~ 1608 153 - 292 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil^~ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Guy Schwartz Printed Name Guy Schwartz, Title Wells Group Engineer ~^ / Signature ` (/ ~ Phone: 265-6845 Date ~ - /j- ~G~ ,~ ~ , '-• ~ Pre aced b har n Allsu -Dr k 263-4612 Form 10-404 evised 04/2006 ' (~~ Submit 'na 'i • 3H-10 Wefl Summary • DATE Summary ,~ 1/20/08 A3-A5 FRACTURE TREATMENT FLUSH JOB TO COMPLETION, WITH 90 bbls INCLUDING 40 BBLS FREEZE PROTECTION. (LOST POD DENSITY HAD TO PUMP USING GATE %) Pumped a total of 190300# of 16/20 Carbolite 700# left in WB with 10 PPA on formation 1919 BBL of SW, with an average pressure of 3643 psi. 1/22/08 Swapped CT Unit & tractor from Unit 5 to Unit 9. Problems with tractor, delayed most of the day. Rigged upon well and prepare to BOP test in AM. 1/26/08 Arrived on location @ 10:00 after weather delay. Begin pumping through CT for BOP test. Ice plug detected 1.3 bbls away pumping S.D. Micro motion showing 7.2 density and 29 degrees. Begin Thawing CT and try to push neat methanol, pumped .5 bbl started pressuring up. 1/27/08 SLB weekly safety meeting. Once on location, start purging CT with 2 bbl of neat methanol and 38 bbls of 80 degree heated diesel. Ice plug removed, continue with Weekly BOP test. Tested all BOP componets 300 & 4000 psi. 1/28/08 RIH with 1.5" BHA JSN, SB, CV, roll on (7.9') total lenght. Tagged upon GLM, could not pass, POOH install 1.70" JSN same BHA. RIH to 5785' CTMD tagged sand bridge. Started FCO getting better than 1:1 returns entire job using gel/slick diesel. Circ. press 3500 psi, WHP 650 psi @ 1.5 bpm. Frac sand & Gel/oil/gas returns to surface. Continue with FCO down to 6420' CTMD. Hard tag could not make any hole, chase sand while POOH slowly. Good frac sand returns while POOH slowly, freeze protect well, rig down. 1/31/08 ATTEMPTED TO DRIFT THREW PATCH @ 6029' JUMPED PAST TO 6042' RKB , LOST SPANGS HAD OJ'S ATTEMPT TO FREE UP PSI, ABOVE SLOWLY BLEEDING DOWN ,ENDED UP BLOWING TOOLS DOWN HOLE PARTING WIRE EST. 45' WIRE AND 30' TOOLS IN HOLE ,JOB IN PROGRESS 2/1/08 TAGGED PATCH @ 6029' RKB WITH LIB: CLEAN. TAGGED FILL @ 6220' RKB, EST. 20' RATHOLE. PULLED DV, SET OV @ 3291' RKB. COMPLETE. • ~ ,--~ KRU 3H-10B ~c~nc~~c~~-ll~ips Ai~ska, tnc. .. .. 13H-10B - _ _ - - APL 501(1;i200tS702 Weli T e: PROD An le at TS: 27 d ~ 6032 TUBING SSSV Type: NIPPLE Orig 6/19/2004 Angle @ TD: 26 deg @6410 (0-3385, OD:4 500 COm etion: . , iD:3sse) Annular Fluid: Last W/O: Rev Reason: TAG, GLV C/O SURFACE Reference Lo : 24.3' RKB Ref Lo Date: Last U date: 2/2/2008 (o~oza, OD:9 625 Last Ta : 6220' RKB TD: 6410 ftK6 . , wt:4o.o0) Last Tag Date 271/2008 - Max Hole Angle• 28 deg n 6073 ---_ Casing String -ALL STRIN GS . Descn ion I __ Size To Bottom TVD Wt Grade Thread 'RODUCTION (~9. OD:7,000, Wt26.00) NIP (3328-3329, OD:5.630) LINER (3367.5405, OD:4.500, Wt:12.60) LOCATOR (3373-3374, OD:5.750) SEAL (3374.3375, OD:5.250) PACKER (3379-3380, OD:5.970) WINDOW (354as5as, OD:7.000) Perf (6039059) Perf (6069089) Perf (6124-6144) Perf (6154-6164) "`, WINDOW 7.000 3548 3549 3541 0.00 Tnhinn Strinn - TI IRINC; CONDUCTOR 16.000 0 108 108 62.50 H-40 WELDED SURFACE 9.625 0 3024 3023 40.00 L-80 BTCM PRODUCTION 7.000 0 3549 3541 26.00 L-80 BTCM LINER 4.500 3367 6405 6269 12.60 L-80 SLHT Other (plugs, equip., etc.) -LINER DETAiL ', Size To Bottom TVD ViR Grade Thread _ 4.500 0 Perforations Summary _-- _ IntervaY TVD 3385 3382 Zone Status Ft SP 12.60 F Date L-80 T IBT-M Comment 6039- 6059 5943- 5961 C-4 20 6 5127!2004 IPERF 2-7/8" HSD PJ, 60 de h 6069 - 6089 5969 - 5987 C-4,C-3 20 6 5/27/2004 IPERF 2-7/8" HSD PJ, 60 de h 6124 - 6144 6018 - 6036 A-5,A-3 20 6 5/27/2004 IPERF 2-7/8" HSD PJ, 60 de h 6154 - 6164 6045- 6053 A-2 10 6 5/27/2004 IPERF 2-7/8" HSD PJ, 60 de h 6190- 6200 6077- 6086 A-1 10 6 5/26/2004 Gas Lift MandrelsNalves - - - _ St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch IPERF Port 2-7/8" HSD PJ, 60 deg ph _- __ TRO Date Run Vlv Cmnt 1 3291 3290 CAMCO Oilier (plug_s, equp., et De th ND T e KBG-2 OV 1.0 BEK --- c..). - CQMPLETION Descri lion 0.188 0 2/1/200B __ , I ID 23 23 HANGER FMC GEN 5, 4.5" TUBING HANGER 4.500 502 502 NIP CAMCO NO GO'DB' LANDING NIPPLE 3.875 3328 3326 NIP CAMCO NO GO'DB' NIPPLE 3.812 3373 3370 LOCATOR BAKER G-22 LOCATOR SUB 3.938 3374 3371 SEAL BAKER PBR SEAL ASSEMBLY 4.360 3380 3377 SHOE MULE SHOE 4.500 De h TvD T e Descn ion to 3368 3366 TIE BACK TIE BACK SLEEVE 5.250 3379 3376 PACKER ZXP LINER PACKER W/HR PROFILE 4.400 3386 3383 NIP BAKER RS NIPPLE 4.250 3388 3385 HANGER BAKER FLEX-LOCK HYD. ROT. LINER HANGER 4.400 6029 5934 Patch 4.5" TTS LOWER PACKER MID ELEMENT SET @ 6098' 7/3/2007. 1.995 Assembly RUN 8 SET TTS PATCH ASSY IN 2 PART'S, SET PBR, SPACER PIPE 8 ANCHOR LATCH @ 6081' WLM (34' TOTAL LENGTH). SETTTS RETRIEVABLE PKR, SPACER PIPE 8 ANCHOR LATCH (33.8' TOTAL LENGTH). TESTED TOP PACKER TO 2000#; GOOD TEST. NOTE: MIN I.D 1.995" set 7/5/2007 6403 6?_67 SHOE BAKER FLOAT SHOE 3.958 General Notes _. Date Note 5/15/2004 NOTE: WELL SIDETRACKED w/CTD FOR SECOND TIME 1/24/200 NOTE: WAIVERED WELL: IA x OA COMMUNICATION Perf (6190E200) • Maunder, Thomas E (DOA) From: Dethlefs, Jerry C [Jerry.C.Dethlefs@conocophillips.com] Sent: Friday, September 23, 2005 4:41 PM To: Maunder, Thomas E (DOA) Cc: 'NSK Problem Well Supv' Subject: RE: Monobore Injection Wells Tom: To my knowledge you are correct. Since we recently "discovered" 2M-09A, I cannot guarantee there are not other anomalous wells out there we do not know about. But your list looks complete for the wells we do know about. Should we come across another in this situation you will be the first to know. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska ~ ~..; ,.~ _ ~ ; '~ ~~' 907-659-7043 *~"` '~""' `~°~ ° -----Original Message----- From: Thomas Maunder [mailto:tom maunderCadmin.state.ak.us] Sent: Friday, September 23, 2005 9:22 AM To: NSK Problem Well Supv Cc: Jim Regg Subject: Monobore Injection Wells Jerry, et al: We are checking our records and wanted to confirm the wells that are monobores. There are various wells out there that have had the name "monobore" attached to them. For this message, monobore means a well that does not have a separate production casing set proximate to the injection horizon and the packer is set a significant distance above the zone. The first 4 wells on the list have the packers set in the surface casing. The wells on our "list" are: 3K-22 30-19 3Q-21 3R-25 and possibly 2M-09A 3H-lOB would also be ~a3- if®~ converted. on the list, but it is a producer never having been Thanks in advance for your assistance. Tom Maunder, PE AOGCC c~hS~~L~:o rte... ~~~ • • :-~-~, ,g.'~' ~E.. ~ ~~ .`: - ,.~,~' MICROFILMED 03/01!2008 DO NOT P LAC E ANY NEW MATERIAL UNDER THIS PAGE F:1L.aserFichelC~rPgs_InsertslMicrofilm Marker.doc ry ,~;G~ ~~~~m~~i~~r~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ~ ~° ~~,~ %' ~~~.~~'`~ ATTN: Beth pp ~} {~ N0.4550 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk 01/11/08 • Well Job # Log Description Date BL Color CD 1J-164 11964565 INJECTION PROFILE = 01/04108 1 3Q-22 11970623 PRODUCTION PROFILE - J 01/04/08 1 3R-21 11964567 LDL - 01106/08 1 3J-12 11970620 INJECTION PROFILE Z j - ~ 01/01/08 1 3H-108 11964562 PATCH EVALUATION/LDL U2C (~ - ~ 01/01/08 1 1F-01AL1 11994591 FLOWING BHP SURVEY = 3 ~ 12/20107 1 2N-342 11964561 OILPHASE SAMPLER "~- - 12/31107 1 2L-330 11970618 SCMT - ~ 12/30/07 1 2A-20 10194199 RST - ~ 10/30/07 1 1 2X-19 11850441 RST - ~ 07/09107 1 1 • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 12120/07 Schlumberger -DCS ~i _m' 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~~ `.r~~ ~~~''~,~ ,, Well Job # Log Description NO.4532 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 1J-105 11837540 INJECTION PROFILE ~`~'}-(~'.~- 11/20107 1 1A-06 11837542 RST WFL '8'j .-~J~ ; 11/22107 1 10-05 11837537 LDL C - ( 11/17/07 1 1B-12 11970607 INJECTION PROFILE J'T 12/04/07 1 2N-327 11996582 OILPHASE SAMPLER Q~- (a 12/15/07 1 1D-132 11994588 SBHP SURVEY ~'~ - ~ 12/17/07 1 3H-10B 11996580 PATCH EVALUATION 12113107 1 3N-02A 11970609 LDL 'g - 12105107 1 1C-125 11964553 INJECTION PROFILE 12101/07 1 2M-15 NIA PRODUCTION PROFILE ( 12/10/07 1 2M-11 N!A PRODUCTION PROFILE ~~ .- I 12/08/07 1 3A-03B 11970604 SCMT ``-~-- J 12/01107 1 2T-217A 11978431 SCMT - 12/15/07 1 2L-330 11837544 FULLBORE MICRO SCANNER 11/27/07 1 2L-330 11837544 SONIC SCANNER 11/27/07 1 • • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. (L "",,,,,,,,,,,,"""'." 12/19/06 NO. 4077 ß») Company: Alaska Oil & Gas Cons Comm ( - Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk . Date BL Color CD Scblu!lIbepgel' Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ,"'nr;l'!or~ ()"~ c9ti3.- /(00 .--- Well Job# Log Description 1 R-03A (REDO) 11483497 INJECTION PROFILE 11/30/06 1 1 B-09 11483500 INJECTION PROFILE 12/03/06 1 3S-26 11538769 INJECTION PROFILE 12/10/06 1 1 F-04 11538770 INJECTION PROFILE 12/11/06 1 3S-08B 11538771 PRODUCTION PROFILE 12/12/06 1 3H-10B 11534187 PRODUCTION PROFILE 12/08/06 1 1 J-136 11534188 US IT 12/10/06 1 2M-12 11534189 PRODUCTION PROFILE 12/11/06 1 1F-10 11534192 INJECTION PROFILE 12/12/06 1 1 Y -27 N/A PRODUCTION PROFILE 12/14/06 1 22-20 N/A SBHP SURVEY 12/15/06 1 1 H-21 11551832 SBHP SURVEY 12/16/06 1 1 F-05 N/A INJECTION PROFILE 12/13/06 1 1 F-09 11548550 PRODUCTION PROFILE 12/14/06 1 3S-03 11551831 PRODUCTION PROFILE 12/15/06 1 3J-18 11548550 PRODUCTION PROFILE 12/16/06 1 1 H-14 11551835 SBHP SURVEY 12/18/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . ~'-':~ ~::~.: If"> ~\ '\Im 1,\ '" ), \ \ ~i--: \:-......t C".\c ':\ (:1 )iì\'Y,' IJJ,.',;'f .', ' L -' _ U Schlumbepger i-~O!~~~¡\~~ O¡~ à:/II/:'<Ï, ~ :(fJö:i'j~\!H i\n;:;~.fl';¡:-~p:~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 8CANNEID OCT J 1 2úDt Company: ~J I ~d-ð3 -/0ð 10/13/06 Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job# Log Description Date BL 1 J-127 11404957 PROD PROFILE W/DEFT 09/14/06 1 2W-10 11404958 INJECTION PROFILE 09/15/06 1 2W-14 11404960 INJECTION PROFILE 09/17/06 1 2U-01 11404964 PROD PROFILE W/DEFT 09/20/06 1 2A-19A 11415618 PROD PROFILE W/DEFT 09/03/06 1 1 E-04 11421627 INJECTION PROFILE 09/13/06 1 2W-02 11296718 INJECTION PROFILE 09/14/06 1 3H-10B 11296723 PATCH/STATIC SURVEY 09/19/06 1 2T -39 11296724 PROD PROFILE W/DEFT 09/20/06 1 1 L-04 11415626 SBHP SURVEY 09/24/06 1 2V-04 11415628 INJECTION PROFILE 09/26/06 1 1A-17 11415622 PROD PROFILE W/DEFT 09/21/06 1 1 L-06 11415625 SBHP SURVEY 09/24/06 1 1 F-07 11415629 LDL 09/27/06 1 2F-06 11434750 FLOWING BHP SURVEY 10/03/06 1 2A-17 11434751 PROD PROFILE W/DEFT 10/04/06 1 2P-447 11404966 INJECTION PROFILE 10/06/06 1 2V-08A 11216327 USIT 09/21/06 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Color CD ( 1 RE: LoSal P¡:ot Test on 1 H-15 PTD# 193-003.08 PTD # 203-1... . ~03· /bO \~'II--·(- ./1. ) C,. {-,.... LA:: v '.V ,7 / /'" ¡ , . '"eel ' Jim, Perhaps! have confused things with my choice of words. CPAI is not changing the status of either wells from their current producer status. We are pumping a finite, relatively small amount of water and tracer into both wells then sampling the returns for tracer flow back. We hope to determine our oil saturation pre and post 10Sal treatment. The treatment is similar to a large scale inhibitor squeeze in regard to design and execution. This is a short term test, less than 30 days where fluid will be injected into the wells approximately one third of the total test period. Since this is not a pilot injection test but more of a pilot enhanced oil recovery test. It was my understanding that neither a 10-403 nor a 10-404 were required in this situation. Historically CPA! has informed the State when we conduct non standard science projects and requests verba! approval from the state even if a sundry request is not required. The e-mail on 9/21/06 was such a request and was meant to keep the state aware of what we are doing. Perry Klein Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1244 (;. ( -----Original Message----- From: James Regg (mailto:jim_regg@admin.state.ak.us] Sent: Monday, September 25,20065:05 PM To: NSK Problem Well Supv Cc: Thomas Maunder Subject: Re: LoSal Pilot Test on 1H-15 PTD#193-003 3H-10B PTD # 203-160 commence injection What approval are you using to initiate injection into these 2 producing wells? Commission approval is required prior to initiating injection; there is no provision for verbal approval of a pilot injection test as requested in your 9/21/2006 email. Jim Regg AOGCC NSK Problem Well Supv wrote: 10f2 9/26/2006 10:08 AM RE: LOSa,1 Pilot Test on 1 H-15 PTD# 193-0031 08 PTD # 203-1... . ., Gentlemen, Injection on 1H-15 stared at 14:00 09/22/06 Injection started on 3H-108 at 18:00 09/23/06 Sincerely, Perry Klein Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1244 20f2 9/26/2006 10:08 AM IÇ-J~~~ DATA SUBMITTAL COMPLIANCE REPORT 6/19/2006 Permit to Drill 2031600 Well Name/No. KUPARUK RIV UNIT 3H-10B MD /" TVD -' Operator CONOCOPHILLlPS ALASKA INC A~~; ~-10{-~OO~~-~ Y 6410 6274 Completion Date 5/15/2004 -' Completion Status REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: Res/GR/NeuUDens, SCMT Well Log Information: Electr Digital Dataset Med/Frmt Number Log/ Data Type .,..,.-(09 ~t ~g iog ,/Log (" Log/ rRþt Log Log Run Scale Media No Blu 1 25 Blu 3 25 Blu 3 25 Blu 3 25 Blu 3 Name Perforation ^ 7 V'1~ '~<.{ Directional Survey Induction/Resistivity Induction/Resistivity Neutron Neutron LIS Verification ~nduction/Resistivity .-éÐ C Lis Log r~ Cement Evaluation Blu .,./' Log Reservoir Saturation 5 Blu -' Log Production 5 Blu Well Cores/Samples Information: Name Interval Start Stop Received Sent WAGIN ~ Current Status 1-01L Directional Survey ~ (data taken from Logs Portion of Master Well Data Maint . Interval OH/ Start Stop CH Received Comments 3240 6194 7/1/2004 PERFORATION W/SBHP 6/17/2004 3549 6367 Open 7/15/2004 ORD, CCN, DSN 12568 3549 6367 Open 7/15/2004 ORD, CCN, DSN 12568 3568 6367 Open 5/13/2004 MPR, DSN 12568 3549 6367 Open 5/13/2004 MPR, DSN 12568 0 0 7/15/2004 DSN 12568 3549 6410 7/15/2004 CCN, ORD, MPR, GRAPHICS, INTEQ META IMAGE FILES 3216 6202 7/1/2004 SCMT CEMENT BOND LOG SCMT-CB/PBMS-A . 3180 6172 9/22/2004 RST-SIGMA MODE/RST- C/PBMS-A 5900 6100 2/5/2005 production profile/psp: press/temp/g rad i o/spins/deft Sample Set Number Comments Permit to Drill 2031600 MD 6410 TVD 6274 ADDITIONAL INFOR~C.. TION Well Cored? 't\l!V Chips Received? ~ Y / N Analysis Received? ~. Comments: Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 6/19/2006 Well Name/No. KUPARUK RIV UNIT 3H-10B Operator CONOCOPHILLlPS ALASKA INC Completion Date 5/15/2004 Completion Status WAGIN Daily History Received? Formation Tops ; ~ API No. 50-103-20087-02-00 Current Status 1-01L UIC Y /~ {)/N Date: /1 JWrvL ~~ . . Schlumberger Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth . Well Job # 'ß1-25 J{-- 35-15 1'3)- No 1G-13 }o.,., ¡GO 3H-10B {;(v~ 1L-24 19/.- ()'-;O 1A-01 /;)1' ')liI 1L-12 /9tJ'Ot.fí 1C-125 :?Wr- /11 10922486 10922529 10942827 10942834 10922530 10922532 10942833 . NO. 3329 (":;¿C) ..? -~ í he 02/04/05 Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Log Description Field: Date BL 11/06104 1 01/28/05 1 01/17/05 1 01/26/05 1 01/29/05 1 01/31/05 1 01/25/05 1 Kuparuk Color CD INJECTION TEST RST WFL PRODUCTION PROFILEIDEFT RST WFL RST WFL LEAK DETECTION INJECTION PROFILE ----- /1' l jll / ~ . SIG~ ~ / ~ /' (¿b~~ DATE: ,/)t;,j:¡{;S- :' I / Please sign and return ~¿ copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Schlumberger Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth . Well Job# 2 OJ - '" 0 3H-1 OB "0(-2.0'1 1F-16A j'Q IZ-'t 2M-21 t~; -( '1'1 -3C-13 [12- -ðf'I 2M-20 2F-07 /1'1-- ~ 2E-11 li~4"fD5"2G-09 'I'l. -lrC, 1 F-07 ¡'8't-f)1/ 2B-10 I 'j( ;/<':> if 1A-05 Itl..{5:. 1A-09 ¡8'1-1Stf 1Q-04 f 'ì3 """ 1 H-01 10802919 10884016 10884017 10884018 10884009 10884005 10884007 10884008 10884001 1 0884004 10884013 10884015 10802926 10802921 . Log Description Date DATE: 09/17/04 NO. 3209 Company: Alaska Oil & Gas Cons Comm A(tf'1': ~tJh, O~a30FI ' 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk BL Color CD RST-SIGMA SBHP SURVEY PRODUCTION PROFILE PRODUCTION PROFILE PRODUCTION PROFILE PRODUCTION PROFILE PRODUCTION PROFILE PRODUCTION PROFILE PRODUCTION PROFILE INJECTION PROFILE SBHP SURVEY SBHP SURVEY PIEZO SONA TOOL PIEZO SONA TOOL 08/12/04 09/06/04 09/07/04 09/07104 09/02/04 08/29/04 08/31/04 09/01/04 08/27/04 08/28/04 09/05/04 09/05/04 08/19/04 08/15/04 1 1 1 1 1 1 1 1 1 1 1 1 1 1 (0 - /0 -- é)t/ Please sign and retur one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ./;~ e fi CJ'3_ ~.f~o ! 2~ tv!J tiIC ,,¡_ BAKER HUGHES Transmittal Form INTEQ Anchorage GEOScience Center To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Robin Deason Reference: 3H-I0B Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 blueline - MPR Measured Depth Log 1 blue line - MPR TVD Log Iblueline ~ CCN/ORDMeasured Depth Log Iblueline - CCN/ORD TVD Log LAC Job#: 680721 Sent By: Glen H'1el { Received BYUAvdw-j ¿~ (J V PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 Date: July 12, 2004 Date: 7/~cJo ct Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 !, . I' [::j IR!.TPkII-:IHMm.tIrnIJ r) I'·,. " '~'------¡'¡:;;¡¡;;~i~i\>:;'¡¡;"'~m,_m'--~__'M] 'WJ-"'" : :r""----~'-------g,;-----~-'----'?"tt--i ~~~«,::,;,,'-'~~ ;F-~-"·--";'jf·_·'"··-·--;~""---:~·---?~~--¡ :=~~,--~~::~'-:;~---~. .._~~j , . --;-: 1(i!5":¡¡;';;~;:''';'_ _ "'" .. _:ori . "'..,. .. ;;,:,-,-;'.;;' - .----.~-.. ~-- --, -":-'-;;;;-1 ~~~".~~~~~~1__~ -j~~",~~ ~'i ~-~~ i l_,__.':';:.".::.,_: : f-----~::__3 i e . STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 67' 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: 5. Permit to Drill Number: 203-160 I 6. API Number: 50-103-20087-02 9. Well Name and Number: 3H-10B 10. FieldlPool(s): Kuparuk Oil Pool Total Depth measured 6410' feet true vertical 6274' feet Effective Depth measured 6309 feet true vertical 6183 feet Casing Length Size MD Structural CONDUCTOR 80' 16" 108' SURFACE 4499' 9-5/8" 4527' WINDOW 1 ' 7-5/8" 3549' PRODUCTION 3523' 7" 3549' LINER 3038' 4-1/2" 6405' Perforation depth: Measured depth: 6039-6200 true vertical depth: 5943-6085 Plugs (measured) Junk (measured) TVD Burst Collapse 108' 4489' 3541' 3541' Tubing (size, grade, and measured depth) 4-1/2" . L-80, 3385' MD. Packers & SSSV (type & measured depth) ZXP Liner PkrwlHR profile PKR = 3379' SSSV= NIP SSSV= 502' Form 10-404 Revised 2/2003 . ~~~l jUl 0 8 7001\ SUBMIT IN DUPLICATE e 3H-10B e DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 06/19/041 Began pre-producing 3H-1 DB injector FW: Request to pre-produce injector 3H-10B (PTD 203-160) e e Subject: FW: Request to pre-produce injector 3H-lOB (PTD 203-160) From: NSK Problem Well Supv <nI617@conocophillips.com> Date: Mon, 07 lun 2004 14:32:10 -0800 To: "Tom Maunder AOGCC (E-mail)..<tom_maunder@admin.state.ak.us> Tom: See message below about the timing for the report. I hope that sound OK to you. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907 -659-7224 -----Original Message----- From: NSK Prod Engr Tech Sent: Monday, June 07, 2004 1:37 PM To: NSK Problem Well Supv Subject: RE: Request to pre-produce injector 3H-10B (PTD 203-160) Jerry, 3H-108 was t via temporary tanks June 1- 3. Test rates: 400 bopd, 280 mcfd, 600 bwpd. We are in the proc / ~ing 3H-108 to well 3H-16. Pipe installation is expected to take about 3 weeks. I entere June 27th ,S the estimated sustained production commencement date on the 10-403. I sent the 10-403 ut yesterd y. Please pass this on to Tom so he can correct the 10-403 if he chooses to do so. -Bob -----Original Message----- From: NSK Problem Well Supv Sent: Monday, June 07, 20047:35 AM To: NSK Prod Engr Tech Subject: FW: Request to pre-produce injector 3H-10B (PTD 203-160) What do you think? -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Monday, June 07, 20046:46 AM To: NSK Problem Well Supv Subject: Re: Request to pre-produce injector 3H-10B (PTD 203-160) Nice to know have a new producer. On the 403, will the effective date be when first produced?? Since all the well has done is produce, that would seem appropriate. Tom NSK Problem Well Supv wrote: Tom: Apparently the test results have been good on pre-producing 3H-10B, and a decision has been made to keep it on production for an extended period. A 10-403 regarding the service change is being prepared and should be in your office shortly. Thanks for the temporary approval up to this point. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7224 -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] -:' 10f2 6/8/2004 1 :46 PM FW: Request to pre-produce injector 3H-lOB (PTD 203-160) e . Sent: Wednesday, May 26, 2004 11:12 AM To: NSK Problem Well Supv Subject: Re: Request to pre-produce injector 3H-10B (PTD 203-160) Marie, Sorry about the delay in getting back to you on this. You are correct with regard to the notice on "short" production periods. You have approval to pre-produce the well. If it goes over 30 days, let me know and we can handle any paperwork then. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote: Tom, Approval to pre-produce 3H-10B (PTD 203-160) for up to 3 weeks prior to injection is requested. I assume this is similar to the injector flowbacks we've done in the last few years where an email request for temporary conversion was adequate for periods less than 1 month. If the pre-production period is extended based on welltest results, we will file the 10-403 and 10-404 paperwork. Please let me know if you have any questions. Thank you, Marie McConnell Problem Well Supervisor 659-7224 20f2 6/8/2004 1 :46 PM 4 e . RFC·E· f/E.·1r,\ Á STATE OF ALASKA . c .",..J,,_ ~ \ :, l.t-., Cplc{ ALASKA OIL AND GAS CONSERVATION COMMISSION -../ ~ APPLICATION FOR SUNDRY APPROVAL JUN 0 82004 ~ Alaska Oil & ~ 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB67' 203-160 6. API Number: 50-103-20087-02 9. Well Name and Number: 3H-10B 10. FieldlPool(s): Kuparuk Oil Pool PRESENT WELL CONDITION SUMMARY TVD Plugs (measured): Junk (measured): 11. Total depth MD (ft): Total Depth TVD (ft): Effective 6410' 6274' Casing Length Size CONDUCTOR 80' 16" SURFACE 4499' 9-5/8" WINDOW 1 ' 7-5/8" PRODUCTION 3523' 7" LINER 3038' 4-112" MD 108' 4527' 3549' 3549' 6405' TVD Burst Collapse Perforation Perforation Depth TVD Tubing Size: 4-112" Tubing Grade: L-80 Tubing MD (ft): 3385' Packers and SSSV Type: ZXP Liner Pkr wlHR profile SSSV= NIP Packers and SSSV MD (ft) PKR = 3379' SSSV= 502' Commission Use Only Conditions of approval: Notify Commission so that a representative may witness ¡Sundry Number: ~ .3 C;J..j.- ¿;;-;).O Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: RmMS aft 'JUN 0 9 'on~ BY ORDER OF COMMISSIONER THE COMMISSION Date Þjl6lf SUBMIT IN DUPLICATE Form 10-403 Revised 2/2003 . OR1GINAL · 3H-10B DESCRIPTION SUMMARY OF PROPOSAL e ~ ConocoPhillips Alaska Inc. requests approval to pre-produce sidetracked injection well 3H- 10B for an extended period. This well was completed on May 15, 2004 for WAG injection service. The Rig performed Tubing and MITIA pressure tests to 3500 psi on 05/15/04. The well was then produced for a short period with significant oil production. The well will be operated as a gaslifted oil producer until December 15, 2004 or until the watercut reaches 100%. ~ ConocoPhUlips TUBING (23-3385, 00:4,500, 10:3.958) SURFACE ~ (28-4527, 00:9,625, Wt:40.00) 'ROOUCTION (26-3549, 00:7,000, Wt:26,00) NIP (3328-3329, OD:5,630) LINER (3367-6405, 00:4,500, Wt:12,60) LOCATOR (3373-3374, 00:5,750) SEAL (3374-3375. 00:5,250) PACKER (3379-3380, 00:5,970) WINDOW (3548-3549, 00:9,615) Perf (6039-6059) Perf (6069-6089) Perf (6124-6144) Perf (6154-6164) Perf (6190-6200) -""" il II A 110... 3H-10B API: 501032008702 SSSV Type: NIPPLE Annular Fluid: Reference Log: 24,3' RKB LastTag: 6200 Last Description PRODUCTION SURFACE CONDUCTOR LINER WINDOW Tubing String - TUBiNG Size I Top 4.500 23 Perforations Summary Interval TVD 6039 - 6059 6039 - 6059 6069 - 6089 6069 - 6089 6124 - 6144 6124 - 6144 6154 - 6164 6154 - 6164 6190 - 6200 6190 - 6200 KRU Well Type: SVC Orig Completion: Last W/O: 3H..108 Angle @ TS: deg @ Angle @ TD: deg @ 6410 Ref Log Date: TD: 6405 ftKB Max Hole Angle: 0 deg @ Rev Reason: Set DMY, PERF, Drift & Tag Last Update: 5/28/2004 Size 7.000 9.625 16.000 4.500 9.615 TVD 3549 4527 108 6405 3549 Wt 26.00 40,00 62,50 12.60 0.00 Top 26 28 28 3367 3548 Bottom 3549 4527 108 6405 3549 Bottom TVD 1 Wt I Grade 3385 3385 1 12,60 L-80 Zone Status Ft 5PF Date Type 20 6 5/27/2004 IPERF 20 6 5/27/2004 IPERF 20 6 5/27/2004 IPERF 10 6 5/27/2004 IPERF 10 6 5/26/2004 IPERF Gas lift MandrelsNalves 5t I MD I TVD I Man I Man Type I 1 32911 3291 CA~~O KBG-2 Other (plUgs, equip., etc.) - JEWELRY Depth TVD Type Description 23 23 HANGER FMC GEN 5, 4,5" TUBING HANGER 502 502 NIP CAMCO NO GO 'DB' LANDING NIPPLE 3328 3328 NIP CAMCO NO GO 'DB' NIPPLE 3373 3373 LOCATOR BAKER G-22 LOCATOR SUB 3374 3374 SEAL BAKER PBR SEAL ASSEMBLY 3380 3380 SHOE MULE SHOE Other (plugs, equip., etc.) - LINER JEWELRY Depth TVD Type 3368 3368 TIE BACK 3379 3379 PACKER 3386 3386 NIP 3388 3388 HANGER 6403 6403 SHOE General Notes Date Note 5/15/2004 TREE: FMC / GEN 4/5M TREE CAP CONNECTION: Top 5.75" ACME W/4,5" EUE8rd THREAD INSIDE 5/15/2004 WELL SIDETRACKED Grade L-80 L-80 H-40 L-80 Thread BTCM BTCM WELDED SLHT Thread IBT-M Comment 2-7/8" HSD PJ, 60 deg phase 2-7/8" HSD PJ, 60 deg phase 2-7/8" HSD PJ, 60 deg phase 2-7/8" HSD PJ, 60 deg phase 2-7/8" HSD PJ, 60 deg phase V Mfr I V Type V OD I Latch I Port I TRO I ~~~ I C~~t DMY 1.0 BEK I 0.000 0 5/22/2004 Description TIE BACK SLEEVE ZXP LINER PACKER W/HR PROFILE BAKER RS NIPPLE BAKER FLEX-LOCK HYD, ROT. LINER HANGER BAKER FLOAT SHOE ID 4,500 3.875 3.812 3.938 4,360 4,500 ID 5.250 4.400 4,250 4.400 3.958 e e Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells ConocJPhillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 June 7, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ¡th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for 3H-1 08 (APD # 203-160) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations of the Kuparuk well 3H-1 08. If you have any questions regarding this matter, please contact me at 265-6830 or Philip Hayden at 265-6481. l Sincerely, ~~~ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT /skad RECEIVED JUN 072004 AlasKa OJ! & Con$. Commission Anchorage .. STATE OF ALASKA . RECEIVED AlA5rÁ Oil AND GAS CONSERVATION COMMISSION . ..... ",' ... ... .. ...... WELL COMPLETION OR RECOMPLETION REPORT AN ÐJIl0G2004. Oil 0 Gas U 1a. Well Status: GINJ 0 2. Operator Name: o WDSPL 0 WINJ Plugged 0 Abandoned U 20AAC 25,105 No, of Completions _ ConocoPhillips Alaska, Inc. 3, Address: P. O. Box 100360, Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 1320' FNL, 4997' FEL, Sec. 12, T12N, R8E, UM At Top Productive Horizon: 941' FNL, 896' FWL, Sec. 12, T12N, R8E, UM Total Depth: 836' FNL, 4250' FEL, Sec. 12, T12N, R8E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 498655 ./ y- TPI: x- 499270 y- Total Depth: x- 499404 y- 18. Directional Survey: Yes 0 NoU 21, Logs Run: Res/GRI NeuUDens, SCMT 22, CASING SIZE 16" 9.625" WT. PER FT. 62.5# 40# 15.5# 12.6# GRADE H-40 L-80 L-80 L-80 7" 4.5" I 6000335 6000716 6000821 Zone- 4 Zone-4 Zone-4 Suspended 0 20AAC 25,110 WAG 0 Other 5, Date Comp" Susp" or Aband,: May 15, 2004 6. Date Spudded: May 10, 2004 7, Date TD Reached: ,¡ May 12, 2004 8. KB Elevation (It): .I 28' RKB / 67' AMSL 9, Plug Back Depth (MD + TVD): 6309' MD /6183' TVD 10, Total Depth (MD + TVD): ¡ 6410' MD /6274' TVD 11. Depth where SSSV set: Landing Nipple @ 502' 19, Water Depth, if Offshore: N/A CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD TOP BOTTOM TOP BOTTOM Surface 108' Surface 108' Surface 3024' Surface 3023' Surface 6264' Surface 5902' 3368' 6405' 3365' 6269' 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 6039'-6059' MD 6069'-6089' MD 6124'-6144' MD 6154'-6164' MD 6190'-6200' MD 5943'- 5960' TVD 5969'-5987' TVD 6018'-6036' TVD 6045'-6054' TVD 6077'-6086' TVD 26, Date First Injection Date of Test Hours Tested Flow Tubing Casing Pressure press, 27, psi 6spf 6spf 6spf 6 spf 6 spf 24-Hour Rate -> 24, SIZE 4.5" if feet MSL HOLE SIZE 24" 12.25" 8.5" 6.125" 1b, Well Clas~. ~ r, r!1. ., f, l:Fd~¡ ¡1~ ,'~¡;t~ om,,,rll<'!m1r Devë1opment'· U "t:xplð orý' ".,,,r:.:~' í7I Î' "" "cO" :;w Pc_ 0 Service ~ ,{¡.,:.t"'ê!rätigraphic Test 12, Permit to Drill Number: 203-160 13, API Number: 50-103-20087-02 14, Well Name and Number. 3H-10B 15, Field/Pool(s): Kuparuk River Field Kuparuk Oil Pool 16. Property Designation: ADL 25531 17, Land Use Permit: ALK 2657 20. Thickness of Permafrost: 1591' MD CEMENTING RECORD AMOUNT PULLED Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary), Submit core chips; if none. state "none", Form 1 0-407 Revised 12/2003 NONE 225 sx AS I 1300 sx AS III, 100 sx AS I, 300 sx Class G 450 sx Class G. 200 sx AS I 115 sx LiteCrete, 110 sx Class G TUBING RECORD DEPTH SET (MD) 3380' PACKER SET 3379' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC, DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a WATER-BBL GAS-MCF WATER-BBL PRODUCTION TEST Method of Operation (Flowing, gas lilt, etc,) Pre-Produced Injector Production for OIL-BBL GAS-MCF Test Period --> Calculated OIL-BBL CORE DATA ORrG1r!ÄL CHOKE SIZE rAS-OIL RATIO OIL GRAVITY - API (corr) "I'~'" , .E, 'rÇ~ bý' ~~d~ / C.,'I JM 1,4 'iII' ~S6fL GEOLOGIC MARKERS e 29, e 28. FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary, If no tests were conducted, state "None". 3H-10B Top Upper Kalubik Top Lower Kalubik Top C4 Top C3 5811' 5946' 6034' 6082' 5735' 5859' 5938' 5981' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, Schematic 31, I hereby certify that the foregoing is true and correct to the best of my knowledge, RECEn/ED JUN 072004 Alaska Oil & . . . CommisSIOn Anchorage Contact: Kelly McLure @ 265-6059 Printed Na~ .. Randv Thomas Signature \. ~~ Title: P~"'ne Kuparuk Drillinq Team Leader ?<;; <;- {,.-'6 ~o Date 6 (? fo7 Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. 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 elevation in feet abour mean low low water. 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: True vertical thickness. 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, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 1 0-407 Revised 2/2003 OR\G\NAL Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3H-10 3H-10 ROT - SIDETRACK Doyon Drilling Inc Doyon 141 Start: 5/6/2004 Rig Release: 5/15/2004 Rig Number: Spud Date: 11/30/1987 End: 5/15/2004 Group: 5/6/2004 08:30 - 12:00 3.50 MOVE DMOB DEMOB Unhooked service lines and blow down rig, moved rig complex's from sub and moved sub base off well, staged complex's on pad 12:00 - 15:00 3.00 MOVE MOB DEMOB Moved sub base and rig complex's 15 miles from 3S pad to 3H pad, spotted sub base over well 3H-1 OB 15:00 - 17:00 2.00 MOVE MOB DEMOB Moved camp, truck shop and sewer plant from 3S pad to 3H pad 17:00 - 18:30 1.50 MOVE RURD DEMOB Spot and RU camp, sewer plant and truck shop 18:30 - 21 :00 2.50 MOVE POSN DEMOB Spotted rig's complex's, rock washer and pipe shed 21 :00 - 23:00 2.00 MOVE RURD DEMOB Hooked up service loops and lines between complex's, got steam and water going on rig and completed rig acceptance check list, held pre-spud mtg with crew coming off tour Accepted Rig @ 23:00 hrs 5/6/2004 23:00 - 23:15 0.25 WELCTL SFTY DECOMP Held PJSM with rig crew on checking well pressures, ND tree and NU BOP's 23:15 - 00:00 0.75 WELCTLNUND DECOMP Removed VR plug from lA, checked well pressures, IA -0-, OA -0-, tbg has BPV installed, ND FMC, model 75, 3 1/8', 5M tree 5/7/2004 00:00 - 01 :30 1.50 WELCTL NUND DECOMP Fin ND Tree and installing blanking plug in tbg hanger 01 :30 - 03:00 1.50 WELCTL OTHR DECOMP PU & RU BOP testing equipment and valves 03:00 - 06:00 3.00 WELCTL BOPE DECOMP Tested choke manifold to 250 psi low and 5,000 psi high, prep 11" x 7 1/16' DSA NOTE: Chuck Scheve with AOGCC waived witnessing of BOP test 06:00 - 08:00 2.00 WELCTL NUND DECOMP NU 11' x 71/16" DSA, set on BOP stack & NU 08:00 - 12:30 4.50 WELCTL BOPE DECOMP Tested rams and valves to 250 psi low and 5,000 psi high, tested annular to 250 and 3,500 psi, tested rams and annular with 3 1/2' test jt, RD test tools 12:30 - 15:00 2.50 WELCTL EQRP DECOMP Retrieved blanking plug, Took several attempts before retrieve blanking plug, LD same, attempted to pull BPV with no sucess 15:00 - 16:30 1.50 DRILL PULD DECOMP MU 3 1/2' landing jt and MU into hanger, PU 90K and hanger and tbg came free, LD landing jt and found several pieces of metal around BPV, removed BPV and LD hanger, tbg st wt 85K Note 31/2" Tbg was cut at 6,112' WL 16:30 - 17:30 1.00 DRILL CIRC DECOMP Circ hole with clean seawater, recovered 100 bbls of diesel used for freeze protection, circ hole at 7 bpm at 800 psi 17:30 - 21 :00 3.50 DRILL PULD DECOMP POOH LD 3 1/2" 9.3#, J-55, BTC tbg, POOH LD 57 jts tbg, control line and 33 clamps, POOH to SSSV and LD same (Total length LD 1,774.09'), cleared rig floor 21 :00 - 21 :45 0.75 WELCTL TRIP DECOMP MU Baker 7' storm packer and valve, RIH and set at 96', POOH with setting tool 21 :45 - 22:00 0.25 WELCTL OTHR DECOMP Pressure tested packer to 1,000 psi for 5 min & ck ok 22:00 - 00:00 2.00 WELCTL NUND DECOMP ND BOP stack and set off, ND 135/8" 3M x 71/16" 5M Tbg head, with several bolts in head while loosening slowly, csg began moving up with tbg head at report time Note: Held pre-spud meeting with new crew coming on tour 5/8/2004 00:00-01:15 1.25 WELCTL NUND DECOMP Fin ND Tbg head, allowed csg and tbg head to move up, csg stopped after moving up hole 4 3/4", removed tbg head and pack-off, loaded pipe shed with 4" HWDP & 4 3/4" DC's 01:15 - 03:15 2.00 WELCTL NUND DECOMP MU Baker 7" csg spear, stung into csg, PU 69K (34K over blk wt) and removed csg slips, installed new slips and set with 34K st wt, installed new pack-off and LD 7' csg spear 03:15 - 04:45 1.50 WELCTL NUND DECOMP NU re-conditioned 135/8" 3M x 71/16" 5M tbg head and tested pack-off to 3,000 psi, good test 04:45 - 06:15 1.50 WELCTL NUND DECOMP NU BOP stack and riser 06:15 - 08:45 2.50 WELCTL BOPE DECOMP RU and tested 4" rams to 250 psi low and 5,000 psi high, annular to Printed: 5/25/2004 9:34:47 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3H-10 3H-10 ROT - SIDETRACK Doyon Drilling Inc Doyon 141 Start: 5/6/2004 Rig Release: 5/15/2004 Rig Number: Spud Date: 11/30/1987 End: 5/15/2004 Group: 5/8/2004 06:15 - 08:45 2.50 WELCTL BOPE DECOMP 250 and 3,500 psi, RD, cleared rig floor 08:45 - 09:45 1.00 WELCTL TRIP DECOMP RIH to 96' with 7" storm packer retrieving tool and latched onto pkr, released same and POOH LD packer 09:45 - 15:00 5.25 DRILL TRIP DECOMP Fin POOH with 31/2" completion, LD 139 jts of 31/2" 9.3#, L-80 BTC tbg, and 7-GLM's, total recovered from well, 196 jts tbg, 7-glm's, 1 SSSV, control line and 33 clamps 15:00 - 16:30 1.50 DRILL RIRD DECOMP RD 31/2" handling tools, cleared rig floor and installed wear bushing 16:30 - 16:45 0.25 DRILL PULD DECOMP MU cleanout BHA #1, 6 1/8" bit, scraper and upper whipstock mill, XO 16:45 - 20:00 3.25 DRILL TRIP DECOMP TIH with BHA #1 PU 29 jts, 4" HWDP, jars and 91 jts of 4" XT-39 Dp, TIH to 3,752', no problems st wt 93K up & dn 20:00 - 20:30 0.50 DRILL CIRC DECOMP Circ 1 complete hole volume with clean seawater, circ at 8 bpm at 800 psi 20:30 - 21 :45 1.25 DRILL TRIP DECOMP Monitored well-static, POOH LD bit, scraper and mill 21 :45 . 22:00 0.25 LOG SFTY DECOMP Held PJSM with rig crew and Schlumberger wireline on operations 22:00 - 00:00 2.00 LOG ELOG DECOMP RU SWS, MU 6" gauge ring / junk basket with CCL, RIH to 3,700' with no problems, logged up from 3,700' to 3,000' for CCL to set CIBP for whipstock, POOH with 6" gauge ring / junk basket and LD, preparing to run 7" CIBP 5/9/2004 00:00 - 01 :30 1.50 LOG ELOG DECOMP MU Baker 7" CIBP, RIH on wireline and set at 3,555', POOH, RD SWS 01 :30 - 01 :45 0.25 DRILL DEQT DECOMP Tested 7" csg and CIBP to 3,000 psi for 10 min, good test 01:45 - 04:15 2.50 WINDOWPULD DECOMP MU & RIH with BHA #2, Baker 7" btm trip whipstock and milling assembly with MWD and oriented same, 4-43/4" dc's, RIH with 9 stds 4" HWDP and 1 std 4" DP to 1,145' 04:15 - 04:30 0.25 WINDOWCIRC DECOMP Shallow tested MWD and checked ok 04:30 - 05:45 1.25 WINDOWTRIP DECOMP TIH with whipstock on 4" DP to 3,489' 05:45 - 06:30 0.75 WINDOWSETW DECOMP Est circ at 295 gpm, 1,200 psi and worked DP down orienting whipstock to 28 deg left of high side from 3,489', tagged CIBP at 3,555" DP (3,555' WL), set whipstock and sheared off same, top of whipstock at 3,537', st up wt 90K, dn 94K with seawater 06:30 - 06:45 0.25 WINDOWCIRC DECOMP Displaced out seawater in well over to 10.2 ppg LSND mud, rot wt 91 K, up wt 90K, dn wt 94K 06:45 - 11 :45 5.00 WINDOWSCML DECOMP Milled window in 7" csg from 3,537' to 3,568' MD/3,559' TVD, top of window at 3,537' MD/ 3,529' TVD, btm of window at 3,549' (12' window, .. 19' of open hole), 2-14K wom, initial rpm's 70, final rpm's 125, torque '2,\\- \'CJ \) ave 3K ft-Ibs, max torque 7K ft-Ibs, circ rate 300 gpm at 1,300 psi 11 :45 - 13:00 1.25 WINDOWCIRC DECOMP Pumped hi vis fiber sweep and CÎrc hole clean, worked mills thru window while eire, circ at 300 gpm at 1,200 psi, after circ clean, worked ~~ mills thru window with no pump or rotation several times with no problems, had good recovery from sweep and magnets while milling window, PU to above top of window 13:00 - 14:00 1.00 DRILL LOT DECOMP RU & performed FIT to 13.6 ppg EMW with 10.2 ppg MW, 627 psi at 3,529' TVD 14:00 - 16:00 2.00 WINDOWTRIP DECOMP POOH with milling assembly BHA #2 to 228', stood back HWDP 16:00 - 17:00 1.00 WINDOWPULD DECOMP POOH LD 4 3/4" Dc's, MWD and whipstock mills, upper mill in gauge 17:00 -18:00 1.00 WINDOWOTHR DECOMP Pulled wear bushing and flushed out stack, re-installed wear bushing and cleared rig floor 18:00 - 19:45 1.75 DRILL PULD PROD PU & Began MU 6 1/8" directional BHA #3, oriented and uploaded MWD 19:45 - 20:00 0.25 DRILL SFTY PROD Held PJSM with crew on loading radioactive sources 20:00 - 20:30 0.50 DRILL TRIP PROD Fin MU BHA #3, loaded radioactive sources and RIH with HWDP to 1,104', shallow tested MWD and ck ok 20:30 - 23:30 3.00 DRILL TRIP PROD TIH with BHA #3 PU singles of 4" XT-39 DP from pipe shed, TIH to 3,534' (above window at 3,537') Printed: 5/25/2004 9:34:47 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3H-10 3H-10 ROT - SIDETRACK Doyon Drilling Inc Doyon 141 Start: 5/6/2004 Rig Release: 5/15/2004 Rig Number: Spud Date: 11/30/1987 End: 5/15/2004 Group: 5/9/2004 23:30 - 00:00 0.50 RIGMNT RSRV PROD Began to slip & cut drlg line 5/10/2004 00:00 - 01 :00 1.00 RIGMNT RSRV PROD Fin slip & cut 88' of drlg line and serviced top drive 01 :00 - 02:30 1.50 DRILL CIRC PROD Attempted to orient MWD to go thru 7" window at 3,537', was unable to get a pulse, troubleshoot at surface and slowed transmittion rate with no success 02:30 - 05:15 2.75 DRILL TRIP PROD Monitored well-static, pumped dry job, POOH to 65' standing back HWDP and flex DC's 05:15 - 05:45 0.50 DRILL PULD PROD Removed radioactive sources, PU & drained motor and checked bit, ck ok, LD MWD pulser 05:45 - 07:30 1.75 DRILL PULD PROD Changed out MWD pulser, oriented and uploaded MWD, loaded radioactive sources and pulse tested MWD & ck ok 07:30 - 08:45 1.25 DRILL TRIP PROD TIH with BHA #4 to 1,104', TIH with flex DC's and HWDP, surface tested MW D & ck ok 08:45 - 09:30 0.75 DRILL TRIP PROD TI H with BHA #4 to 3,441' to above top of window at 3,537', tested MWD @ 2,319' & ck ok 09:30 - 10:00 0.50 DRILL CIRC PROD Oriented above window, went thru window with no pump or problems, washed to btm from 3,555' to 3,568' 10:00 - 12:45 2.75 DRILL DRLG PROD Drilled 6 1/8" hole from 3,568' to 3,718', ART 1.45 hrs, AST .6 hrs y 12:45 - 14:00 1.25 DRILL CIRC PROD Circ hole clean and performed PWD baseline with 10.2 ppg mud, clean hole ECD = 11.28 ppg at 280 gpm and 100 rpm's 14:00 - 00:00 10.00 DRILL DRLG PROD Drill, slide and survey 61/8" hole per directional plan from 3,718' to 4,279' MD/ 4,245' TVD (561 ') ART 7.15 hrs, AST 1.5 hrs, 5-15K wob, 100 rpm's, 67 spm, 275 gpm, off btm pressure 1,750 psi, on btm 2,000 psi, ave ECD 12.5 ppg, max ECD 13.0 ppg, control drlg to control ECD's below 13.0 ppg, rot wt 105K, up wt 108K, dn wt 99K, ave BGG 40 units Pumped 1 hi vis sweep and had a 30% increase in cuttings back, lost MWD signal for 10 min after pumping sweep and then signal came back up 5/11/2004 00:00 - 12:00 12.00 DRILL DRLG PROD Drill 6 1/8" hole per directional plan from 4,279' to 4,933' MD/4,886' TVD (654') ART 7.7 hrs, AST 1.2 hrs, 10-20K wob, 100 rpm's, 67 spm, 283 gpm, off btm pressure 1,900 psi, ave ECD 12.7 ppg, max ECD 13.0 ppg, control drlg to control ECD's below 13.0 ppg, rot wt 105K, up wt 108K, dn wt 100K, ave BGG 40 units, Mud weight 10.2 ppg. 12:00 - 00:00 12.00 DRILL DRLG PROD Drill 6 1/8" hole per directional plan from 4,933' to 5,615' MD/5,549' TVD (682') ART 6.7 hrs, AST 2.8 hrs, 5-12K wob, 100 rpm's, 67 spm, 283 gpm, off btm pressure 1,900 psi, ave ECD 12.8 ppg, max ECD 13.1 ppg, control drlg to control ECD's below 13.0 ppg, rot wt 130K, up wt 117K, dn wt 112K, ave BGG 40 units, Raise mud weight f/1 0.2 to 10.8 ppg as per schedule. 5/12/2004 00:00 - 04:45 4.75 DRILL DRLG PROD Drill 6 1/8" hole per directional plan from 5,615' to 5,831' MD (216') ART 3.0 hrs, AST 1.0 hrs, 5-15K wob, 100 rpm's, 58 spm, 245 gpm, On btm pressure 2000 psi, ave ECD 12.8 ppg, max ECD 13.1 ppg, control drlg to control ECD's below 13.0 ppg, rot wt 130K, up wt 117K, dn wt 112K, ave BGG 150 units, Max gas 500 units, Raise mud weight f/1 0.8 to 11.3 ppg as per schedule. 04:45 - 06:15 1.50 DRILL CIRC PROD Circ btm's up, Pump Hi-vis sweep, Circ hole clean and minimize ECD's to 12.4 to 12.6 ppg prior to drilling ahead- No mud lost, Gas circ down to below 100 units. 06:15 - 23:00 16.75 DRILL DRLG PROD Drill 6 1/8" hole per directional plan from 5,831' to 6,410' MD/6,274' ¡/ TVD (579') ART 11.9 hrs, AST 1.2 hrs, 5-15K wob, 100 rpm's, 56 spm, 237 gpm, On btm pressure 2000 psi, ave ECD 12.8 ppg, max ECD 13.1 ppg, control drlg to control ECD's below 13.0 ppg, rot wt 128K, up wt Printed: 5/25/2004 9:34:47 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3H-10 3H-10 ROT - SIDETRACK Doyon Drilling Inc Doyon 141 Start: 5/6/2004 Rig Release: 5/15/2004 Rig Number: Spud Date: 11/30/1987 End: 5/15/2004 Group: 5/12/2004 06:15 - 23:00 16.75 DRILL DRLG PROD 23:00 - 00:00 1.00 DRILL CIRC PROD 5/13/2004 00:00 - 03:00 3.00 DRILL WIPR PROD 03:00 - 04:45 1.75 DRILL WIPR PROD 04:45 - 06:00 1.25 DRILL CIRC PROD 06:00 - 10:00 4.00 DRILL TRIP PROD 10:00 - 13:30 3.50 DRILL PULD PROD 13:30 - 15:30 2.00 WELCTL EORP PROD 15:30 - 16:00 0.50 CASE RURD PROD 16:00 - 21 :45 5.75 CASE PULR PROD 21:45-22:15 0.50 CASE RUNL PROD 22:15 - 23:00 0.75 CASE CIRC PROD 23:00 - 00:00 1.00 CASE PULR PROD 5/14/2004 00:00 - 00:30 0.50 CASE RUNL PROD 00:30 - 01 :00 0.50 CASE CIRC PROD 01 :00 - 02:00 1.00 CASE RUNL PROD 02:00 - 02:30 0.50 CEMENT PULD PROD 02:30 - 05:30 3.00 CEMENTCIRC PROD 05:30 - 06:30 1.00 CEMENT PUMP PROD 06:30 - 07:00 0.50 CASE DEOT PROD 07:00 - 07:30 0.50 CEMENTOTHR PROD 07:30 - 08:15 0.75 CEMENTCIRC PROD 08:15 - 08:45 0.50 CEMENT PULD PROD 08:45 - 12:00 3.25 DRILL PULD PROD 140K, dn wt 120K, ave BGG 150 units, Max gas 3200 units, Raise mud weight f/11.3 to 11.6 ppg as per schedule. Monitor well, Pump Hi-vis sweep, Circ hole clean, BGG below 100 units. Observe well, Back ream out to 5,496' at drilling rate, POOH on elevators (No tight hole-Hole in very good shape), Observe well. RIH to 6,338', Precautionary wash & ream to Btm @ 6,410'. Circ btm's up w/241 GPM @ 1750 psi, 100 RPM, Trip gas 400 units, Pump Hi-vis sweep & circ hole clean. ObservE! well, Back ream out to 5,496' w/186 GPM @ 1000 psi, POOH on elevators to BHA @ 1,105' (No tight hole-Hole in very good shape). Stand back 8 stands HWDP, Lay down 5 HWDP, Jars, DC's, PJSM, RemovE~ A.A. sources, Down load MWD/LWD, Lay down BHA. Pull wear bushing, Set test plug, Change lower rams to 4-1/2", Test door seals to 2500 psi, Install wear bushing. Rig to run 4-1/2" liner, PJSM. Run 97 joints 4-1/2",12.6#, L-80, SLHT casing, Pick up liner hanger, Liner wt. UP 64K, DN 64K. RIH w/liner at 40/50 fUmin. to 3,505'. Circ pipe volume and btm's up at rate of 3 bpm @ 300 psi @ 3,505', Liner UP wt. 66K, DN 66K, "0" Torque at 15 RPM. RIH w/liner at 40/50 fUmin. to 4,736'. RIH w/4-1/2" liner at 40/50 fUmin. to 4,923'. Circ btm's up at rate of 3 bpm @ 550 psi. RIH w/4-1/2" liner at 40/50 fUmin., Tag btm @ 6,410'. Pick up and rig up Baker plug dropping cement head. Break eire, Stage pump rate up to 4.5 bpm @ 700 psi, Circ & cond mud for cement, Final properties PV 10, YP 14, Gels 8/13/15, Vis 39, Wt. 11.6 ppg, Trip gas 550 units, No mud lost. Casing UP 111 K, DN 11 OK, TO at 15 RPM 2.5K., Held PJSM for cement job, Batch mix cement. Switch over to Dowell cementers, Pump 10 bbls CW100 at rate of 3.2 bpm @ 510 psi, Pressure test liners to 4500 psi, Pump 40 bbls 12.0 ppg MudPUSH at rate of 4.0 bpm @ 750 psi, Pump 115 sxs (47 bbls) 1.2.5 PPQ LiteCRETE Lead cement plus additives at rate of 4.6 bpm @ 910 psi, Followed by 110 sxs (23 bbls) 15.8 PPO Tail cement plus additives at rate of 4.7 bpm @ 800 psi, Shut down, Flush Dowell lines to rig floor with water, Switch to rig pumps and flush lines to rig floor with Hi-vis Sea water, Drop Baker wiper plug and displace cement w/ 55 bbls Hi-vis sea water, followed by 25 bbls 11.6 ppg mud at rate of 4 bpm @ 600 to 1700 psi, Observed wiper plug enter liner and took 2800 psi to shear, Continue to displace and bump plug with calculated displacement bump plug w/2200 psi, Slowed rate to 2 bpm @ 1500 to 1600 psi for last 8 bbls, Reciprocated 15' and rotated liner at 15 RPM from time cement rounded shoe to cement above liner top, Then landed shoe @ 6,405.00', Top of liner @ 3,367.60', Had good circ thru out job, CIP @ 0625 hrs 5/14/04. Set liner hanger, Set liner packer, Release from liner, Test casing to 500 psi for 5 min. reverse out est..10 bbls cement, MudPUSH, CW100 at rate of 7 bpm @ 900 psi. ' Circ long way 3 complete circulations at rate of 11 bpm @ 2000 psi. Observe well, Pump dry job, Rig down cement head, Clear rig floor. POOH & lay down 4" drill pipe, Lay down Baker liner running tools. Printed: 5/25/2004 9:34:47 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3H-10 3H-10 ROT - SIDETRACK Doyon Drilling Inc Doyon 141 Start: 5/6/2004 Rig Release: 5/15/2004 Rig Number: Spud Date: 11/30/1987 End: 5/15/2004 Group: 5/14/2004 12:00 - 16:15 4.25 DRILL PULD PROD RIH & Lay down excess drill pipe and HWDP from derrick 16:15 - 17:15 1.00 CMPL TN RURD CMPL TN Pull wear bushing, Rig to run 4-1/2" completion. 17:15-21:30 4.25 CMPL TN RUNT CMPL TN Run 4-1/2",12.6#, L-80, IBT completion string to 3381' & tag top of liner. 21 :30 - 22:30 1.00 CMPL TN DEOT CMPL TN Rig & test 7" & 4-1/2' casing to 3500 psi for 30 min.- OK. 22:30 - 23:15 0.75 CMPLTN CIRC CMPL TN Change over & Flush well w/ clean sea water w/1% CRW-132 Corrossion inhibitor at rate of 15 bpm @ 2700 psi. 23:15 - 00:00 0.75 CMPLTN SOHO CMPL TN Space out completion string and pick up pup joints. 5/15/2004 00:00 - 00:45 0.75 CMPLTN SOHO CMPL TN Make up Hanger & Landing loint, Land tubing @ 3,380', RILDS. 00:45 - 02:30 1.75 CMPLTN DEOT CMPL TN Rig & test 4-1/2" tubing to 3500 psi for 15 min. on chart, Bleed tubing press. to 1500 psi, Pressure test 4-1/2" x 7' annulas to 3500 psi for 15 min. on chart, Bleed tbg pressure, RP valve did not shear, Repressure annulas several times to finally shear RP valve. 02:30 - 02:45 0.25 CMPL TN PULD CMPL TN Lay down landing joint, Set BPV in hanger. ,/' 02:45 - 04:00 1.25 WELCTL NUND CMPL TN Nipple down BOPE. 04:00 - 06:30 2.50 WELCTL NUND CMPL TN Nipple up FMC tree, Test hanger void to 5000 psi for 10 min., Pull BPV, Set 2 way check, Test tree to 250 low & 5000 psi high for 10 min. 06:30 - 07:45 1.25 CMPL TN FRZP CMPL TN Rig little Red service, Freeze protect 4-1/2"x 7" annulas w/60 bbls diesel, Put tubing and annulas in communication and allow to U-tube. 07:45 - 09:00 1.25 WELCTL EORP CMPL TN Change lower pipe rams from 4-1/2" to 5". 09:00 - 10:30 1.50 WELCTL NUND CMPL TN Rig down U-tube lines, Set BPV, Nipple down pump in flanges, Nipple up Blank flanges on tree, Secure well. 10:30 - 12:00 1.50 DRILL RIRD CMPL TN Change saver sub & grabbers on top drive back to 5". Note; Release rig @ 12:00 hrs 5/15/2004. Printed: 5/25/2004 9:34:47 AM e 3H-10B Well Events Summary e Date Summary OS/22/04 DRIFT TUBING WITH 3.70" SWAGE TO 6195'WLM, DRIFT TUBING WITH 22' X 2.875" HC DUMMY PERF GUN TO 6225'RKB, SET 1" DV @ 3291'RKB, PT TUBING AND CASING 2500#. [PT Tbg-Csg, Tag OS/26/04 RAN SCMT BOND LOG FROM 6202' TO 3210' -- CEMENT QUALITY WAS VERY GOOD FROM 6200' TO 5705' AND ABOVE 5705' CEMENT VARIED FROM GOOD TO FAIR UP TO 3510' -- TAGGED BOTTOM AT 6214' -- PERFORATED: 6190' - 6200', 6 SPF PJ. 5/27/2004 PERFORATED: 6039'-6059', 6069'-6089', 6124'-6144' AND 6154'-6164' - 6 SPF POWERJET. y ConocoPhillips ConocoPhillips Alas~nc.,Slot #10 Pad 3H, Kuparuk River Unit, North Slope, Alaska SURVEY U.G Page 1 Well bore: 108 Well path: MWD w/Sag<3537 - 6410'> Date Printed: 25-May-2004 '&i. BAKER HUGHES INTEQ w......' .. Néme 10B Svstern· Name AK4 on NORTH AMERICAN DATUM 1927 Field Néme KUDaruk River Unit I Eastillo· 48;754.6208 I Northino 5948985.8206 I êðôrt!ŠVstem Name «<.< ,NorthAlionmef'lt AK4 on NORTH AMERICAN DATUM 1927 datum' True All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (RKB(Doyon #141) 66,6' 66.6ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 56.25 degrees Bottom hole distance is 893.06 Feet on azimuth 57.04 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ) ()"3 _ 1 ~ Ô Conoc;p.,illips ConocoPhillips AlastnC.,Slot #10 Pad 3H, Kuparuk River Unit,North Slope, Alaska SURVEY LaG Page 2 Wellbore: 108 Wellpath: MWD w/Sag<3537 - 6410'> Date Printed: 25-May-2004 r&l. BAKER HUGHES INTEQ Wel I path (Grid) Report MD[tt] Inc[deg] Azi[deg] TVD[ft] Station Station Dogleg Severity Vertical Easting Northing Position(Y) Position(X) Sectionfftl 3537.00 15.43 84.34 3529.79 39.72N 81.09E 0.00 89.50 498735.38 6000374.82 3829.89 17.44 64.14 3810.93 62.73N 159.44E 2.06 167.42 498813.72 6000397.81 3921.63 15.42 58.79 3898.93 75.05N 182.24E 2.75 193.22 498836.52 6000410.12 4015.87 14.64 56.70 3989.94 88.08N 202.91 E 1.01 217.65 498857.19 6000423.15 4110.21 13.92 48.43 4081.38 102.16N 221.37E 2.29 240,82 498875.65 6000437.22 4204.81 13.65 45.28 4173.25 117.56N 237.81E 0,84 263.05 498892.10 6000452.62 4297.85 12.08 45.74 4263.96 132.08N 252.59E 1.69 283.40 498906.87 6000467.14 439121 11.35 44.64 4355.37 145.44N 266.04E 0.82 302.00 498920.33 6000480.49 4484.82 10.85 53.44 4447.24 157.24N 279.59E 1.88 319.83 498933.88 6000492.29 4578.53 12.00 59.26 4539.09 167.47N 295.05E 1.74 338.37 498949.33 6000502.52 4671.99 12.49 58.21 4630.42 177.76N 311.99E 0.58 358.17 498966.28 6000512.81 4765.19 12.06 57,16 4721.49 188.35N 328.73E 0.52 377.98 498983.02 6000523.39 4858.34 11.42 59.42 4812.69 198.32N 344.85E 0.85 396.91 498999.14 6000533.36 4951.27 12.20 54.09 4903.66 208.76N 360.72E 1.44 415.91 499015.01 6000543.79 5045.55 12.69 53.61 4995.72 220.75N 377.13E 0.53 436.21 499031.42 6000555.77 5138.00 13.44 53.18 5085.78 233.21N 393.90E 0.82 457.09 499048.19 6000568.23 5231.21 13.16 52.57 5176.49 246.15N 411.00E 0.34 478.49 499065.29 6000581.17 5324.12 13.50 52.11 5266.90 259.24N 427.96E 0.38 499,86 499082.25 6000594.25 5418.28 13.83 53.31 5358.39 272.71N 445.66E 0.46 522.06 499099.95 6000607.72 5511.86 14.62 54.35 5449.10 286.28N 464.22E 0.89 545.04 499118.52 6000621.28 5606.26 15.74 56.73 5540.21 300.25N 484.61 E 1,36 569.75 499138.90 6000635.25 5699.51 17 .44 59.44 5629.57 314.29N 507.2?E 2.00 596.35 499161.51 6000649.29 5793.33 19.76 62.67 5718.49 328.73N 533.42E 2.70 626.15 499187.71 6000663.71 5886.90 22.83 61.22 5805.66 344.73N 563.39E 3.33 659.96 499217.68 6000679.71 5979.87 26.54 53.47 5890.14 365.79N 595.91 E 5.29 698.70 49925020 6000700.76 6072.98 27.92 51.61 5972.93 391.71N 629.71E 1.74 741.21 499284.01 6000726.68 6166.41 27.54 51.13 6055.63 418.85N 663.67E 0.47 784.53 499317.97 6000753.81 6260.12 26.63 51.10 6139.06 445.63N 696.88E 0.97 827.02 499351.18 6000780.58 6331.32 26,03 52.86 6202.88 465.09N 721.76E 1.38 858.51 499376.06 6000800.03 6410.00 26.03 52.86 6273.58 485.94N 749.28E 0.00 892.98 499403.58 6000820.87 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (RKB(Doyon #141) 66.6' 66.6ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 56.25 degrees Bottom hole distance is 893,06 Feet on azimuth 57.04 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated y ConocoPhillips ConocoPhillips Alaslnc.,Slot #10 Pad 3H, Kuparuk River Unit, North Slope, Alaska SURVEY LaG Page 3 Wellbore: 108 Wellpath: MWD w/Sag<3537 - 6410'> Date Printed: 25-May-2004 r&l. BAKER HUGHES INTEQ Cornrnents MDrftl TVDfftl 3490.60 3484.96 6410.00 6273.58 I Northrftl 38,15N 485.94N I Eastfftl 69.25E 749.28E Cornment Tie-In Point to Previous Survey Proiected Data - NO SURVEY Hole Sections ~~e:~/8 1~~~~0.60 I Start Start TVDfftl Northfftl 3484.96 38.15N Start . IEndEnd ·End.. . I Start ..Wellbore Eastfftl MDfftl TVDrftT·· Northfftl ... Eastfftl 69.25E 6410.00 6273.58 485.94N 749.28E ··1 OB Casinas Na'nê TqP TOP I Top MDfftl .. TVDrftl Northrftl 3490.60 3484.96 38.15N TOP I Shoe Shoe < .ShÓI3Shoe ...i\f\Iellbore Eastfftl MDrftl TVDrftl Northrftl . Eastfftl 69.25E 6405.00 6269.09 484.61 N 747.53E 10B 4 1/2" Liner All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (RKB(Doyon #141) 66.6' 66.6ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 56,25 degrees Bottom hole distance is 893.06 Feet on azimuth 57.04 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated 3H-10B KuparukJ.gjector 4- WI Monobore Completi_tring Clnocó'PhiUips 16"x30" insulated conductor @ +/- 115' MD Surface Casing, 9-5/8" 36# J-55 BTC +/- 3024' MD / 3024' TVD TOL 3381' MD Milled Window Top to Btrn 3537' MD - 3549' MD ToplWhipstock: 3489' MD CIBP 3555' MD PBR: 6172' - 6186' MD PKR: 6186' - 6193' MD Inflatable TTRtnr : 6300' MD 7" 26# J-55 6763' MD /6327' TVD I I I I i! ~ f i' I II I ~ I I ~ I i J. I L... ~ I I I '- I> ~ ¡¡j ~ I ~ i ~ ~ I I ~ I ~ I ~~ ~ ~ ~ ~ i ~ ~ ~ I ~ 4-1/2" x 1" Cameo 'KBG-2' GLM w/ DCR Dump Kill Valve (3000 psi casing to tubing shear) with 10ft, handling pups installed above and below. 1 jt 4-1/2" 12,6# L-80 IBT-Mod tubing 4-1/2" Cameo 'DB' Landing Nipple with 3.813" No-Go profile and 10 ft. handling Pups installed above and below, X-Over: 4-1/2" IBT-Mod Box x 5" LTC Pin 10Ft. Baker 5.25" Bullet Seal assembly w/ 5" LTC box up § ~. ~ ~ ~ ~ !íí ~ I ~ ! ~ æ ~ æ ~ JJ ~ !íí ~ !íí ~ !íí ~ !íí ~ !íí ~ æ " I i JI I I ~ I ~ ~ ~ I I I ~ ... 4-1/2" FMC Gen IV Tubing Hanger, 4-1/2" L-80 IBT-Mod pin down, Special drift 3.91" 4-1/2" 12,6# L-80 IBT-Mod Spaceout Pups as Required. Special drift 3.91" 4-1/2" 12.6# L-80 IBT-Mod Tubing to Surface. Special drift 3.91" 4-1/2" Cameo 'DB' Landing Nipple with 3.875" No-Go profile set @ +/- 500' MD with 10 ft, handling Pups installed above and below, 4-1/2" 12.6# L-80 IBT-Mod Tubing as needed ..... ( Liner Assemb/v (run on drilloioet 150' of liner over/ao Baker 5" x 7" 'ZXP' Liner Top Isolation Packer with HR profile Baker 5" x 7" 'Flexlock Liner Hanger X-Over 5" BTC Box x 4-1/2" SLHT Pin XX Joints 4-1/2" 12,6# L-80 SLHT liner 9 Joints 4-1/2" 12,6# L-80 SLHT liner X-over 4-%" SLHT Box x 4-%" IBT-Mod Pin 4-1/2" landing Collar IBT-mod 2 jt 4-1/2" 12.6# L-80 IBT-Mod tubing 4-1/2" Float Collar IBT-mod 2 jts 4-1/2" 12.6# L-80 IBT-Mod tubing 4-1/2" Float Shoe IBT Future C-Sand Perforations Future A-Sand Perforations TD @ +/- 6410' MD /6274' TVD (205' MD below Kuparuk A-sand) KAM Updated 5/13/04 Ver. 5 " .. .. (IDJ ~~~~[i~ . AI,ASKA OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W, 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Kuparuk Drilling Team Leader ConocoPhillips (Alaska), Inc. PO Box 100360 Anchorage, Alaska 99510 Re: Kuparuk River Field 3H-10B ConocoPhillips (Alaska), Inc. Permit No: 203-160 Surface Location: 1322' FNL, 281' FWL, Sec. 12, T12N, R8E, UM Bottomhole Location: 840' FNL, 996' FWL, Sec. 12, T12N, R8E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to redrill the above development well. You have requested an exception to 20 AAC 25.412 (b) regarding packer placement more than 200' above the perforations. That exception is granted. The proposed casing program (long liner, mono bore) is unusual for an injection well and in particular for one that will be used in WAG (Water Alternating Gas) service. Additional integrity demonstrations beyond those specified in the regulations are appropriate. In addition to the annulus pressure test (MITIA) [25.412 (c)] and cement quality log [25.412 (d)] Conoco Phillips must 1). Perform a pressure test of the tubing and liner (MITT) using the seating nipple above the perforatións as well as the MITIA every 2 years. 2). Obtain a baseline RST log of the 4-1/2" liner over its entire length prior to injecting MI (Miscible Injectant) into the well. 3). Obtain a subsequent RST log within 30 days of completing the initial MI cycle. 4). Submit the RST logs with analysis to the Commission. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Randy Thomas Pennit No: 203-160 Page 20f2 . . Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the tenns and conditions of this pennit may result in the revocation or suspension of the pennit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, LÁ~~. ~andy ~edrich Commissioner BY ORDER OF THE COMMISSION DATED this:3 day of October, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section Re: 3H-10B proposal Subject; Re: 3H-108 proposal Date: Wed, 01 Oct 200306:45:19 -0800 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: Jerry C Dethlefs <Jerry.C.Dethlefs@conocophillips.com> CC: Jim Regg <jim_regg@admin.state.ak.us>, Johnny 0 Golden <Johnny.O.Golden@conocophillips.com>, Jerry C Dethlefs <jdethlef@ppco.com> . . Jerry, Thanks for the response. I believe it is appropriate to list them as conditions of the permit to drill. Based on how the well is intended to be constructed, these conditions are necessary in order for it to operate so it makes sense to me to put them upfront. Tom Maunder, PE AOGCC Jerry C Dethlefs wrote: > Tom: Your requirements are reasonable for this well. Johnny will have to > respond to the potential use of the GLM for future potential to run a liner > (the well was 3Q-21, I believe). Would you prefer these conditons as part > of the Permit To Drill, or handled separately as a Sundry Notice? Thanks > for the quick response. > > Jerry Dethlefs > Problem Well Supervisor > ConocoPhillips Alaska > > > Tom Maunder <tom_maunder@admin.state.ak.us> > > > > > > 09/30/200304:19 PM ~ To: Johnny 0 Golden/PPCO@Phillips cc: Jerry C Dethlefs/PPCO@Phillips, Jim Regg <jimJegg@admin.state.ak.us> Subject: Re: 3H-10B proposal > > > Johnny and Jerry, > Jim Regg and I have looked at your proposal and we find that with 2 > additions what you propose is > acceptable. > > The additions are: > 1. The 2 year MIT requirement will be the MITlA as you propose AND a MITT > using the nipple and a plug. > > 2. "Follow-on" RSTs will be required at a minimum following the first MI > cycle. > > If there is any indication of integrity loss, the continued use of the well > would be in jeopardy. It > is possible that water only might be an option, but as Jerry knows there > are pitfalls there as well. > > I know the GLM above the ZXP will be used for freeze protection, will it > potentially be used like the > sliding sleeve in that other well (sorry I don't remember which one) where > the coil string was run?? > > Please respond with your acceptance of these requirements and I will move > the sundry and permit forward > for approval. Call with any questions. 10f3 10/1/20036:45 AM Re: 3H-10B proposal > > Tom Maunder, PE > AOGCC . > > Johnny 0 Golden wrote: > > > Tom- /F c...¡ d- "3> -0 ~ » ./ > > Following up on our conversation last week about the proposed sidetrack > > 3H-10B. I have enclosed a revised completion diagram which has the added > > profile to MIT the tubing. In addition, Jerry and I have been discussing > > the mitigating measures we would be willing to agree to if it would allow > > MI injection into this well. The mitigating measures are as follows: » > > Premium connections will be used in 4-1/2" liner » > > Cement job will be designed to cover entire -4500' of 4-1/2" liner. » > > Bond log will be run up to the top of 4-1/2" liner to demonstrate » > > isolation of the Kuparuk » > > A RST log will be obtained prior to the first MI cycle. This log > could » > > then be used as a baseline for subsequentlogging passes if we become » > > concerned about losing MI uphole. » > > A passing MIT of tubing and casing (down to the ZXP) every two years. » > > This is similar to what we have done with other Kuparuk injectors that » > > have failed casing MITs. » > > I'd appreciate your thoughts. » > > Thanks - Johnny (265-6894) » > > (See attached file: 3H-10B revised completion.ppt) » » > - ---------- ------------------- - ---------- > > Name: 3H-10B revised completion.ppt > > 3H-10B revised completion.ppt Type: Microsoft PowerPoint Show > (application/vnd.ms-powerpoint) > > Encoding: base64 > (See attached file: tom_maunder.vcf) Tom Maunder <tom maunder@admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 20f3 . 10/1/20036:45 AM Conoc~nlips e Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Fax: (907) 265-1535 Email: randy.l.thomas@conocophillips.com August 5,2003 Alaska Oil and Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Permit to Drill, Rotary Sidetrack, Injector 3H-10b Dear Commissioner: ,/ ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill/Sidetrack an onshore Injector well, KRU 3H-10b, a development well. Note: it is planned to cut a window in the existing 7" production casing after squeezing cement into the 7" x 8-1/2" annulus at the whipstock depth. A permanent whipstock will be set with its top at ± 3562'. ,/ Note: this well is to be temporarily completed as a 4-1/2" mono-bore inject¿('The 4-1/2" mono-bore will facilitate a planned CTD sidetrack in the near future. A waiver to 20 ACC 25.412 (c) is required and ~ hereby requested. The liner portion of the mono-bore will be cemented top-to-bottom using a rotating liner hanger. A cement evaluation log will be run in the liner before using this well for injection. Again, this is a temporary waiver contingent upon satisfactory MIT's and cement evaluation log. Please find attached for the review of the Commission the information required by 20 ACC 25.005 (c). The spud date is expected to be approximately 10/15/03. If you have any questions or require any further information, please contact Shane Cloninger at 265- 6829. Sincerely, ~~ Randy Thomas GKA Drilling Team Leader SEP 1 6 2003 OR1GtNAL 1 a, Type of Work: Re-entry L..J 2, Operator Name: ConocoPhillips Alaska, Inc, 3. Address: Dril'''' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION -n--\ PERMIT TO DRILL $" c.....~.,p 20 AAC 25.005 Redrill t.£ 11b1b. Current Well Class: ExploratoryU Development Oil U Multiple Zone 0 Stratigraphic Test 0 Service 0 Development Gas 0 Single Zone 0 5, Bond: ~ Blanket U Single Well 11, Well Name and Number: Bond No. 59-52-180 3H-10B 6. Proposed Depth: 12. Field/Pool(s): MD: 6319'· TVD: 6189' . Kuparuk River Field e P.O. Box 100360 Anchorage, AK 99510-0360 4a, Location of Well (Governmental Section): Surface: 1322' FNL, 281' FWL, Sec. 12, T12N, R8E, UM / Top of Productive Horizon: 929' FNL, 873' FWL, Sec. 12, T12N, R8E, UM ' Total Depth: 840' FNL, 996' FWL, Sec. 12, T12N, R8E, UM I 4b, Location of Well (State Base Plane Coordinates): Surface: x- 498655· 16. Deviated wells: Kickoff depth: 3550, ft. 18, Casing Program Size Hole Casing 6.125" 4.5" 19 Total Depth MD (It): 6365' Casing Structural Conductor Surface Production Open Hole Liner Perforation Depth MD (ft): 20, Attachments: Filing Fee Property Plat e ~ I<:f.l 12.6# NS-CT 7, Property Designation: ,tip¿. ~5531 ~ 8. Land Use Permit: Kuparuk River Pool 13. Approximate Spud Date: 10/15/2003 L-80 5988' Length Size 115' 16" 3024' 9-5/8" 6264' 7" 95' 2-3/8" 6268' - 6365' o BOP SketchD o Diverter Sketch 0 21, Verbal Approval: Commission Representative: ADL 2657 9. Acres in Property: 2560 ' 14, Distance to Nearest Property: 996' at TD 2919' PRESENT WELL CONDITION SUMMARY Total Depth TVD (It): Plugs (measured) Form 10-401 Revised 3/2003 . y- 6000335 . Zone- 4 Maximum Hole Angle: 30° Specifications Weight Grade Coupling Length MD 10, KB Elevation ,/ RKB 28' , 67' AMSL 17. Anticipated Pressure (see 20 AAC 25.035) . Max. Downhole Pressure: 3496 psig / Max. Surface Pressure: 2844 psig Setting Depth Quantity of Cement Bottom c, f. or sacks TVD (including stage data) 15, Distance to Nearest Well within Pool: 3H-26 , 227' @ 3550' Top TVD MD 3400' 3397' 6319' 6189' 130 sx LiteCrete, 120 sx Class G (To be completed for Redrill and Re-Entry Operations) I Effective Depth MD (It): Effective Depth TVD (It): Junk (measured) 6270' 5907' Cement Volume MD TVD 225 sx AS I 1300 sx AS I, 100 sx AS I 450 sx Class G, 200 sx AS I open hole 115' 3024' 6264' 6365' 115' 3023' 5902' 5988' IPerfOration Depth TVD (ft): 5905' - 5899' Drilling Program 0 Time v, Depth Plot U Seabed Report 0 Drilling Fluid Program 0 Date: Printed Name 22, I hereby certify that the foregoing is true and correct to the best of my knowledge. R. Thomas ~~ Commission Use Only Permit to Drill 0 I API Number: 8. _I Permit Approval Isee cover letter /' Number: 203-/0 50-/03 -200 7-64 Date: for other requirements Conditions of approval: Samples required 0 Yes &0 Mud log required ~..~~ ~£: Hydrogen sulfide measures ~Yes 0 No Directional survey required 1 J?(m tfl '-'Nb-- ::~:~~:l~I~~~lssIONER :;:~::,~ ~::1C:;;~';0 (1 r· \. Signature Shallow Hazard Analysis U 20 AAC 25.050 requirements 0 Contact Shane Cloninger 265-6829 Title Kuparuk Drilling Team Leader Phone'2.b \6 ~ :s ò Date '7 f I { (0 -; Preoared bv Sharon AI/suo-Drake , , Submit in duplicate .;.J ,---) ApplicÇltion for Permit to Drill, Well 3H-10S ) Revision No.O ./ Saved: 8-Sep-03 Permit It - Kuparuk Well 3H-108 Application for Permit to Drill Document Moxil'nizE We-II VOhH Table of Contents 1. Well Name......................................... ........................................................................ 2 Requirements of 20 AAC 25.005 (f)........................................................................................................ 2 2. Location Sum mary ........................... ................................................................ ........ 2 Requirements of 20 AAC 25.005(c)(2) ................................................................................................... 2 Requirements of 20 AAC 25. 050(b)........................................................................................................ 2 3. Blowout Prevention Equipment Information .........................................................3 Requirements of 20 AAC 25.005(c)(3) ................................................................................................... 3 4. Dri II i ng Hazards Information...... .................................................... ......................... 3 Requirements of 20 AAC 25.005 (c)( 4) .................................................................................................. 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 3 6. Casing and Cementi ng Program .............. .... ................................. ..................... .....4 Requirements of 20 AAC 25.005(c)(6) ................................................................................................... 4 7. Diverter System Information.......................................................... ......................... 4 Requirements of 20 AAC 25.005(c)(7) ...................................................................................................4 8. Dri II i ng FI u id Program ............................................................................................. 4 Requirements of 20 AAC 25.005(c)(B) ................................................................................................... 4 9. Abnormally Pressured Formation Information ...................................................... 5 Requirements of 20 AAC 25.005 (c)(9) ........ .......................................................................................... 5 1 O. Seism ic Analysis.................................................................................... .................. 5 Requirements of 20 AAC 25.005 (c)(1 0) ................................................................................................ 5 11. Seabed Condition Analysis .....................................................................................5 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 5 12. Evidence of Bond i ng ............................................................................................... 5 Requirements of 20 AAC 25.005 (c)(12) ........................ ........................................................................ 5 13. Proposed Dri II i ng Program ..................................................................................... 5 O r;, ,.',::~ ,~ .~ I ~ , , .. i .g ~,,¡' , ¡¡ "' " .; t:t" J II' ',)!' ." ': ~ " _~ ~¡ \~" J 11) '; ","'" 3H-10B PERMIT IT. DOC Page 1 of 6 Printed: 8-Sep-03 3H-10B PERMIT IT. DOC Page 2 of 6 Printed: 8-Sep-03 OR\G\N1\l Please see Attachment 2: Directional Plan Requirements of 20 AAC 25. 050 (b) If a we!! Is to be intentionally devlatec~ the application for a Perrmt to Dn/l (Form 10-401) mus't (1) 117t:/ude a pla0 drawn to a sUitable scak?¡ .shovling the path of tile propo::'ì.:xi v,;elíbon~ ¡/7duding all adjacent wellÖores within 200 téet of an V portion of the proposed well:' 6319' 6189' 6122' 6014' 5925' 5858' 67' AMSL 39' AMSL and (D) other III/ormation required by 20 AAC 25: 050(b),' Measured Depth¡ RKB: Total Vertical Depth¡ RKB: Total Vertical Depth¡ 55: Sec 12, T12N, R8E, UM j Measured Depth¡ RKB: Total Vertical Depth¡ RKB: Total Vertical Depth¡ 55: Location at Total Depth 1840' FNL, 996' FWL, NGS Coordinates Northings: 6,000,818 Eastings: 499,370 Eastings: 499,247 Location at Top of Productive Interval (Kuparuk C-4 Sand) NGS Coordinates Northings: 6,000,729 929' FNL, 873' FWL, Sec 12, T12N, R8E, UM J j 11322' FNL, 281' FWL, Sec 12, T12N, R8E, UM RKB Elevation Eastings: 498,654 Pad Elevation Location at Surface NGS Coordinates Northings: 6,000,335 2. Location Summary Requirements of 20 AAC 25.005(c)(2) 1117 application (Òr a Permit to Drill must be aŒfxnpanied by eac/¡ of the fbllowing items, except lor an Item alreadv on file with tlÌ!:~ conmìiS3ìon and identified in the application: (2) a P/.'ìt idcntifylÌ7[J the properly and the (A)th(; coordinates oltl7e pm posed loc/:ltiofl reférenced to govemmental section lines, (8) the cOOldlÌ7att?S of the proposed !oo:Jtion of the well at the sud;¡Cí.~ rel'erenced to tIle state pLme ccìordinate system fÒr th/~"i slate as' maintalÌï¿yj by the National (j'eodetic Surve,V in the National Ot:eanic and Atmospheric Administration,' (C) the propos'cd depth of the well at the top of eae/¡ ofJjeäive formatkm and at total depth/ owners and s17oWliì(} well at the: surfÓæ, at the top of' each objective formatiof7, and at total depth, 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be id(mtitled by a unique name designated by tile operator ami a unique API numÖer assigned by tIlt:' commission under 20 AAC 25, 040(b). For a v.¡e!1 with multiple well branches, cadì brand; mus't similarly be identified by a un¡(!l/í.-; name and API number by adding a sull/x to the name designated for the well by the ojx?rator and to the number as!óigned to the well by the commls..':ion. The well for which this application is submitted will be designated as 3H-l0B. 15. Attachments................. ............... ............................................................................. 6 Attachment 1 Drilling Program... ........ ..... ........... .... ...... .............. ... ............ .......... ....... ....... ....... ....... .......6 Attachment 2 Directional P,an.................................................,..........,................................ 6 Attachment 3 Well Schemaics.... ...... ......... .................................... ...... .... ............. ...... ... .... ..6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 5 Requirements of 20 AAC 25.005 (c)(14) .........................................................................,..............,....... 5 Requirements of 20 AAC 25.005 (c)(13) ..... ....... ....... ......... ... ..... ... ..... ....... ..... ........ ............. .............. .....5 þ...."'lication for Permit to Drill, We1l3H-10B Revision No.O Saved: 8-Sep-03 '-) Application for Permit to Drill, We1l3H-1 08 ) Revision No.O , Saved: 8-Sep-03 and (2) for all wells wdt7in 200 feet of tl7e proposed wellbore (A) list the names of the operators of those well.,,~ to the extent that those names are known or di<;,'Coverable li7 public record~ and show that eaell named operator has been furnished a copy of the application by certified mal¿' or (8) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An appliætion for a PermIt to Drill must be ac'co/Tlpanied by each of the fallowti7g Items~ except for an item already an file with the CXJmmis-sion and identified in tile applk.;·ation: (J) a diagram and description ot'the blowout prevention equipment (SOPE) as required by 20 AAC 25.035, 20 AAC 2.5.036, or 20 AAC 25.037; as applicable/ Please reference BOP schematics on file for Doyon 141. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be aanmpanied by eac:h of the f"ollowing ¡[em5~ except for an Hem already on file with the (X)mmis:.c,ion and identlfjed in the applk..:-ation: (4) info/matlon on drilling hazards¡ inäuding (A) the maxliTlum downhole pressure that may be encountere(~ cntelia used to determ1l7e it; and max/iTlum potential surface pressure based on a methane grt/dient,' BHP data on offset injectors indicates that the current reservoir pressure for 3H-l0b is .:5. 3500 psi at 5925' TVD, 0.59 psi/ft or 11.4 ppg EMW. ,- - The ma~imum potential surface pressure (MPSP) while drilling 3H-l0b is calculated using above maximum reservoir pressure, a gas gradient of 0.11 psi/ft, and the Kuparuk C sand target at 5925' TVD: MPSP, =(5925 ft)*(0.59 - 0.11 psi/ft) = 2844 psi ,/ (8) data 017 potential ga:5 zones,' KOP is in the Colville. The well bore is not expected to penetrate any gas zones between KOP and TD. and (C) data conceming potentkl! cau:,ì:?S olhole problems such as abnormally geo·pre.%ì.Jred strata, lost circulation zoneS;, and zones that have a propensity for diff-erentia! sticking,' 1. The first potential hazard is the LOT at the window. It is planned to cement this annular void with enough class "G" cement to cover and seal this section of the original well bore. Once that is achieved, a LOT/FIT of at least 13 ppg should be attained. 2. Sloughing shales in the Kalubik near the fault zone could cause hole trouble while drilling, tripping and running the liner. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An applk"c'JtJÒn for a Permit to Drill must be accompanied by eaä7 of the following item;;,~ exæpt for an item already on file ~'.¡ith the commiss"Ìon and ¡(jentlfied in the application: (5) a desaiption of tfle procedure for c.vnducting (ormation integrity test::,~ as required under 20 AAC 25. 030(f)/ A procedure is on file with the commission for performing LOT's. For 3H-l0b the procedure will be followed after milling the window, with one exception. The formation at the window depth (Colville) will be pressured until leak-off occurs or to 14 ppg EMW, which ever comes first (see step 6 in the procedure). . 0,' C,'"'>'· -A. ~ ~ .~, ~ l ...: .. ;-:'~ I'j :. f\ ~ . I" 'Y', ; ~;. ,"I '\' \ ': '. ,~ , .~. # ~¡ '\'i~ , ,II ;~ r2 .\:""'" 3H-10B PERMIT IT. DOC Page 3 of 6 Printed: 8-Sep-03 Sidetrack Hole mud properties initial Top HRZ Top Kalubik Kuparuk- TO / Density (ppg) 9.7 - 10.2 10.7 11.2 11.7 Funnel Viscosity 45-55 45-58 42-58 42-58 (seconds) Yield Point 11-15 20-25 20-25 20-25 (cP) Plastic Viscostiy (lb1100 6-12 8-18 8-18 15-25 sf) 10 second Gel Strength 2-5 4-7 4-7 4-8 (lb1100 sf) 10 minute Gel Strength 4-10 7-12 7-12 8-16 (lb1100 sf) pH 9-9.5 9-9.5 9-9.5 9-9.5 API Filtrate(cc) <6 <6 <4 <4 Solids (%) 6-11 1 0-15 1 0-15 15-1 9 OR\G\NAL 3H-10B PERMIT IT. DOC Page 4 of 6 Printed: 8-Sep-03 Drilling will be done using a KCljpolymer mud systems having the following properties: 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An applk'."r.:Jtion for a Permit to Dnll must be accompank?d by ead) of the folko¡wing items~ except f'or an item already on file with the commis:sion and Identitled in the applk.,::tion: (8) a dn//ing Iluid prograrn ¡(ìc!uding a diagram and description of the dnfling fluid s')Is-tern a.s- reqUired Öy 20 AAC 2.5JJ3}/ This rotary sidetrack will exit pre-existing casing at ± 3562'. BOPE will be installed prior to exiting the casing, and therefore, no diverter is required. 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An applk:ation fÓr a Permit to Drill must be accompanied by eac.j¡ of the fÒ/lowmg items¡ except fbr an item already on file v¡¡itli the comm/s:';ion dnd ¡(fen titled in the (7) a diag!am ami description ri/l/erlE'r system as' requked Öy 2() AAC 25'{J3.5~ unit's:'':; tlìis' require!Tlt'nt Is' waived Öy the {'(){WnI5:.sioll under}{) AAC 25, 035(/¡)(2)/ Cement Program Original TOC = 5616' MD Squeeze and/or circulate cement above & below window with 200 sx "G" 6-1/8" 12.6# L-80 NS-CT & 2919' 3400'/3397' 6319'/6189' 130 sx 12.5 LiteCRETE & IBT-mod 120 sx "G" - expanding cement: 15.8, 1.2 ft/sx 4-1/2 12.6# L-80 IBT-mod 3372' 28'/28' 3400'/3397' Stung into a Baker, 80-47 Tubing PBR/HGR & ZXP LNR PKR * This is a mono-bore completion requiring a waiver of ACC 20.25.412 (b). Btm MD/TVD (ft) 6763'/6327' 3562'/3554' Top MD/TVD (ft) 28'/28' 28'/28' Length (ft) 6735' 3534' J-55 J-55 Weight (lblft) 26 26 Window In the 7" Casing 4-1/2" Liner BTC-Mod BTC-Mod Casing and Cementing Program Hole Size (in) 8-1/2 8-1/2 Grade Csg/Tbg 00 (in) 7" Connection 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application fÓr a Permit to Dnll must be acc:ompanied /)y each otthe fò!/owing items~ except lo/" an item alreadv on flIe WIt!) tile commi.5..9Òn and ¡(ientifìed in the application: (6) a complete proposr.:?d cas-¡ng and cementing progff:7m as required by .?O AAC 25: 03Q and a des"oiptlon o(any s-jotted liner~ pre" perfÒrated Ilne/~ or S"'Cf'(:?en to be i/¡sfalled/ Þ"'''''ication for Permit to Drill, We1l3H-10B Revision No.O Saved: 8-Sep-03 0") APl"li('\.ation for Permit to Drill, Well 3H-1 OB , Revision No.O , Saved: 8-Sep-03 Diagram of Doyon 141 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be acc:ompanied by each of the fòllowing ¡fem$~ except tÖr an item already on file with the commis:,,'ion and identified in the applk.'iition: (9) tor an exploratOlY or stratigraphic test wel¿ a tabulation setting out the depths ofprediäed abnormally geo-pressured strata as required by 20 AAC 25, 033(t),; Nj A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An applicf:'Jtion for a Permit to Drill must be accompanied by each of the following ìtems~ except fÒr an item already on file with the commi5:.c,ion and identitied in the application: (1 ()) for an exploratory or stratigraphic test well; a seismic refraction or reflection analysis as required by 20 AAC 25: 06.1 (a),: Nj A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application fòr a Permit to Drill must be accvmpanied by each of the (ollowing item~ except (or an item already on file with the commission and Identified 1i7 the applicr1tion: (1.1) for a well dr/lIed from an offs17ore plat(vrm, mob1le bottom"lbunded structure, jack'·..up rig, or floating drdling vesse¿ an analysis olseabed conditions as required by 20AAC 25'. 061 (b); Nj A - Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application fÓr a Permit to Dnll must be accompanied by each o( the following items¡ except for an item already on tlle with the commi!;''3ìOn and Idenlifk,ld in the application; (12) eVidence showing that the requirements 01'20 AAC 25.025 {8ol7din£1}flave been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Perlrut to Dlill must be accompanied by each of the following Item.~ except ('Or an Item already on file with the commí..":9017 and Identified in the applkat/on: 1. See attachment 1, and refer to Attachment 3, Well Schematics. '·14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a PermIt to Dnll mustc be accompanied by each of'the fòllowlÍ7g Item.", except tor a/7 item already 0/7 tHe with the cOmmi'i:'7on and identified in the application: (14) a qenefi;¡1 desaiption of how t/7e operatvr plans to dispose of dr/lling mud and cuttings and a statement of whether the operator lí7tends to request authorization under 20 AAC 25'.080 ('Or an annular disp05ôl operation in the we/I.; Waste fluids generated during the drilling process will be disposed of at KRU's, lR-18 Class II ,/ disposal well. All cuttings will be processed through Doyon's ulta-sonic processor and then disposed of either at KRU's, lR-18 Class II disposal well, or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection at the G & I facility on DS-04. , ,.~~ jI t , ~.' J! ORIGINAL 3H-10B PERMIT IT. DOC Page 5 of 6 Printed: 8-Sep-03 3H- ,1",08 Pf.,~/'T" '~D 9C î¡ f"''' ~ ,of 6 I, ¡,I mö_ .', 03 ' :; ~'Y'. . . -, ep- ':",,~ .. l~'"'!ication for Permit to Drill, We1l3H-10B Revision No.O Saved: 8-Sep-03 f'· ~~ ,; ,~~, r~" ..",1 ~'.., r 1,'I!"\il"'!:' '11,',1: !e '~"~!'II:""'< ,I I"~ l ,~;, >:,~,,,,;r~ J Attachment 1 Drilling Program Attachment 2 Directional Plan Attachment 3 Well Schematics 15. Attachments : ·_~) APPlj('~" tion for Permit to Drill, Well 3H-108 ) Revision No.O , Saved: 9-Sep-03 3H-l0B Drilling Proaram Pre-Rig Well Work: 1. Check all lock down screws on the 7-1/16" x 5M tubing head flange. Test the packoffs on the 7" casing and the 9-5/8" casing. Check the OA for pressure and then pump ± 90 bbl of diesel down the OA to establish injectivity (relevant to squeeze operations later) and to insure freeze protection. 2. File Sundry notice - plug back. Notify AOGCC field inspector 24 hours before commencing au work. 3. RU au. Open the SSSV and RIH to the aD window at 6270' MD. Spot ± 5 bbl, class "G" cement plug on bottom. Pull up to ± 6000' MD and squeeze away 1-3 bbl if possible. The intended TOC should be at least 6150' MD. Circulate and displace the tubing with seawater while maintaining final squeeze pressure on the cement plug. POOH and freeze protect with ± 20 bbl of diesel from 2000' to surface. POOH. Maintain final squeeze pressure on the well. Close the SSSV and R/D CTU. SI. 4. After ± 48 hours, open the SSSV and test the cement plug to 2500 psi. Open the well and "flow check" for at least an hour. 5. RU SlU. Tag the cement plug to verify TOe. Pull the lowest dummy GlV possible. RD. 6. Perform a CMIT to 3000 psi against master valve, on chart for 30 minutes. Close the SSSV and repeat the CMIT against the SSSV (from below), on chart for 30 minutes. 7. RU E-line. Jet-cut the 3-1/2" tubing above TOC (to be determined). RD E-line. 8. Remove the necessary well houses and flowlines. Rig Work: 1. Notify the AOGCC field inspector 24 hours before spud and BOP test. MI/RU Doyon 141. Install a TWe. ND the upper tree assembly. NU and test the 13-5/8" BOPE to 250# / 3500# (note: a 7-1/16" x 13-5/8" DSA or spool is required). Retrieve the TWe. 2. Engage the 3-1/2" tubing with a spear. LID the tubing hanger. Screw in to the tubing and circulate the well clean with seawater. LID the tubing, control line, bands, and GlM's. 3. P/U a 6-1/8" milled tooth bit and a casing scraper. P/U 3-1/2" HWDP and DP. Circulate bottoms up with seawater at ± 3700' MD. POOH. 4. R/U E-Line. Run a CCl/Gage Ring/Junk Basket to ± 3700'. Make a CCl log from ± 3700' up to ± 3000'. POOH. RIH and perforate 8 squeeze holes at ± 3610'-12'. POOH. Close the blind rams, and with the OA open, establish injection into the squeeze holes at ± 2 bpm. Note: run a hose from the OA valve to an isolated pit to catch returns. 5. Set a 7" RTNR at ± 3584' MD: the RTNR must be > 2' above a casing collar and > 20' below a casing collar: the actual depth is adjustable. POOH. R/D E-line. Note: If sufficient injection rate cannot be established at 1500-2000 psi, consider a suicide squeeze. If this becomes the plan, set the RTNR on E-Line as planned and then perforate a second set of squeeze holes above the RTNR at ± 3510'-12'. R/D E-Line. 6. RIH with the stinger for the RTNR on drill pipe from the derrick. Sting into the RTNR and re-establish injection with the OA open. Note: If a suicide squeeze is attempted, circulate through the RTNR and both sets of perforations. 7. RjU Dowell. Mix and pump ± 200 sx (41 bbl) of class "G" cement + ~ 2% CaCI2 to accelerate the compressive strength curve. Squeeze the O.H. x 7" annulus with the OA open as before. Displace the cement with 3 bbl of fresh water followed by ± 22 bbl of seawater. If the pressure data indicates "lift", . 0 RIG' N If::: 9-Sep-03 3H-10B DRILLING PROGRAM.doc Page 1 of 3 Apnlication for Permit to Drill, Well 3H-1 OB Revision No.O Saved: 9-Sep-03 pull out of the RTNR and circulate the casing clean on top of the RTNR. If the pressure data indicated no lift, pump enough displacement to clear the perforations by .2:: 10 bbl and prepare to squeeze again. In either case, pull out of the RTNR and circulate two bottoms up with seawater right on top of the RTNR. The whipstock will be set directly on top of the RTNR. POOH. Note: If a suicide squeeze is planned, pump the cement job through the RTNR and both sets of perforations - taking returns from the 7" casing. Displace the cement with 2 bbl water and 21 bbl of seawater. Pull out of the RTNR and pull up ± 5 stands. Circulate the DP and casing clean but watch for seepage losses. Shut the well in and hold ± 1000 psi on the cement plug for 4-6 hours. POOH. RIH. Dress the cement plug to ± 3584' and test same to at least 13.5 ppg EMW. Circulate the hole clean at high rate. POOH 8. Once the squeeze operations are completed, RIH with Baker's "WindowMastel' whipstock system, bottom trip anchor, MWD, and UBHO on drill pipe from the derrick. Orient and set the whipstock using the MWD. 9. Shear off the whipstock. Displace the 7" casing and the pits with Hi-Vis, KCI-Polymer mud. Mill the window in the 7", 26#, J-55 casing, and continue milling until the upper watermelon mill is outside the casing: .2:: 29'. After reaming through the window to eliminate burrs and other irregularities, pump a ''Super Sweep/l'pill and CBU. Perform a lOT: minimum acceptable EMW = 13 ppg, maximum necessary = 14 ppg. POOH. 10. P/U a 6-1/8" PDC bit, PDM, MWD, lWD, non-mag flex collars and jars as required. RIH with the HWDP from the derrick, and then P/U an additional 30 stands of 3-1/2" DP. Finish RIH with DP from the derrick. Carefully wash the last 15'-20' to bottom. 11. Drill ahead: sliding to turn north and to drop angle slightly (Baker-Inteq program attached). If necessary, perform another lOT after drilling ahead ± 20'. The sidetrack point is in the Colville mudstone and no thief zones are expected near this depth. Maintain the KCI-Polymer mud properties as per the MI program. Watch the ECD and limit ROP as necessary to maintain ECD ~ 13.5 ppg. The MW should be .2:: 10.7 ppg at the T/HRZ: 5696' TVD. The MW should be ± 11.7 ppg before drilling into the T/Kuparuk: 5934' MD. -...... j 12. Control drill through the Kuparuk as needed for good quality lWD logs. Continue drilling into the Miluveach Shale to give ± 200' of rat hole below the base of the Kuparuk A. The proposed TD is ± 6319' j MD, 6189' TVD. At TD, circulate bottoms and make a wiper trip up near the window. RIH to TD. Circulate and condition the hole to run the liner. POOH. 13. R/U and run the 4-1/2" liner to TD. The required overlap is.2:: 150': TOl = 3400' MD. Rotate and reciprocate the liner while circulating and cementing. R/U Dowell and prepare to cement the liner. 14. Pump 10 bbl of CW100. Test Lines to 4000 psi. Rotate & reciprocate the liner throughout the job. Pump 40 bbl of Mud Push Spacer. Mix and pump 130 sx of LiteCrete (45 bbl) followed by 130 sx of class G expanding cement (23.6 bbl) at 15.7 ppg and 1.2 cfh;k. Drop the DP dart and displace with 45 bbl of 3% KCI followed by ± 24 bbl of mud. Slow the pump rate to ~ 2 bpm after pumping ± 22 bbl of seawater. Watch for the liner wiper plug to shear. Stop reciprocating the liner and finish displacement. Rotate the liner as long as possible. Slow the pump rate for the last 3 bbl and bump the plug with 1000 psi over final displacement pressure. Check the floats. Pressure up to ± 2500 psi and set the liner hanger. Release the HR setting tool and set the ZXP using slack off weight: .2:: 25,000#. Pressure up to ± 500 psi and slowly pull up out of the Liner hanger. When the pressure bleeds off to the annulus, immediately circulate bottoms up (± 90 bbl) at high rate. Note any cement and/or spacer returns. SID and test the ZXP to 3000 psi. R/D Dowell. 3H-1OB DRILLING PROGRAM.doc Page 2 of 3 dR, "(j[!i~Ä rep03 ') Appli"~ion for Permit to Drill, Well 3H-108 J Revision No.O , Saved: 9-Sep-03 15. Displace the well above the TOL with seawater (± 115 bbl) and until the returns are clean. Check for flow. POOH. LD/DP. RIH with the DP from the derrick and then LD/DP. 16. R/U and run the 4-1/2" tubing with the PBR seal nipple. RIH and tag the TOL. Space out the tubing string with pup joints such that there remains 1'-2' of free travel in the seal assembly. Install the tubing hanger and landing joint. Displace the well above the TOL with clean seawater. Sting into the PBR and land the tubing hanger. RILDs. Test tubing, PBR and liner to 3500 psi with the IA open. Bleed the tubing down to 2000 psi. Test the lA, PBR and TOL to 3500 psi. Bleed off all pressures. 17. Install a TWC. ND BOPE. NU and test the 4-1/16" (5M) tree to 5000 psi with the IA open. Pull the TWC. Pressure up the IA to ± 2500 psi and shear the "RP" valve. Displace the well with diesel freeze protect fluid through the "RP" valve (114 bbl). Install a BPV. R/D and M/O Doyon 141. Post-Rig Well Work: 1. Pull the BPV. R/U SLU. Drift and tag to PBTD. 2. Dummy-off the GLM. R/D SLU. 3. R/U E-Line. Run a GR/CCL/SCMT from PBTD to TOL. .... 4. Perforate the Kuparuk as directed. RID E-Line. 5. Install new "5" riser and replace the well house(s). 6. Secure waiver for ACC 20.25.412 (b) before injecting water, etc. o RIG I N A ted: 9-Sep-03 3H-10B DRILLING PROGRAM.doc Page 3 of 3 a ::::0 - G) - z » r- ...._.....__.____...___..______m._________..____.._..______...____"__..____ Created by bmichoel For: S Coyner Dote plotted: 26-Aug-20D3 ¡ Plot Reference is 3H-10B VersionllL : i Coordinates ore in feet reference slot # 1 OA. ¡ iTrue Vertical Depths ore reference RKB (Doyon 141 ).: ~glm IAKI. -..oIIU lNTEQ ---------- ---------------------- == P RO F~ ----- Point ----- MD Top Whipstock Face 3550.00 Base Whipstock Face 3562.00 KOP - End Milled Hol~ 3580.00 EOC 3742.42 HRZ 5759.16 Build 6/100 5773.80 5861.19 6014.21 Kalubik C4 EOC A A3 6043.28 Target - A1 6056.68 6061.30 6085.55 6119.03 Miluveach 6180.23 I 6319.03 ConocoPhillips Alaska, Inc.1 Structure : Pad 3H Well: 108 -..-------------. Field: Kuparuk River Unit Locat,~,~,:__~_~,~~~~e. Alaska] E Inc 15.72 15.83 15.83 13.83 13.83 13.83 19.07 28.26 30.00 30.00 30.00 30.00 30.00 30.00 30.00 COMMEN 85.35 78.34 78.34 53.96 53.96 53.96 54.08 54.19 54.20 54.20 54.20 54.20 54.20 54.20 54.20 Dir TVD 3542.32 3553.87 3571.18 3728.34 5686.60 5700.82 5784.60 5924.60 5950.00 5961.60 5965.60 5986.60 6015.60 6068.60 6188.80 ¥ ConocoPhillips DA A North 40.07 40.54 41.53 57.44 341 .10 343.16 357.69 393.63 401.91 405.83 407.18 414.27 424.07 441 .97 482.56 East 84.60 87.82 92.63 130.06 51 9.90 522.73 542.76 592.49 603.96 609.40 611 .27 621 . 1 0 634.68 659.50 715.79 c::::::=:=J c::=== ===:::J ~ V. Sect 92.61 95.54 100.09 140.06 621 .79 625.29 650.01 711 .32 725.47 732.16 734.47 746.58 763.32 793.90 863.25 Deg/100 0.00 15.90 0.00 4.00 0.00 0.00 6.00 6.00 6.00 0.00 0.00 0.00 0.00 0.00 0.00 Created by bmlchoel For: S Coyner Dote plotted : 25-Aug-2003 Plot R.ference I. 3H-10B Vor.lonNI. coordinates ore In reet rererence slot #10A. True Verticcl Deplhs ore reference RKB (Doyon 141). ~!itW!l ..... ....._..__...........~...........~............._.._.............-.......-.......... INTEQ 3400 - 3600 - 3800 - 4000 - 4200 - ........... 4400 - -+- Q) Q) 4- '---" 4 600 - ...r: -+- 0.. Q) 4800 - 0 0 5000 - U :;: !..... Q) > 5200 - Q) :J !..... 5400 - r- I V 5600 - 5800 - 6000 - 6200 - 6400 - 6600 - TANGENT ANGLE 13.83 DEG ) ) ........................................................................................ ......_........................................................................................................ ConocoPhillips Alaska, Inc. ....-.................................. ..... ................"...................................... .........................................."........................................................ Structure: Pad 3H Well: 108 Field: Kuparuk River Unit Location: North Slope, Alaska .................................................................-...............-............................-............................................-....-........-....-............-............................ Top Whipstock Face Base Whipstock Face KOP - End Milled Hole EOC 56.25 AZIMUTH 763' (TO TARGET) \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ HRZ \ B1uJI.~06/1 00 \ Kalubik \ \~ A2 ' Target - A1 \ Miruveach \ \ \\ \ \ @] u*Plane af Proposal*** DLS: 6.00 deg per 100 ft 27.40 C4 EOC AA3 3H-10B ST TGT RVSD 11 JUL 03 TARGET ANGLE 30 DEG 400 200 o 200 400 600 800 1000 1200 1400 1600 1800 2000 2200 2400 Vertical Section (feet) -> Azimuth 56.25 with reference 0.00 N, 0.00 E from slot #10A OR I GINA_ ~/ ConocoPhillips o :::0 - G) - z » r- ConocoPhillips Alaska, Inc.\ ~ ConocoPhillips 240 Created by bmichael For: S Coyner Dote plotted : 26-Aug-2003 Plot Reference is 3H-10B VersianN!. Coordinates ore in feet reference slot 110A. Vertical Depths ore reference RKB (Doyon W~UI -aU INTEQ 60 0 840 900 960 1020 1080 1140 780 56.25 AZIMUTH -720 763' (TO TARGET) '--- ***Plone of Proposal*** -660 , ~ - 600 . - 540 TRUE Structure : Pad 3H Well : 1 DB Field: Kuparuk River Unit Location: North Slope, Alaska: East (feet) -> 720 780 120 180 240 300 360 420 480 540 600 660 180 120 60 I I I I I I I I ~ ~ ¥ ¡;fJ R~ ßÞ \ \ \ II í /// CÀ \ \ íí r/ / ~\,""" í! ' // \ \ ,/./ ///// \ \ ; \\,""""" \:,'.'.\"",1, 500 ¡I., . un f í' If ;6~ \"1""",5",,..,0, ~\ / / II // , \\, \'\000 j100¡í /Î / //// ~ ~OO \ \ ~l~71500 //// '''', \. 25~b ~ ie8 / // C2V.........', ',', \1000\ V,I / // .... 1ÒQO ,\ '~1'~! // 2 1 ~o.,i:::~~~~,-..J'ÖGQ V 500/ // (JIL,-... '\ '. 1., '-, ~o.O' / ~, ".'............. \ ''-,- 5ö(Y..\'J ; ,/'/20;0 ~ ....,... '\, ""1'" 0'500/ 1 000 ¡ ,,/'" ,.."..... 1 000'" 1 590 -"'. I /2500 ,,/"'/ """" '",,; /500 / /// ,......... ,; I / _ __~~®JO ¡ // \ ') 50<)' ./ \ 20~"'--ßÔO \ 0. f \ sbo "'0-./ '.............,... 5'6èOo ~_,50L___ 1000 1000 TARGET LOCATION: 898' FNL, 915' FWL SEC. 12, T12N, R8E TO LOCATION: 840' FNL, 996' FWL SEC. 12, T12N, R8E - 480 ý' ^ - 420 I Z - 360 0 ., -+ ::r r-".. - 300 ~J '--"" - 240 -180 -120 - 60 &un -~~.............~ '......... 1000 ...,.,........,.". Q),....., ................................... ''-, -"""'''--, '- ",- 2500 i"3ÕÓÕ- 6'O:~~~.... ~. .jOO Jf1¡7Æ.F/!,Q' '\ ~o ~tog~k~Ió'O' 2000 "JV..~ og~1ó' I-¡o/~ rëI _..--,-- ,-- -__~ (j¡ ^ ~. ~, ~-.._h+,15..Q9-,'€P W "" --'-,.._'--_..~~-- 4000 --------,-____ 2000 --------- ------------ - - , "- --.... ----..-----.... '-- '---- - ------------. ---------..,______... 4500 -- -- -'---==8£11 - ------_,_ 5000 --,-_______-,.., --, 10 _ 60 - 0 ) '\ ) ...................................,.................................................................. ..........................................................................................-.............................. ConocoPhillips Alaska, Inc. Created by bmicnael For: Coyner Dot. plott.d : 25-Aug-2003 Plot Reference Ie 3H -1 08 VerelonN 1. Coordinates are in 'eet rererenoe slot #10A. True Vertical Deplhs ore reference RKB (Doyon 141). Structure: Pad 3H Well: 108 ............ ConocoPhillips ............................-.......................-- ,.............................................-..........................-..............-....-....................................... Field : Kuparuk River Unit Location: North Slope, Alaska ..........................................................................._................................................__....................~............n.................._..........__............................ W'@¡¡j¡m .... INTEQ .m.._..........·...·..··......................_.........._._................._............................. TRUE NORTH ~ c=J 350 0 10 340 20 330 280 30 320 40 310 50 300 60 290 70 280 80 40 270 90 260 100 250 1 1 0 240 130 140 210 150 200 160 190 180 170 Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well ORIGINAL - e ConocoPhillips Alaska, Inc. Pad 3H lOB slot #lOA Kuparuk River Unit North Slope, Alaska PRO P 0 S ALL 1ST I N G by Baker Hughes INTEQ Your ref Our ref License 3H-I0B Version#l prop55l6 Date printed Date created Last revised 25-Aug-2003 l-Aug-2003 25-Aug-2003 Field is centred on n70 16 18,576,w150 5 56,536 Structure is centred on n70 24 56.740,w150 ° 47.688 Slot location is n70 24 43,738,w150 0 39.451 Slot Grid coordinates are N 6000335.115, E 498654,289 Slot local coordinates are 1322.00 S 281,00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ORIGINAL e e ConocoPhillips Alaska, Inc. PROPOSAL LISTING Page 1 Pad 3H,10B Your ref 3H-I0B Version#1 Kuparuk River Unit,North Slope, Alaska Last revised : 25-Aug-2003 Measured Inclin, Azimuth True Vert R E C T AN G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/100ft Sect 3550.00 15,72 85,35 3542,32 40,07 N 84,60 E 0,00 92,61 Top Whipstock Face 3562.00 15,83 78 .34 3553.87 40,54 N 87.82 E 15,90 95,54 Base Whipstock Face 3580.00 15,83 78.34 3571.18 41,53 N 92,63 E 0.00 100,09 KOP - End Milled Hole 3600.00 15.45 75,72 3590.44 42.74 N 97,88 E 4.00 105.13 3700.00 14,10 60,91 3687.17 51. 95 N 121. 45 E 4.00 129.84 3742,42 13,83 53.96 3728,34 57,44 N 130.06 E 4,00 140,06 EOC 4000,00 13,83 53.96 3978.45 93,67 N 179,85 E 0,00 201. 58 4500.00 13,83 53,96 4463,95 164.00 N 276,51 E 0,00 321. 02 5000,00 13.83 53.96 4949,46 234.32 N 373,16 E 0,00 440.45 5500,00 13.83 53.96 5434,96 304.65 N 469,81 E 0,00 559,89 5759,16 13,83 53.96 5686,60 341,10 N 519.90 E 0,00 621,79 HRZ 5773,80 13,83 53.96 5700.82 343.16 N 522,73 E 0,00 625.29 Build 6/100 5800.00 15.40 54,00 5726,17 347.05 N 528,08 E 6.00 631.89 5861,19 19.07 54.08 5784,60 357.69 N 542,76 E 6.00 650,01 Kalubik 5900,00 21.40 54,12 5821. 01 365.56 N 553,63 E 6,00 663,43 6000,00 27.40 54,18 5912,04 389,75 N 587.11 E 6.00 704,70 6014,21 28.26 54.19 5924,60 393.63 N 592,49 E 6,00 711,32 C4 6043,28 30,00 54,20 5950,00 401. 91 N 603,96 E 6.00 725.47 EOC 6056.68 30.00 54,20 5961. 60 405,83 N 609.40 E 0.00 732,16 A 6061.30 30.00 54.20 5965,60 407.18 N 611,27 E 0,00 734,47 A3 6085,55 30,00 54.20 5986,60 414,27 N 621.10 E 0.00 746,58 A2 6119.03 30,00 54.20 6015,60 424.07 N 634,68 E 0,00 763,32 3H-I0B ST TGT RVSD 11 JUL 03 6180.23 30,00 54.20 6068,60 441. 97 N 659,50 E 0,00 793,90 Miluveach 6319.03 30.00 54,20 6188,80 482.56 N 715,79 E 0,00 863.25 TD All data is in feet unless otherwise stated, Coordinates from slot #10A and TVD from RKB (Doyon 141) (66.60 Ft above mean sea level), Bottom hole distance is 863,26 on azimuth 56,01 degrees from wellhead, Total Dogleg for wel1path is 24.57 degrees, Vertical section is from wellhead on azimuth 56,25 degrees, Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ORIGINAL e e ConocoPhillips Alaska, Inc, Pad 3H,10B Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref 3H-10B Version#l Last revised : 25-Aug-2003 Comments in wellpath -------------------- -------------------- MD TVD Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------- 3550.00 3542.32 40,07 N 84,60 E Top Whipstock Face 3562.00 3553,87 40,54 N 87,82 E Base Whipstock Face 3580,00 3571.18 41. 53 N 92.63 E KOP - End Milled Hole 3742.42 3728,34 57,44 N 130.06 E EOC 5759,16 5686,60 341.10 N 519,90 E HRZ 5773,80 5700.82 343.16 N 522.73 E Build 6/100 5861.19 5784.60 357.69 N 542,76 E Kalubik 6014,21 5924.60 393.63 N 592,49 E C4 6043.28 5950.00 401. 91 N 603.96 E EOC 6056,68 5961.60 405.83 N 609,40 E A 6061,30 5965.60 407,18 N 611,27 E A3 6085,55 5986.60 414,27 N 621. 10 E A2 6119,03 6015.60 424.07 N 634,68 E 3H-10B ST TGT RVSD 11 JUL 03 6180.23 6068.60 441. 97 N 659,50 E Miluveach 6319.03 6188.80 482,56 N 715,79 E TD Targets associated with this wellpath ------------------------------------- ------------------------------------- Target name Geographic Location T,V,D, Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------- 3H-10B ST TGT RVSD 1 499289,000,6000759.000,0.0000 6015,60 424,07N 634,68E 9-Jul-2003 ORtG1NA e e ConocoPhillips Alaska, Inc. Pad 3H lOB slot #10A Kuparuk River Unit North Slope, Alaska SUM MAR Y C LEA RAN C ERE P 0 R T by Baker Hughes INTEQ Your ref Our ref License 3H-I0B Version#l prop5516 Date printed Date created Last revised 25-Aug-2003 1-Aug-2003 25-Aug-2003 Field is centred on n70 16 18,576,w150 5 56,536 Structure is centred on n70 24 56,740,w150 ° 47,688 Slot location is n70 24 43,738,w150 ° 39.451 Slot Grid coordinates are N 6000335,115, E 498654.289 Slot local coordinates are 1322,00 S 281.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath PMSS <9810-10943'>, ,16A,Pad 3H PMSS <9700-10457'>, ,16APBl,Pad 3H 16 <0 - 9763'>Depth Shifted, ,16,Pad 3H PMSS <461-12044'>,,24,pad 3H 32 <13809'-16000'>, ,32,Pad 3H PMSS <895-14278>, ,32PHl,Pad 3H PMSS <6133 - 7755'>, ,13A,pad 3H PMSS <549 - 14940'>, ,28,Pad 3H PMSS <5706 - 8867'>, ,28A,pad 3H PMSS <7395 - 12575'>, ,28A,Pad 3H PGMS <0-10293'>, ,18,Pad 3H PGMS <0-12410'>, ,25,pad 3H PGMS <0-7370'>, ,13,Pad 3H PGMS <0-9360'>, ,23,Pad 3H PMSS <1743-6660'>, ,26,Pad 3H PGMS <0-8095'>,,4,pad 3H PGMS <0-7987'>,,6,Pad 3H PGMS <0-7750'>, ,11,Pad 3H PGMS <0-7155'>, ,5,Pad 3H PGMS <0-8167'>, ,1,Pad 3H PGMS <0-9555'>, ,3,Pad 3H PGMS <0-8620'>,,7,pad 3H PGMS <0-7310'>,,9,pad 3H PGMS <0-8350'>,,2,pad 3H PGMS <0-8614'>, ,17,Pad 3H PGMS <0-7298'>, ,12,Pad 3H PGMS <0-10234'>, ,22,Pad 3H PGMS <0-11346'>,,21,Pad 3H Closest approach with 3-D Minimum Distance method Last revised 2-May-2002 2-May-2002 2-May-2002 14-Feb-1996 8-Mar-2000 16-Feb-2000 7-Jan-1999 7-Dec-1999 28-Feb-1996 7-Dec-1999 13-Nov-1991 17-Feb-1999 13-Nov-1991 7-Nov-1996 7-Jan-1999 13-Nov-1991 13-Nov-1991 13-Nov-1991 13-Nov-1991 13-Nov-1991 13-Nov-1991 13-Nov-1991 13-Nov-1991 13-Nov-1991 13-Nov-1991 13-Nov-1991 22 -Jul-2 003 13-Nov-1991 Distance 1975.1 1975.1 1975,1 1739,3 1659.6 1659,6 2488,7 1825,4 1825.4 1825,4 1973.9 1709.3 903,8 1687,2 227,2 1514,5 1541. 6 1474,2 1408.2 1868.3 1885.8 1391,4 1340,7 1860,7 1626,7 747.7 2027 . 5 2017,5 M.D, 3550,0 3550,0 3550,0 3550,0 3550.0 3550.0 5180.0 3550.0 3550.0 3550.0 3550.0 3550,0 3550,0 3550.0 3550.0 3550.0 3550,0 3550,0 3550,0 3550.0 3550,0 3550.0 3550.0 3550.0 3550,0 3550,0 3550,0 3550,0 ORIGINAL Diverging from M.D. 3550,0 3550,0 3550,0 3550,0 3550.0 3550.0 5180.0 3550.0 3550,0 3550,0 3550,0 3550,0 3550,0 3550.0 3550.0 3550,0 3550,0 3550.0 3550.0 3550,0 3550,0 3550.0 3550.0 3550,0 3550,0 3550,0 3550,0 3550,0 e PMSS <1506-2076'>, ,20,Pad 3H PMSS <1622-4449'>, ,20,pad 3H PGMS <0-9050'>, ,20,pad 3H PMSS <1506-3878'>, ,20,Pad 3H PGMS <0-8650'>, ,19,Pad 3H PGMS <0-8460'>, ,15,Pad 3H PMSS <12256 - 15240'>, ,25A,pad 3H PMSS <11231' - 14458'>, ,25APB1,Pad 3H PMSS <12259 - 13247'>, ,25APB2,Pad 3H PMSS <7640 - 9875'>, ,23A,pad 3H PGMS <0-10730'>, ,31,Pad 3H PGMS <0-6881'>,,8,Pad 3H PGMS <0-9770'>, ,16,Pad 3H PGMS <0-8250'>, ,14,Pad 3H PMSS <7680-8700'>, ,14APB1,Pad 3H PGMS <0-6785'>, ,10,Pad 3H MWD <6264 - 6365'>, ,10APB1, Pad 3H MWD<6254-6355,6'>DepthShifted,,10APB1,Pad 3H PGMS<0-6775,6'>DepthShifted, ,10,Pad 3H 13-Nov-1991 13-Nov-1991 13-Nov-1991 13-Nov-1991 22-Jul-2003 13-Nov-1991 16-Jul-1999 16-Jun-1999 16-Jun-1999 7-Jan-1999 22-Jul-2003 13-Nov-1991 13-Nov-1991 27-Nov-2002 27-Nov-2002 21-Jul-2003 21-Jul-2003 l-Aug-2003 l-Aug-2003 1934,0 1816,2 1818,5 1816.2 1793.9 1560,0 1709,3 1709.3 1709.3 5440,3 1950,4 586,9 1975,0 1275.6 1275.6 0,0 0,0 0,0 0,0 ORIGINAL e 3550,0 3550,0 3550,0 3550.0 3550.0 3550.0 3550.0 3550,0 3550,0 4880,0 3550,0 3550,0 3550,0 3550,0 3550.0 3550.0 3550.0 3550.0 3550.0 3550,0 3550.0 3550,0 3550.0 3550,0 3550.0 3550,0 3550.0 3550,0 4880,0 3550,0 3550,0 3550,0 3550,0 3550.0 3550,0 3550.0 3550,0 3550,0 · e ConocoPhillips Alaska, Inc. Pad 3H lOB slot #lOA Kuparuk River Unit North Slope, Alaska PRO P 0 S ALL I S TIN G by Baker Hughes INTEQ Your ref Our ref License 3H-IOB Version#l prop5516 Date printed Date created Last revised 26-Aug-2003 l-Aug-2003 25-Aug-2003 Field is centred on n70 16 18.576,w150 Structure is centred on n7Q 24 56.740,w150 56,536 47,688 Slot location is n70 24 43.738,w150 0 39.451 Slot Grid coordinates are N 6000335.115, E 498654.289 Slot local coordinates are 1322.00 S 281.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ORIGINAL e . ConocoPhillips Alaska, Inc. PROPOSAL LISTING Page 1 Pad 3H,10B Your ref 3H-IOa Version#l Kuparuk River Unit, North Slope, Alaska Last revised , 25-Aug-2003 Measured Inclin Az imu th True Vert R E C TANGULA R G RID COO R D S G E o G RAP H I C Depth Degrees Degrees Depth C 0 0 R DIN ATE S Easting Northing C 0 o R DIN A T E S 3550,00 15,72 85,35 3542,32 40,07N 84,60E 498738.89 6000375,17 n70 24 44,13 w150 36,97 3562,00 15.83 78.34 3553,87 40,54N 87,82E 498742,11 6000375,63 n70 24 44.14 w150 36,88 3580,00 15,83 78 ,34 3571.18 41,53N 92.63E 498746,92 6000376,62 n70 24 44,15 w150 36,74 3600.00 15,45 75,72 3590,44 42,74N 97,88E 498752,17 6000377 ,83 n70 24 44,16 w150 36,58 3700,00 14.10 60,91 3687,17 51,95N 121. 45E 498775,73 6000387,03 n70 24 44,25 w150 35,89 3742.42 13 ,83 53,96 3728,34 57 , 44N 130,06E 498784,35 6000392.52 n70 24 44,30 w150 35,64 4000,00 13,83 53,96 3978,45 93,67N 179,85E 498834,14 6000428,74 n70 24 44,66 w150 34,18 4500,00 13,83 53,96 4463,95 164,OON 276.51E 498930.80 6000499,04 n70 24 45,35 w150 31.35 5000,00 13 ,83 53,96 4949,46 234,32N 373,16E 499027,46 6000569,33 n70 24 46,04 w150 28,51 5500,00 13,83 53,96 5434.96 304,65N 469,81E 499124,12 6000639,63 n70 24 46.73 w150 25,68 5759,16 13,83 53,96 5686,60 341,10N 519,90E 499174,22 6000676,07 n70 24 47.09 wISO 0 24,21 5773,80 13,83 53,96 5700,82 343 .16N 522,73E 499177,05 6000678 .13 n70 24 47,11 wISO 0 24,13 5800,00 15,40 54,00 5726,17 347,05N 528,08E 499182,39 6000682,01 n70 24 47,15 w150 ° 23,97 5861.19 19,07 54,08 5784,60 357,69N 542,76E 499197,07 6000692,65 n70 24 47,26 w150 0 23,54 5900,00 21. 40 54.12 5821. 01 365.56N 553,63E 499207,95 6000700,52 n70 24 47.33 w150 ° 23,22 6000,00 27,40 54,18 5912,04 389,75N 587.11E 499241.42 6000724,70 n70 24 47,57 w150 0 22.24 6014 ,21 28,26 54,19 5924,60 393,63N 592,49E 499246,80 6000728,58 n70 24 47,61 w150 ° 22,08 6043,28 30.00 54,20 5950,00 401. 91N 603,96E 499258,28 6000736,85 n70 24 47,69 w150 0 21. 75 6056,68 30,00 54,20 5961. 60 405,83N 609,40E 499263,71 6000740.77 n70 24 47,73 w150 ° 21. 59 6061.30 30,00 54,20 5965.60 407,18N 611,27E 499265,59 6000742,12 n70 24 47.74 w150 0 21. 53 6085,55 30,00 54,20 5986,60 414,27N 621,10E 499275,42 6000749,21 n70 24 47,81 w150 ° 21 .24 6119,03 30,00 54,20 6015,60 424,07N 634.68E 499289,00 6000759,00 n70 24 47,91 w150 0 20 ,84 /6180,23 30,00 54,20 6068,60 441,97N 659,50E 499313,82 6000776,89 n70 24 48,08 w150 0 20.12 6319,03 30,00 54,20 6188,80 482,56N 715,79E 499370,11 6000817,47 n70 24 48.48 w150 0 18,47 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #lOA and TVD from RKB (Doyon 141) (66.60 Ft above mean sea level). Bottom hole distance is 863.26 on azimuth 56.01 degrees from wellhead. Total Dogleg for wellpath is 24.57 degrees. Vertical section is from wellhead on azimuth 56.25 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ORIGI-NAL e . ConocoPhillips Alaska, Inc. Pad 3H, lOB Kuparuk River Unit, North Slope, Alaska MD TVD ----------------------------------------------------------------------------------------------------------- 3550,00 3562,00 3580,00 3742,42 5759,16 5773,80 5861.19 6014,21 6043,28 6056,68 6061. 30 6085,55 6119,03 6180.23 6319.03 3542,32 3553,87 3571.18 3728,34 5686,60 5700,82 5784,60 5924,60 5950,00 5961,60 5965,60 5986,60 6015,60 6068,60 6188,80 Target name PROPOSAL LISTING Page 2 Your ref 3H-IQB Version#l Last revised : 25-Aug-2003 Comments in wellpath -------------------- -------------------- Rectangular Coords. 40,07N 40.54N 41. 53N 57.44N 341.10N 343,16N 357,69N 393,63N 401,91N 405,83N 407,18N 414.27N 424,07N 441,97N 482,56N Comment 84.6GE Top Whipstock Face 87.82E Base Whipstock Face 92.63E Kep - End Milled Hole 130,06E EOC 519,90E HRZ 522,73E Build 6/100 542,76E Ka1ubik 592,49E C4 603,96E EOC 609.40E A 611.27E A3 621.10E A2 634.68E 3H-10B ST TGT RVSD 11 JUL 03 659.50E Miluveach 715,79E TD Targets associated with this wellpath ------------------------------------- ------------------------------------- Geographic Location Rectangular Coordinates Revised T.V.D. ----------------------------------------------------------------------------------------------------------- 9-Jul-2003 3H-10B ST TGT RVSD 1 499289.000,6000759,000,0,0000 6015,60 424,07N 634,68E ORIGINAL e e ~ Conacal' Ilips KRU - 3H-10A Injector f !r ~ ~ I ~ ~ ~ ~ ~ ~ 16"x30" ~ ~ '- ~ I i! ~ ~ ~ insulated ¡j í!J '- '- I ~ conductor @ I í!J ~ ~ I ~ ..J ~ ~ ~ ~ L... +1-115' MD I ~ ~ ~ I I ~ ~ ~ ~ i! í!! ~ I ~ í!! ~ ~ R í!! ~ I ~ I .. ~ z i!J I '- ~ I ~ ~ I I I I ~ ~ II~ ~ ~ ~ 9-5/8" 36# J-55 3024' MD ~ ~ '- ~ ~ ... ~ ~ '- ~ ~ '- ~ ~ ~ ~ ~ ~ ~ ~ III) ~ ~ ~ I ~ ~ ~ ~ ~ ~ ~ ~ ... ~ ~ ~ ~ '- ~ ~ ~ ~ ~ ~ ~ ~ ~ III) ~ I ~ ~ ~ '- '- ~ '- ~ '- ~ III) ~ ~ ~ ~ ~ '- ~ ~ ~ ~ ~ ~ ~ .... '- I ~ ~ '- '- ~ ~ ~ .. ~ I ~ I I ~ I '- ~ '- I ~ PBR: 6172' - 6186' MD I ~ I ~ l I PKR: 6186' - 6193' MD 6300' MD 7" 26# J-55 6763' MD 6327' TVD r ------ F r '- ,,¡¡ 3-1/2" FMC Gen IV tubing hanger: 7-1/16" x 5000# Flange Up 3-1/2", L-80, 9,3# EUE8RD Spaceout Pups as Required, Special Drift 2.91" 3-%" OTIS Series 10 SSSV: at 1793' MD, 33 stainless Bands Valve #1: 3-1/2" x 1" CAMCO KBUG wI DMY: at 2242' MD Valve #2: 3-1/2" x 1" CAMCO KBUG wI DMY: at 3630' MD Valve #3: 3-1/2" x 1" CAMCO KBUG wI DMY: at 4427' MD Valve #4: 3-1/2" x 1" CAMCO KBUG wI DMY: at 4707' MD Valve #5: 3-1/2" x 1" CAMCO KBUG wI DMY: at 5238' MD Valve #6: 3-1/2" x 1" CAMCO KBUG wI DMY: at 5477' MD Valve #7: 3-1/2" x 1" CAMCO KBUG wI DMY: at 5820' MD Valve #8: 3-1/2" x 1-1/2" OTIS Merla wI DMY: at 6127' MD 1 Joint 3-1/2", J-55, 9,3# EUE 8rd Mod x 30,27', 1 Pup Joint 3-1/2", J-55, 9,3# EUE 8rd Mod x 6,10' Baker '80-40' PBR. Previoualy Sheared Baker 7" x 3-1/2" 'FHL' Packer. Min ID through the PKR = 2.992". Tailpipe Cut Off at 6202' MD: Fish fell to bottom CTD Window at 6270' MD. Shale Collapsed. Abandoned Sidetrack. --. Baker Inflatable TTRtnr Kuparuk D Sand: 6348' - 6356' MD Kuparuk C Sand: 6362' - 6450' MD Kuparuk A Sand: 6480' - 6510' MD TO @ 7946' MD 16101' TVD (300' MD below Miluveach) ORIGINAL Skip Coyner 6/27/03 e ~cóPhillips KRU - 3H-10B De-Complete I i :r I I i I ~ ~ í!: ~ ~ í!: i ~ .3 i ~ .- !íJ ~ !ì! ~ !!! ~ f!j ~ i ~ i ~ f!j ~ ~ ~ i; ~ !!! ~ !ì! ~ ~ ~ .....1 ~ 9-5/8" 36# J-55 3024' MD ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ r f ( l Z ~ ~ ¡ ~ f!j ¡ I I ¡ ~ I L... ~ a: ~ ~ ~ ~ ~ [§ ~ ~ I I I I ~ z ~ I ~ f!j ~ I I i!J......... ~ ~ ~ ~ ~ ~ ~ ~ I ~ ~ I ~ 16"x30" insulated conductor @ +/-115' MD PBR: 6172' - 6186' MD ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ I ~ ~ ~ ~ ~ ~ ~ ~ ~ l PKR: 6186' - 6193' MD 7" 26# J-55 6763' MD 6327' TVD Perforate squeeze holes at 3610-12' MD Set RTNR at +/- 3584' on E-Line Block Squeeze w/1 00-200 sx Class "G" Cut and Pull the Tubing at above 6000' MD Valve #8: 3-1/2" x 1-1/2" OTIS Merla wI DMY: at 6127' MD 1 Joint 3-1/2", J-55, 9,3# EUE 8rd Mod x 30,27'. 1 Pup Joint 3-1/2", J-55, 9.3# EUE 8rd Mod x 6,10' Baker '80-40' PBR. Previoualy Sheared Baker 7" x 3-1/2" 'FHL' Packer. Min ID through the PKR = 2.992". Tailpipe Cut Off at 6202' MD: Fish fell to bottom CTD: P & A the CTD Sidetrack. CTD Window at 6270' MD. Shale Collapsed. Baker Inflatable TTRtnr Kuparuk D Sand: 6348' - 6356' MD Kuparuk C Sand: 6362' - 6450' MD Kuparuk A Sand: 6480' - 6510' MD TO @ 7946' MD 16101' TVD (300' MD below Miluveach) ORIGINAL Skip Coyner 6/27103 e KRU - 3H-10B Whipstock 16"x30" insulated conductor @ +/-115' MD 9-5/8" 36# J-55 3024' MD ToplWhipstock: at 3562' MD EZSV: 3584' MD PBR: 6172' - 6186' MD PKR: 6186' - 6193' MD Inflatable TTRtnr : 6300' MD 7" 26# J-55 6763' MD 6327' TVD Ii! § ~ ¡¡¡ § ~ '" Z ~ Z z . '" Z . Z Z · '" Z . Z Z ~ ~ ~ l -' ~ ~ ~ ~ ~ ~ I~ æ I I I ~ ~ I ~§ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ · ~Ph· ..... ·1·1··· Conoco.·· ... II IpS I § § '-! '-! '-! '-! I § § ~ I § § L. !i1 I L LOT > 13.0 ppg \ \ / / Kuparuk (3H-10A) D Sand: 5974' - 5981' TVD C Sand: 6986' - 6061' TVD A Sand: 6087' - 6112' TVD TD @ 7946' MD 16101' TVD (300' MD below Miluveach) ORIGINAL Skip Coyner 7/07/03 e KRU - 3H-108 Sidetrack Hole \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ TD @ +1- 6319' MD /6189' TVD \ (TD 200' MD below Kuparuk A-sand) I ~ ~ 7. :2 ¡¡¡ ~ ~ I ~ ! I 16"x30" ~ ~ I ~ ~ ~ ~ I ~ insulated ~ II! ~ ~ ~ § ~ II! ~ § conductor @ ..4. § ~ I § h.. +/-115' MD § ~ ~ ¡¡¡ I ~ ~ I ~ ~ ~ ~ ~ I ¡¡j ~ ~ ~ I I ~ ~ ~ ~ ~ i ~ ~ ¡¡¡ ~ ~ I I ~ ~ f!! § ~ ~ II! -..J ~ ~ II! I ~ ..... I ~ 9-5/8" 36# J-55 3024' MD ~ ~ I ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ToplWhipstock: at 3562' MD EZSV: 3584' MD PBR: 6172' - 6186' MD PKR: 6186' - 6193' MD Inflatable TTRtnr: 6300' MD ~ r ~ ~ I 7" 26# J-55 6763' MD 6327' TVD e .. .... - eonocJPhillips Drill 6-1/8" Hole thru the Kuparuk sands & TD in the Miluveach shale +/- 6319' MD /6189' TVD. Expected MW ::::: 11.7 ppg OR'GI~JAL Skip Coyner 7107103 e KRU - 3H-10B Liner !'i: ~ ~ ¡ ~ ~ I ~ ~ g ~ ~ I fiJ ~ ~ i i ¡;¡ ~ f!: ~ f!: ~ .. ~ ¡ ~ I I ~ ~ I ~ ~ i ¡¡¡ ~ J ~ ......IIIIii.ì! ~ ~ 9-5/8" 36# J-55 3024' MD ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 16"x30" insulated conductor @ +1-115' MD +1- 3400' MD ToplWhipstock: at 3562' MD EZSV: 3584' MD PBR: 6172' - 6186' MD PKR: 6186' - 6193' MD Inflatable TTRtnr: 6300' MD 7" 26# J-55 6763' MD 6327' TVD e .~ ConocoPhil IIi ps I ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ;.; .;11 ;"'il'~"T-' I I I ¡¡¡ ¡¡¡ ~ I I I ¡¡¡ ¡¡¡ ~ ~ ~ I II ¡¡¡ § ~ l. FlexLock, ZXP Liner Top Packer & 80-47 PBR 4-%" NSCT & 1ST-mod Liner set thru the Kuparuk (see Well Plan for details) Hole Angle 13° to 150 Built to 300 at T/Kuparuk C- sand +1- 6014' MD 1 5925' TVD ~ ~ ~ ~ TD @ +1- 6319' MD 16189' rvD (TD 200' MD below Kuparuk A-sand) ORIGINAL Skip Coyner 7107103 e KRU - 3H-10B Completion ~illiþS m- !2 ~ E E , E E ~ E E ~ jE i ~ I ~ ~ ~ § ~ ~ , iiæ , § ~ ~ i § ~ !!! ~ ~ ~ ~ ~ ~ ~ ~i ~ ~ ~ 9-5/8" 36# J-55 3024' MD ~ ~ ~ ~ ~ ~ ~ ~ ~ i +/- 3400' MD T. m- ¡ I i E '- E ~ jjJ ~ 111 ~ ~ i I ~ æ i I ~ Zl ~ ~ i I ~ ~ ~ ~~ ~ ~ ~ ~ ~ ~ J. ~ ~ '- i f I I L. 4-1/2" FMC Gen IV tubing hanger, 4-Y:z" L-80 1ST-mod pin down, 4-1/2", L-80, 12,6#, 1ST-mod Spaceout Pups as Required, 16"x30" insulated conductor @ +1-115' MD 4-%", 12.6#, L-80, IBT-mod Tubing (see Well Plan for details) FlexLock, ZXP Liner Top Packer & 80-47 PBR ToplWhipstock: 3562' MD 4-%" NSCT & 1ST-mod Liner set thru the Kuparuk (see Well Plan for details) EZSV: 3584' MD PBR: 6172' - 6186' MD PKR: 6186' - 6193' MD \<N\~ q,s'ù Inflatable TTRtnr : 6300' MD 7" 26# J-55 6763' MD 6327' TVD TD @ +1- 6319' MD 16189' TVD (TD 200' MD below Kuparuk A-sand) ORIGINAL Skip Coyner 7/07/03 e e KRU - 3H-1 OB Completion - Revised Conoc6Phillips ~ 16"x30· ~ Insulated ~ conductor @ .J +/-11S'MD n L ! ~ ¡ I SSSV profile I ~LZ ~ ! ! ! ¡ 4-%" NSCT Tubing ! ! ! ! ! J I GLM ! f ! ! ! ! ! I ! I i I 9-5/8" 36# J-55 3024' MD I I I ! . Baker HMC, ZXP & 80-47 PBR ToplWhipstock: 3562' MD EZSV: 3584' MD 4-%" NSCT Liner set thru the Kuparuk PBR: 6172' - 6186' MD PKR: 6188'·6193' MD A & C Sand perfs 7" 26# J-55 6763' MD 6327' TVD Johnny Golden 9/29/03 <í,so-o ~ e 3H-IOB Liner Detail No. 1 ea 1 ea 1 ea 60 ea 1 ea 23 ea 1 ea 1 ea 1 ea 9 ea 1 ea 2 ea 1 ea 2 ea 1 ea Item 5" x 7" ZXP Liner Packer wi 5" x 10' PBR 5" x 7" FlexLock Liner Hanger: 5" BTC pin Crossover: 5" BTC box X 4-1/2" NSCT pin 4-1/2", 12.6#, L-80, NSCT, R-2 (get rid of inventory) Crossover: 4-1/2" NSCT box X IBT pin 4-1/2", 12.6#, L-80, IBT-Mod, R-2liner joints 4-1/2", 12.6#, L-80, IBT-Mod Pup Joint 4-1/2" "X" Nipple, IBT (Selective, 3.813" Bore) 4-1/2", 12.6#, L-80, IBT-Mod Pup Joint 4-1/2", 12.6#, L-80, IBT-Mod, R-2liner joints 4-1/2", 12.6#, L-80, IBT Landing Collar 4-1/2", 12.6#, L-80, IBT-Mod, R-2liner joints 4-1/2", 12.6#, L-80, IBT-Mod Float Collar 4-1/2",12.6#, L-80, IBT-Mod, R-2liner joints 4-1/2", 12.6#, L-80, IBT-Mod, R-2 Float Shoe 3H-IOB Tubing Detail No. 1 ea 1 ea 15 ea 1 ea 1 ea 1 ea 94 ea 1 ea 1 ea 1 ea 1 ea 1 ea 1 ea 1 ea 1 ea 1 ea Item 4-1/2", 12.6#, L-80 Landing joint FMC, Gen IV, 4-1/2" Tubing Hanger + pups 4-1/2",12.6#, L-80, IBT-Mod, R-2 tubing 4-1/2", 12.6#, L-80, IBT Pup Joint 4-1/2" "X" Nipple, IBT (Selective, 3JH3" ID) 4-1/2",12.6#, L-80, IBT Pup Joint 4-1/2", 12.6#, L-80, IBT-Mod, R-2 tubing 4-1/2", 12.6#, L-80, IBT Pup Joint 4-1/2" xl" KBG-2 GLM wi Shear valve 4-1/2", 12.6#, L-80, IBT Pup Joint 4-1/2",12.6#, L-80, IBT, R-2 tubing joint 4-1/2", 12.6#, L-80, IBT Pup Joint 4-1/2" "X" Nipple, IBT (Selective, 3.813" ID) 4-1/2", 12.6#, L-80, IBT-Mod Pup Joint X-O: 5" LTC pin x 4-1/2" IBT-Mod box PBR "Bullet" Seals with 5" LTC box up ORIGINAL e Length 14.0' 6.0' 2.0' 1800.0' 3.0' 690.0' 8.0' 2.0' 8.0' 270.0' 2.0' 60.0' 3.0' 60.0' 3.0' Length 30.0' 10.0' 450.0' 10.0' 2.0' 10.0' 2820.0' 10.0' 5.0' 10.0' 30.0' 10.0' 1.0' 10.0' 3.0' 12.0' Notes TOl = 3400' 5" BTC pin down GKA #10637705 GKA #10527842 GKA #10535630 + cplg GKA #10542463 GKA #10542482 GKA #10541991 GKA #10542482 GKA #10542463 GKA #10643747 GKA #10542463 GKA #10643745 GKA #10542463 GKA #10643746 Supplier GKA Inventory GKA #10616626 GKA #10542463 GKA #10542484 GKA #10541991 GKA #10542484 GKA #10542463 GKA #10542484 Cameo (or Alpine stock) GKA #10542484 GKA #10542463 GKA #10542484 GKA #10541991 GKA #10542484 Need to cut this X-O Baker e 7",26# X 5" ZXP Liner Top Packer w/10Ft. 5.25" IC Tieback Extension 5" RS Nipple 7", 26# X 5" FLEX LOCK Rotating Liner Hanger w/ 5" BTC . down pin X-O: 5" BTCB X 4-1/2" NSCT . ox pin xx jts 4-1/2" 12.6# NSCT Liner X-O: 4-%" NSCT box X IBT-M pin xx jts 4-%", 12.6# IBT-M Liner w/ a 3.813" "X" nipple above the Kuparuk Landing Collar w/4-%" IBT-M 2 Jts 4-%" IBT-M Liner Float Collar w/4-1/2" IBT-M 2 Jts 4-%" IBT-M Liner Float Shoe: 4-1/2" IBT Co-'ocÓPhillips LINER SCHEMATIC 3H-108 OR1G\N,AL 3-1/2" Drill Pipe to Surface Rotating Dog Sub HR Running Tool RS Packoff 4- %" Liner Wiping Plug 7-29-03- Drawn by Jose Iguaz, At +1- 500 ft e e ~ Conoco ililis COMPLETION SCHEMATIC 3H-10B 4-1/2" NSCT Completion Tubing 4-%" 18T Box Pup Joint x 10 ft (#10542484) "X" Nipple, 3.813", 18T, (#10541991) 4-%" 18T Box Pup Joint x 10 ft (#10542484) XXX Joints 4-1/2" 18T Completion Tubing 4-%" 18T Box Pup Joint x 10 ft (#10542484) 4-%" X 1" Camco K8G-2 Gas Lift Mandrel wI shear Valve 4-%" 18T Box Pup Joint x 10 ft (#10542484) 1 Joint 4-1/2" 18T Tubing (#10542463) 4-%" 18T Box Pup Joint x 10 ft (#10542484) "X" Nipple, 3.813", 18T, (#10541991) 4-%" 18T Box Pup Joint x 10 ft (#10542484) x-o: 4-%" 18T Box x 5" L TCpin [make this X-OJ or [add a 5" Obi pin (LTC x STC) & a 4-%" 18T cplg to #10541943] 10 ft. X 5.25" OD 8ullet Seal Assembly wI 5" LTC 80x Up OR\G\N,A, N ~ C~ N \ Re: 3H-IOb, Rotary Sidetrack e e Subject: Re: 3H-I0b, Rotary Sidetrack From: Tom Maunder <tom_maunder@admin.state.ak.us> Date: Thu, 31 Jul 2003 10:09: 18 -0800 To: Vern M Coyner <Vem.M.Coyner@conocophillips.com> Skip, Thanks for sending the slideshow in the ppt format. This well is possible as you plan, but it may take a special letter. The injection well regs and the Kuparuk injection order have provisions to allow "alternate construction" since there are no aquifers up there. You indicated that the new liner would be cemented throughout its length and that you would obtain a bond log. You also indicated that a nipple profile would be provided about 100' or so above the proposed perforations to allow MITing the tubing and liner. Placement of that nipple should try to consider where Dan might do his future sidetrack. According to our records, 3H-IOA is suspended. this suspended well and conduct the abandonment to permit the coil and "early rig" activities. Thanks for running this by. Good luck with the Tom Maunder, PE AOGCC You will need a 403 to re-enter operations. 1 403 could be used Then the 401 would take over. project. Vern M Coyner wrote: This proposed rotary sidetrack is not difficult but there are some issues that must be addressed. The plan is to sidetrack out of the 7" casing to a suitable location "inboard" of the original location. Later (2004 ?) the well will be sidetracked again by CTD and a horizontal wellbore will traverse the major fault, etc. To facilitate a successful CTD sidetrack, the rotary sidetrack is planned to be completed as a 4-1/2" monobore. This is an injector, which will require at least a temporary waiver to ACC 20.25.412 (b). in order to inject, right? The liner will be perf'd at ± 6130' MD and the ZXP will be at 3400' MD. So, is a waiver (temporary) feasible or am I just wasting time? Will a real good CBL make a difference? Will periodic liner MIT's make a difference? In a nutshell, what's the procedure for getting a waiver to ACC 20.25.412 (b) ? Skip Coyner 907-265-6074 ofc 907-748-3689 cell (See attached file: Project Slideshow.vsd) ------------------------------------------------------------------------ Name: Project Slideshow.vsd Project Slideshow.vsd Type: unspecified type (application/octet-stream) Encoding: base64 e e KRU - 3H-1 OA Injector 16"x30" insulated conductor @ +1-115' MD J r l .. L J8t ..., ~ ~ .., laB 1BJ ... 1 J 9-5/S" 36# J-55 3024' MD PBR: 6172' - 6186' MD PKR: 6186' - 6193' MD 6300' MD 7" 26# J-55 6763' MD 6327' TVD 3-1/2" FMC Gen IV tubing hanger: 7-1/16" x 5000# Flange Up 3-1/2", L-80, 9,3# EUE8RD Spaceout Pups as Required. Special Drift 2.91" 3-'1:." OTIS Series 10 SSSV: at 1793' MD, 33 stainless Bands Valve #1: 3-1/2" x 1" CAMCO KBUG wI DMY: at 2242' MD Valve #2: 3-1/2" x 1" CAMCO KBUG wI DMY: at 3630' MD Valve #3: 3-1/2" x 1" CAMCO KBUG wI DMY: at 4427' MD Valve #4: 3-1/2" x 1" CAMCO KBUG wI DMY: at 4707' MD Valve #5: 3-1/2" x 1" CAMCO KBUG wI DMY: at 5238' MD Valve #6: 3-1/2" x 1" CAMCO KBUG wI DMY: at 5477' MD Valve #7: 3-1/2" x 1" CAMCO KBUG wI DMY: at 5820' MD Valve #8: 3·1/2" x 1-1/2" OTIS Merla wI DMY: at 6127' MD 1 Joint 3-1/2", J-55, 9,3# EUE 8rd Mod x 30,27', 1 Pup Joint 3-1/2", J-55, 9,3# EUE 8rd Mod x 6,10' Baker '80-40' PBR. Previoualy Sheared Baker 7" x 3-1/2" 'FHL' Packer. Min ID through the PKR = 2.992". Tailpipe Cut Off at 6202' MD: Fish fell to bottom CTD Window at 6270' MD. Shale Collapsed. Abandoned Sidetrack. Baker Inflatable TTRtnr Kuparuk D Sand: 634S' - 6356' MD Kuparuk C Sand: 6362' - 6450' MD Kuparuk A Sand: 64S0' - 6510' MD TO @ 7946' MD /6101' TVD (300' MD below Miluveach) Skip Coyner 6/27/03 e e conoclPbnups KRU - 3H-10B De-Complete 16"x30" insulated conductor @ +1-115' MD J'" I ~ I ~ 9-518" 36# J·55 3024' MD PBR: 6172' - 6186' MD PKR: 6186' - 6193' MD 6300' MD 7" 26# J-SS 6763' MD 6327' 1VD ~ 3-1/2" FMC Gen IV tubing hanger: 7-1/16" x 5000# Range Up 3-112", L-80, 9,3# EUE8RD Spaceout Pups as Required, Special Drift 2.91" ~ Perforate squeeze holes at 3610-12' MD Set RTNR at +/- 3584' on E-Une Block Squeeze w/1 00-200 sx Class Cut and Pull the Tubing at above 6000' MD Valve #8: 3-1/2" x 1-1/2" OTIS Merla wI DMY: at 6127' MD 1 Joint 3-112", J-55, 9.3# EUE 8rd Mod x 30.27', 1 Pup Joint 3-1/2", J-55, 9,3# EUE 8rd Mod x 6,10' Baker '80-40' PBR Previoualy Sheared Baker 7" x 3-1/2" 'FHL' Packer. Min ID through the PKR = 2.992". Tailpipe Cut Off at 6202' MD: Fish fell to bottom CTD: P & A the CTD Sidetrack. CTD Window at 6270' MD. Shale Collapsed. Baker Inflatable TrRtnr Kuparuk D Sand: 6348' - 6356' MD Kuparuk C Sand: 6362' . 6450' MD Kuparuk A Sand: 6480' - 6510' MD TD@ 7946' MD/6101' 1VD (300' MD below Miluveach) Skip Coyner 6/27/03 e e KRU - 3H-10B Whipstock 16"x30" insulated conductor @ +/-11S'MD J , 9-5/8" 36# J-55 3024' MD ToplWhipstock: at 3562' MD J...........'.... , 3584' MD PBR: 6172' - 6186' MD PKR: 6186' - 6193' MD Inflatable TTRtnr : 6300' MD 7" 26# J-55 6763' MD 6327' TVD L 3-1/2" FMC Gen IV tubing hanger: 7-1/16" x 5000# Flange Up 3-1/2", L-80, 9,3# EUE8RD Spaceout Pups as Required, Special Drift 2.91" LOT :> 13.5 ppg \ \ / / Kuparuk D Sand: 5974' - 5981' TVD C Sand: 6986' - 6061' TVD A Sand: 6087' - 6112' TVD TO @ 7946' MD /6101' TVD (300' MD below Miluveach) Skip Coyner 7/07/03 e KRU - 3H-10B Sidetrack Hole L 3-1/2" FMC Gen IV tubing hanger: 7-1/16" x 5000# Flange Up 3-1/2", L-80, 9,3# EUE8RD Spaceout Pups as Required, Special Drift 2.91" \ \ \ \ \ \ \ \ \ \ \ Expected MW= 11.7 ppg \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ KUDaruk \ D Sand: 5974' - 5981'1VD \ \ \ \ \ ~ r r , 16"x30" insulated conductor @ +/-115' MD ~ ~ 9-518" 36# J-55 3024' MD Top/Whipstock: at 3562' MD EZSV: 3584' MD PBR: 6172' - 6186' MD PKR: 6186' - 6193' MD Inflatable TTRtnr : 6300' MD 7" 26# J-55 6763' MD 6327' TVD C Sand: 6986' - 6061' TVD A Sand: 6087' - 6112' TVD TD@ 7946' MD /6101' lVD (300' MD below Miluveach) e CGntKò))¡,nlips Drill 6-1/8" Hole thru the Kuparuk sands & TD in the Miluveach shale. Skip Coyner 7/07/03 e e KRU - 3H-1 OB Liner ConOG· 16"x30" insulated conductor @ +/-115' MD J~ 9-5/8" 36# J-55 3024' MD +/- 3400' MD ToplWhipstock: at 3562' MD EZSV: 3584' MD PBR: 6172' - 6186' MD PKR: 6186' - 6193' MD Inflatable TTRtnr : 6300' MD 7" 26# J-55 6763' MD 6327' TVD l 3-1/2" FMC Gen IV tubing hanger: 7-1/16" x 5000# Flange Up 3-1/2", L-BO, 9.3# EUEBRD Spaceout Pups as Required, Special Drift 2.91" L FlexLock, ZXP & 80-47 PBR 4-%" NSCT Liner set thru the Kuparuk Hole Angle 13° to 15° Built to 30° at T/Kuparuk Kuparuk D Sand: 5974' - 5981' TVD C Sand: 6986' - 6061' TVD A Sand: 6087' - 6112' TVD TO @ 7946' MD /6101' TVD (300' MD below Miluveach) Skip Coyner 7/07/03 e KRU - 3H-10B Completion 16"x30" J insulated conductor @ +/-115' MD III e illips 3-1/2" FMC Gen IV tubing hanger: 7-1/16" x 5000# Flange Up 3-1/2", L-80, 9,3# EUE8RD Spaceout Pups as Required, Special Drift 2.91" :~ L 9-5/S" 36# J-55 3024' MD 4-%" NSCT Tubing +/- 3400' MD Baker HMC, ZXP & 80-47 PBR Top/Whipstock: 3562' MD EZSV: 3584' MD PBR: 6172' - 6186' MD PKR: 6186' - 6193' MD Inflatable TTRtnr : 6300' MD TO @ 7946' MD /6101' TVD (300' MD below Miluveach) 7" 26# J-55 6763' MD 6327' TVD 4-W' NSCT Liner set thru the Kuparuk Skip Coyner 7/07/03 e e .~ KRU - 3H-10C COno(oPttil Ii ps f +/- 3400' MD +/- 3562' MD Future CTD Horizontal Sidetrack ....... ~ e e ¡¡ . ~ . 1.~~I: 21.B~? 1.t10?t1 2?b "~""'$;m.~"~'f'~J»'~~~&~"'1?>lfi'il!fci MEMO o CHASE 200W~ II 1.00 2 · e TRANSMITAL LETTER CHECKLIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER KR-U 311 -loB 2-03-/{dj WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) PILOT (PH) "CLUE" The permit is for a new wellbore segment of existing well ~ Permit No, API No. Production should continue to be reported as a function· of the original API number stated above. HOLE In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 ajody\tempJates The permit is approved subject to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing . exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. on Date: /o/;D , Geologic Commissioner: Engineering Commissioner: Date Public Commissioner Date Appr SFD 35 36 Date 37 9/16/2003 38 39 Conta_ct flamelphofleJorweelsly progre~s rep,ort$ _Seabed wfldjtioo survey Jif Permit cao be Issued w{o_ hydrpgen_ s_ulfide measures D_ata_ preseoted on ROte_ntial over¡1res_sure _zOfles Belsmic_analysjs_ of shaJlow gas_zpoes oft-shore) [explorato¡y _onlyt No Yes NA NA NA Receot Expected reservoir preSSUJe is range from 25 to 185 PRm tl2S. A ppg EMW; will be drjlled with t 1,7 Rpg mud._ Geology 32 33 34 Is presence_ of Meçf:1aJ1lcalcoodjtipo of wens within AOR verified (For_s_ervlce Well Oflly) Appr Date ';1~ 18 19 20 21 22 23 24 25 26 27 28 29 30 31 H2S gas Rrobable to _Cholsemanjfold com plies_ w/APLRf'-53 (May 84) Work will occJJr withoutoperation _sbutdown BOPEs._ dp _they meet regulation. _BOPE_press ra_tiog appropriate; _test (Ru_t PSig in_commen.!$) NA Yes Yes Yes Yes Yes No_ NA measurements_ io Si)( offs_et produ_cers _1 Exceptioo for packerdeptb 25.4121cj RigJs eQ.uipped with sen.sQrs and alarms. require_d, See emaiLoJ1other conditions._ Mud should pr:eclude_ H2_S_ oJ1_rig._ MASI? calculated at 284~ psi, 35QOPSi appropriate_. PP_Co lilsely to te_st to 50QO_ ps Drilliog flujd_ p,rogram schematic & equip listadeQ.uate Adequ¡1te wellbore_ separatjon proposed it meet regulation.s_ Ifdjverter req_uired, does C. Adequ¡1teJan_kageoJ re_seIYe pit If a_ re-ddll~ has a_ 10-403 for abandOflment beeo approved _CMT_will coYer_all _Casiog de_signs ad_eClua_te for T~ B _&_ p,ermafmst kn.own pr~uctiYe hori~Qn_s known USDWs _CMT vQL adeQu_ate_ to circ_ulate _ on tie-In _CMT vol adeQu_ate to long _string to_SUG ~g _Cpodu_ctor _S_urface _casing pJotects all _con.d_uctoc& su_rf_CSg Yes NA Yes Yes Yes Yes Yes Yes Yes BOI? wiJl Þe instalJe_d Jor _all operatioos_. Max pote.ntial BtlP J 1 AEMW. _l?laflned MW 1 U aUD, 30_3:273 isrecomm_eode_d JQr _apprOllal I?roximlty an¡1lysis pertorme_d, to P_&AJhe_'ower welJbore. No _close approach_es ideottfied Traveliflg cylinderplo_t included, Rig js_e_quippe_dwitb steelpi!$. _No reseJlle_pjtplann.ed, WasteJo an approved_ annulus Qrdisposal weJI. CI?A plan.sJo cement Surtaœ casing set with orjgjnal well, the liner Oller ii's entire_leflgth_. Engineering stdfl~Lprovided Appr - 9/16/2003 Date Unique welL EiIi~f~#~:;~ Field & Pool KUPARUK RIVER. KUPARUK RV OIL P 031600 Company CONOCOPHILLlPS ALASKA INC Administration Permit fee attached Operator only affected party _Qper_ator bas appropriate_ bond _Sufficieflt acreage_available in_drilliog unit If deviated in.cluded Well Wen Well located in_a d_efine_d pool located pmper distance_ from driJling unitbQunda¡y_ Jocated pmperdlstance_ from otheJ wells 12 13 14 15 16 17 2 3 4 5 6 7 8 9 10 11 Sidetrack Of an existing well. Area ~Qn_e jdentined ACMPFjflding of Consisteocy_has beenjssued for_ this prJ:>iect In Jorce Permit cao be Issued witbout conservaJiOfl order Pe(Tl]it can be issued without ad_ministratilleapprovaJ _Cao permjt Þe apPJoved before J 5-day_ wajt WellJocated wlthifl area afldstrata autborlzed by lojectioo Order # (put 10# All welJs_ within _1l4mitearea_of review jdeotified (For servjce well only) _ _ Pre-produ~ed injector; duration_of pre-production. less_ than_ 3 months_ (For js_ weJlbore plat Lease _numberapRrORriate n_ame _and oumb_er 490100 nitial ClasslType Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes No_ NA ,A.I aquifeJS exempted ~O CrR Sidetrack ofe~istlng well. 147.102(b}(3) ser:vice welt Qnly) in_ commeots}_ (For_ Injectjon_QrdeJ No._2.B~ December_12, 2002 Con_selYatioo Ord_er f\Jo. _4328 Well Name: ~UPARUK RIV UNIT SER I PEND GeoArea 890 3H-10B Unit 11160 Program SER On/Off Shore On _ Well bore seg Annular Disposal o o e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. **** REEL HEADER **** LDWG 04/07/12 AWS 01 **** TAPE HEADER **** LDWG 04/07/12 01 *** LIS COMMENT RECORD *** e e ---."'" .J l ìsn ~~f !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 ! ! !! !! !! ! ! ! ! !! ! ! !!! Extract File: LISTAPE.HED TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 3 1 C. WONG D. GLADDEN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: 3H-I0B 501032008702 ConocoPhillips Alaska, Inc. BAKER HUGHES INTEQ 12-JUL-04 MWD RUN MWD RUN 12 12N 8E 66.60 38.60 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 7.000 3537.0 6410.0 6.125 PER CONOCOPHILLIPS ALASKA STANDING ORDER, THE ~,.,)-'7 / /(PCJ ,,<....::> (I '-' ~.. eel ) 'Z:J rc ~ e e GAMMA RAY CURVE FROM THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. AS SUCH, NO DEPTH SHIFTS HAVE BEEN APPLIED. SURFACE LOCATION: LAT: N 70 DEG 24' 43.7383" LONG: W150 DEG 00' 39.4510" LOG MEASURED FROM D.F. AT 66.6 FT. ABOVE PERM. DATUM (M.S.L.) . COMMENTS: (1) Baker Hughes INTEQ run 1 utilized a Directional Only service to set a whipstock and mill the casing window from 3537 - 3549 feet MD (3530 - 3541 TVD), and drilled to 3568 feet MD (3560 TVD). (2) Baker Hughes INTEQ run 3 utilized the Advantage Porosity Logging Service (APLS) which includes the Optimized Rotational Density (ORD), Caliper Corrected Neutron (CCN), along with MAP (Modular Annular Pressure) and MPR Resistivity services from 3568 - 6410 feet MD (3560 - 6274 TVD). (3) Per ConocoPhillips Alaska instructions, the Gamma Ray curve from this log is the depth reference for this well. As such, no depth shifts have been applied. REMARKS: (1) Top of 7" Casing Window: 3537 feet MD (3530 TVD) Bottom of 7" Casing Window: 3549 feet MD (3541 TVD) (2) The interval from 6367 to 6410 feet MD (6235 - 6274 TVD) was not logged due to sensor-bit offset at TD. $ Tape Subtile: 1 70 records... Minimum record length: Maximum record length: 8 bytes 132 bytes **** FILE HEADER **** LDWG .001 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!! ! !!!!!!!!!!!!!!!!!! ! FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE MWD $ LDWG File Version 1.000 Extract File: FILE001.HED 1 and clipped curves; all bit runs merged. .5000 START DEPTH 3549.0 STOP DEPTH 6410.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE e e PBU TOOL CODE MWD $ BIT RUN NO MERGE TOP 3 3549.0 MERGE BASE 6410.0 # REMARKS: MERGED PASS. NO DEPTH SHIFTS WERE APPLIED AS THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. $ # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN LCC CN WN FN COUN STAT 3h-l0b 5.xtf 150 ConocoPhillips Alaska, Inc. 3H-I0B Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAM 0.0 RPD RPD RPD 0.0 RPM RPM RPM 0.0 RPS RPS RPS 0.0 RPX RPX RPX 0.0 RHOB RHOB BDCM 0.0 DRHO DRHO DRHM 0.0 PEF PEF DPEM 0.0 NPHI NPHI NPCKSM 0.0 ROP ROP ROPS 0.0 FET FET RPTH 0.0 MTEM MTEM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 52 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 19 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 12 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 GAPI 4 4 2 RPD MWD 68 1 OHMM 4 4 3 RPM MWD 68 1 OHMM 4 4 4 RPS MWD 68 1 OHMM 4 4 e 5 RPX MWD 68 1 OHMM 4 4 6 RHOB MWD 68 1 G/C3 4 4 7 DRHO MWD 68 1 G/C3 4 4 8 PEF MWD 68 1 BN/E 4 4 9 NPHI MWD 68 1 PU-S 4 4 10 ROP MWD 68 1 FPHR 4 4 11 FET MWD 68 1 HR 4 4 12 MTEM MWD 68 1 DEGF 4 4 ------- 48 Total Data Records: 302 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 3549.000000 6410.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 349 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .002 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE011.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 2 e log header data for each bit run in separate files. 4 .2500 START DEPTH 3520.0 STOP DEPTH 6410.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # 12-MAY-04 MSB 18655 4.75 TC MEMORY 6410.0 3549.0 6410.0 o 10.9 27.9 e TOOL STRING (TOP TO VENDOR TOOL CODE DIR CCN ORD MPR GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL CAL. COR. NEUTRON OPT. ROT. DENSITY MULT. PROP. RESIS. GAMMA RAY # 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: # e TOOL NUMBER PAA 10918 SON 44706 SON 44706 MPR 54694 SRIG 58019 6.125 3549.0 LSND 11.15 .0 .0 600 .0 .000 .000 .000 .000 123.0 .0 .0 .0 SANDSTONE .00 .000 .0 o BIT RUN 4 (MWD Run 3). GR/MPR/oRD/CCN. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) BDCM - BULK DENSITY COMPENSATED (G/CC) DRHM - DENSITY CORRECTION (G/CC) DPEM - PHOTOELECTRIC CROSS SECTION (B/E) NPCK - NEUTRON POROSITY, CALIPER & SALINITY CORRECTED (SANDSTONE PU) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER CONOCOPHILLIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RASL - MEDIUM ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) RASH - EXTRA SHALLOW ATTENUATION RESISTIVITY (OHMM) $ *** INFORMATION TABLE: CONS MNEM VALU WDFN 3h-10b.xtf -------------------------------- · ' e e LCC CN WN FN COUN STAT 150 ConocoPhillips Alaska, I 3H-I0B Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPSL RPSL RPM 0.0 RPCH RPCH RPS 0.0 RPSH RPSH RPX 0.0 RACL RACL RAD 0.0 RASL RASL RACSLM 0.0 RACH RACH RAS 0.0 RASH RASH RACSHM 0.0 BDCM BDCM BDCM 0.0 DRHM DRHM DRHM 0.0 DPEM DPEM DPEM 0.0 NPCK NPCK NPCKSM 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 68 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 14 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAPI 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 RACL MWD 68 1 OHMM 4 4 7 RASL MWD 68 1 OHMM 4 4 8 RACH MWD 68 1 OHMM 4 4 9 RASH MWD 68 1 OHMM 4 4 10 BDCM MWD 68 1 G/C3 4 4 11 DRHM MWD 68 1 G/C3 4 4 12 DPEM MWD 68 1 BN/E 4 4 13 NPCK MWD 68 1 PU-S 4 4 14 ROPS MWD 68 1 FPHR 4 4 15 RPTH MWD 68 1 MINS 4 4 16 TCDM MWD 68 1 DEGF 4 4 · , . Total Data Records: 826 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units **** FILE TRAILER **** e 3520.000000 6410.000000 0.250000 teet Tape Subtile: 3 936 records... Minimum record length: Maximum record length: **** TAPE TRAILER **** LDWG 04/07/12 01 **** REEL TRAILER **** LDWG 04/07/12 AWS 01 Tape Subfile: 4 Minimum record length: Maximum record length: 8 bytes 4124 bytes 2 records... 132 bytes 132 bytes e ------- 64