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195-010
• WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. December 8, 2010 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Whipstock Setting Record: 2Z -23 Run Date: 11/19/2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2Z -23 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 22544 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. a0 $5 -49 Anchorage, Alaska 99518 Office: 907 - 273 -3527 - Fax: 907 - 273 -3535 klinton.woo t i Date: 0.C. 2 1 26 0 Signed: t , • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended Q b. Well Class: 20AAC 25.105 20AAC 25.110 p Dg»elopment ❑ Exploratory ❑ GINJ El WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: /,,,_ ts. Service El Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., 0" 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. or Aband.: November 27, 2010 195 - 010 / 310 - 352 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 February 5, 1995 50 029 - 22544 - 00 4a. Location of Well (Govemmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 1304' FSL, 334' FEL, Sec. 11, T11N, R9E, UM February 10, 1995 2Z Top of Productive Horizon: 8. KB (ft above MSL): 41' RKB 15. Field/Pool(s): 982' FSL, 642' FWL, Sec. 11, T11N, R9E, UM GL (ft above MSL): 70.6' AMSL Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): 1036' FSL, 235' FWL, Sec. 11, T11N, R9E, UM 7870' MD / 6163' 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 529376 y - 5966062 Zone 4 7972' MD / 6242' TVD ADL 25646 TPI: x - 525074 y - 5965724 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 524667 y - 5965777 Zone 4 493' MD / 492' TVD 2577 18. Directional Survey: Yes ❑ No gi 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) 1331' MD / 1268' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re drill /Lateral Top Window MD/TVD none not applicable 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H -40 Surf. 121' Surf. 121' 24" 200 sx AS I 9.625" 36# J -55 Surf. 4242' Surf. 3474' 12.25" 890 sx ASIII, 480 sx Class G 7" 26.0# L -80 Surf. 7960' Surf. 6232' 8.5" 338 sx Class G 24. Open to production or injection? Yes ❑ No Q If Yes, list each 25. TUBING RECORD Interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 3.5" / 2.875" 7568' / 7597' 7313' MD / 5759' TVD perfs squeezed off e01'i4 A f G 5 y c o§ 7571' MD / 5953' TVD U � ( 2114-' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED /2•/7 /a 7395' 15.8 ppg cement ( 3dL S ? , 4 t c 5 a j $O 3Be- "O " Ce ».. .,s� PRE - CTP J77 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 IM Sidewall Cores Acquired? Yes ❑ No Q If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 225.0. 71 �/ ... EC I PF E AN 1 NONE DEC 1 , 7 7010 Alaska Ott & teas Cons. Commission RBDMS DEC 17 Anchorage Form 10-407 Revised 12/2009 CONTINUED ON REVERSE S ' ubmit original only / 4 /Z •/7 /o r . --/7/ I 28! GEOLOOJC MARKERS (List all formations and markers •ntered): 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 1331' 1268' needed, and submit detailed test information per 20 AAC 25.071. not applicable N/A Formation at total depth: not applicable 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/ Jill Long @ 263 - 4093 Printed Name Ca , Title: Alaska Wells Manager Signature .,aaurar Phone 263 - 4619 Date JO • 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 • KUP • 2Z -23 C coPhil Well Attributes Max Angle & MD TD Alasi a lrtc � ' Wellbore API /UWI Field Name Well Status Intl ( °) MD (ftKB) Act Btu (ftKB) 500292254400 I KUPARUK RIVER UNIT INJ 43.92 6,360.01 7972.0 Comment Last : Tag: SLM 7,395 0 H2S (ppm) Date Annotation nd Date KB (ft) Rig Release Date "' SSSV. NIPPLE Last t W WO: : 40.66 0 2//12/19/19 95 Well COnfg 2Z- 24,1,g 910 4:2:91 ISM - - - - - SIzhema(� 9�+a1 Annotation Depth (ftKB) End Date Annotation Last Mod By End Data 11/29/2010 Rev Reason: PRE -CTD CMT SOZ, TAG 1 Imosbor 12/212010 Casing Strings String OD Siring ID Set Depth Set Depth (11/D) String Wt String ,( Casin Desc (i n) ( ) Top (ftKB) (ftKB) (OKB) (Ibsltt G de String Top Thrd CONDUCTOR ? 9_.,. „-lion _ . 121 , CONDUCTOR 16 15.062 0.0 121.0 121.0 62.58 H-40 SURFACE 9 5/8 8.599 0.0 4,242.0 3,474.2 40.00 L -80 NIPPLE, 693 _- PRODUCTION 7 6.151 0.0 7,960.0 26.00 L -80 Tubi 4,262 TUBING e ` 3 1 2 String To (ttK 0) . S (ORB) Set Set Depth String l 400' St g - - - SURF I StrI Grad Seri Top Thrd _ 301-80 EUE ABM TUBING 2 718' 2 441 7568.0 7,597.0 6.50 J -55 I EUE ABM GAS 7246 Other In Hole All Jewelry: Tubing Run & Retrievable, Fish, etc.) Top Depth (TVD) Top Intl y Tap (ftKB) (ftK8) (•) Description Comment Run Date ID (in) ' 493.0 491.7 9.14 NIPPLE Camco 'DS' Landing NIPPLE 4/1/1995 2.812 NIPPLE, 7,289 -- ' _ .� 7,246.0 5,709.2 42.10 GAS LIFT CAMCO/MMG-2/1.5/DMY/RK// /Comment: STA 1 5/6/1995 2.920 7,289.0 5,74-1.2 42.22 NIPPLE Camco 'W -1' Selective NIPPLE 4/1/1995 2.812 7,299.0 5,748.6 41.97 PBR Baker PBR 4/1/1995 3.000 r '. PBR, 7299 1 7,313.0 5,759.1 41.63 PACKER Baker'FHL' PACKER 4/1/1995 3.000 - 7,357.0 5,791.9 41 50 INJECTION CAMCO /MMM/1.5 /DMY/RK/ // Comment: STA2 10/20/2010 2.920 7,512.0 5,908.3 41.11 WHIPSTOCK BAKER WHIPSTOCK PRE -CTD; 2.7 degrees, LOHS 11/6/2010 2.882 7,553.0 SLEEVE -C Camco 'CB-1' Sliding SLeeve (D' Profile); CLOSED 1/16/1996 2.750 PACKER,7,313 11/25/2004 7,571.0 PACKER TIW 'SS' PACKER 4/1/1995 3.250 _._ '� I 7,581.0 NIPPLE Ons'XN' Nipple NO GO 4/1/1995 2.250 INJECTION, '1114 7,5960 SOS Baker 4/1/1995 2.441 7,357 [ , _1:-. 7,597.0 TTL 411/1995 2.441 I Perforations & Slots ? 73/ L i.;„, Top (TVD) Btm (ND) Dena Top MKS) Bits (ftKB) ( ftKB ) (1116) Z Date (eh- Type Comment IPERF, 7,400.0 7,418.0 5,824.0 58374 D, C-4, 3/30/ 12.0 IPERF 30 deg. phasing, SWS 41/2 "HSD 7,4007,418 2Z -23 HJ II x 7,445.0 7,495.0 5,857.7 5,895.5 C -3, C -2, C-1, 3/30/1995 12.0 IPERF 30 deg. phasing, SWS 4 1/2" HSD HJ 2Z -23 II IPERF, 7,511.0 7,516.0 5,907.6 5,911.3 UNIT B, 2Z -23 11/12/2010 6.0 APERF TUBING PUNCHES: 2" Millenium II ]445 - ],495 445 Big Hole charges, 60 deg phase ra. C r 7,678.0 7,688.0 A -5, 2Z -23 3/30/1995 4.0 IPERF 180 deg. phasing, SWS 4 1/2" 1 5-/ Z 1 Ultrapac V r.-"t- - 7,696.0 7,726.0 A4, 2Z -23 3/30/1995 4.0 IPERF 180 deg. phasing, SWS 4 1/2" ^ti 1 Ultrapac A - 1,516 _ 7511 - 1,516 tom\ 7,750.0 7,770.0 A 3,2Z - 23 3/30/1995 4.0 IPERF 180 deg. phasing, SWS 41/2" WHIPSTOC(, Uttra[ac 7,512 '3;3 \ 7,804.0 7,809.0 A -3, 2Z -23 3/30/1995 4.0 IPERF 180 deg. phasing, SWS 4 1/2" Ultrapac SLEEVE -C, 7,553 0 PACKER, 7,571 - ' P NIPPLE, 7,587 -- SOS, 7,596 3‘9 TTL, 7,597 tL'S CMT PLUG, 7,395 IPERF, x'ca v 7,678 -7,688 - kc, s4 IPERF, .. . -. _$ IPERF, $� ' 7,750 - 7,770, r IPERF, 1. 7,504 - 7,809 -_. "h. STAGE I, "_.. _� 7.395 PRODUCTION, 7,960 TO (2Z -23), 7,972 2Z -23 Well Work Summary DATE SUMMARY 1t/7/10 LOGGED MEMORY GR/CCL FR.567' RKB TO 7023' RKB. DRIFTED TBOITH 2.625" x 19' DUMMY WHIPSTOCK TO CB -1 © 7553' RKB. MEASURED BHP @ 7553' RKB: 2757 PSI. COMPLETE. 11/12/10 PERFORATED TUBING AT 7511' -7516' (FIRST FULL JOINT ABOVE SLIDING SLEEVE) USING 2" X 5' GUN, WITH 6 SPF, 60 DEGREE PHASING, MILLENIUM BIG HOLE CHARGES. CORRELATED TO TUBING DETAIL 11/13/10 LRS PERFORMED INJECTIVITY TEST. PRESSURE WAS 1100 PSI AT 0.5 BPM, 1250 PSI AT 1 BPM, AND 1400 PSI AT 1.5 BPM. ATTEMPTED TO SET WHIPSTOCK AT A DEPTH OF 7511' RKB WITH ECCENTRIC WEIGHT BARS. COULD NOT GET WHIPSTOCK TO MAINTAIN 0 DEGREE ORIENTATION ( +/- 5 DEGREES) AT SET DEPTH DUE TO WELL BORE CONDTIONS. POOH TO INSPECT TOOL STRING AND WHIPSTOCK. WHIPSTOCK TRAY WAS STILL ORIENTED TO 0 DEGREES AT SURFACE. RETURN AT FUTURE DATE TO RE- ATTEMPT. 11/19/10 SET BAKER WHIPSTOCK (2.625" RUN OD) AT 7512' RKB, ORIENTED 2.7 DEGREES LOHS, WITH DPU -I 2.5" SETTING TOOL AND ECENTRIC WEIGHT BARS. CORRELATE TO TUBING DETAIL RECORD (3/31/1995). 11/27/10 PRE -CTD CEMENT SQUEEZE. PUMPED 15.8 PPG CEMENT ON TOP OF WHIPSTOCK AND SQUEEZED OFF "C" SAND STRADDLE COMPLETION AND LOWER "A" SAND PERFS. TOP OF CEMENT AT 7395'. FREEZE PROTECTED WITH DIESEL DOWN TO 2000'. WELL SHUT IN WITH 1500 PSI ON THE TUBING. 11/29/10 TAG CMT @ 7395' SLM (EST. 7413' RKB USING 18' CF FROM SAME UNIT ON EARLIER JOB). MIT TBG #2500, PASS. COMPLETE. Afore p � ca C< r I -1-19 • V r ' 5,j ° sAtEu ;du - -64-6 � L cam �0 1� f 7 ,6___> /2 /7 I Page 1 of 1 • • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, December 17, 2010 3:11 PM To: 'Long, Jill W Subject: RE: 2Z -23 Pre -CTD Wellwork (Cementing Perfs) . Thanks Jill.. I will add this to the 407 report. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Long, Jill W [mailto:Ji1I.W.Long @conocophillips.com] Sent: Friday, December 17, 2010 3:05 PM To: Schwartz, Guy L (DOA) Subject: 2Z -23 Pre -CTD Wellwork (Cementing Perfs) Guy - As requested on the phone, attached is the report describing the cement procedure on 2Z -23. This will hopefully suffice as documentation that cement was pumped. Also, as you also mentioned on the phone, no mechanical plug was set in this well to isolate the A sand. A plug had previously been planned to be set in the tubing tail but during the pre -rig diagnostics the tubing tail was found to be inaccessible. Because of this, a change in procedure was made to simply cement squeeze both the A and C sand perfs. Neither a plug or cement retainer was set. I have noted that in the future when a change like this is made due to pre -rig diagnostics that the State should be notified, even if the end outcome is the same. I will pass this along to my colleagues as well. Please let me know if you need further information. Thanks, Jill Long ConocoPhillips Alaska Drilling and Wells Office: 907 - 263 -4093 Cell: 907 - 230 -7550 Fax: 918- 662 -6330 12/17/2010 t ell Progress Summary Report ConocoPhillips 2Z -23 Job Type: Drilling Support - Capital ALASKA Secondary Job Type: ZX52 Cementing AFE / RFE / Maint. #: 10294431 Job Category: Well Intervention Primary Wel!bore Affected: 2Z -23 Contractor: SLB -DS Last 24hr Summary: PRE -CTD CEMENT SQUEEZE. PUMPED 15.8 PPG CEMENT ON TOP OF WHIPSTOCK AND SQUEEZED OFF "C" SAND STRADDLE COMPLETION AND LOWER "A" SAND PERFS. TOP OF CEMENT AT 7395'. FREEZE PROTECTED WITH DIESEL DOWN TO 2000'. WELL SHUT IN WITH 1500 PSI ON THE TUBING. Report Start Date: 11/27/2010 06:30 Report End Date: 11/27/2010 22:00 Time Log End Time Start Time Dur (hrs) Operation 08:45 06:30 2.25 ON LOCATION MIRU. PT 4000 PSI. PJSM. 10:45 08:45 2.00 OPEN WELL, RIH. WT CHECK @ 2800' = 3K #, 620 0' = 12.7K# 12:15 10:45 1.50 TAGGED TOWS 7509' CTM. PU WT AND PUH 5', FLAG PIPE AND CORRECT DEPTH TO 7507' (TOWS E -LINE DEPTH 7512'). PUH TO 7370', PU WT 20K #. DISPLACING CT AND START CIRCULATING WELL TO SEAWATER. PUMPED 120 BBL. INJECTION TEST: 0 BPM: CT =700 PSI, WHP =700 PSI 0.5 BPM: CT =885 PSI, WHP =700 PSI 1.0 BPM: CT =1420 PSI, WHP =740 PSI 1.5 BPM: CT= 2270 PSI, WHP =825 PSI 13:00 12:15 0.75 PJSM. START MIXING CEMENT. 15:15 13:00 2.25 SLURRY MIXED 50 BBL TO 15.8 PPG. START PUMPING DOWN THE CT, 5 BBL FRESH WATER FOLLOWED BY CEMENT. INITIAL STATIC PRESSURE CT = 430 PSI, WHP = 630 PSI. 15:45 15:15 0.50 CT AT 7507' WITH CEMENT EXITING THE NOZZLE. SQUEEZING AT 1.4 BPM PUMP PRESS 2580 PIS, WHP 820 PSI. 10 BBL OUT OF NOZZLE PUMP PRESS = 2800 PSI, WHP =1000 PSI. 20 BBL OUT OF NOZZLE PUMP PRESS = 2330 PSI, WHP = 1150 PSI. 30 BBL OUT OF NOZZLE PUMP PRESS = 1780 PSI, WHP = 1275 PSI. REDUCE RATE TO 0.5 BPM, OPEN CHOKE TO 1100 PSI, PLACE 1 BBL ABOVE NOZZLE 1:1 RETURNS, PUH LAYING IN CEMENT. CEMENT OUT OF CT. TOC © 5950', FINAL PRESS TO MAINTAIN 1:1 RETURNS WHP = 300 PSI. PUH TO 5000'. SHUT IN PRESS WITH CT FULL OF FRESH WATER = 745 PSI, WHP = 580 PSI. CIRC CT REEL TO DIESEL MAINT 1:1 RETURNS. 17:00 15:45 1.25 SHUT PRESS CT= 595 PSI, WHP = 405 PSI. HESITATION SQUEEZE: ( -5 MIN INTERVALS) PRESS 405 PSI TO 860 PSI, PUMPED 0.3 BBL @ 0.5 BPM PRESS 620 PSI TO 925 PSI, PUMPED 0.3 BBL @ 0.3 BPM PRESS 770 PSI TO 1135 PSI, PUMPED 0.4 BBL @ 0.3 BPM PRESS 915 PSI TO 1305 PSI, PUMPED 0.5 BBL @ 0.3 BPM PRESS 1095 PSI TO 1420 PSI, PUMPED 0.4 BBL @ 0.3 BPM PRESS 1130 PSI TO 1510 PSI, PUMPED 0.5 BBL @ 0.3 BPM PRESS 1310 PSI TO 1570 PSI, PUMPED 0.2 BBL @ 0.3 BPM PRESS 1370 PSI TO 1675 PSI, PUMPED 0.3 BBL @ 0.2 BPM PRESS 1460 PSI TO 1745 PSI, PUMPED 0.3 BBL @ 0.3 BPM PRESS 1560 PSI TO 1805 PSI, PUMPED 0.2 BBL @ 0.2 BPM PRESS 1620 PSI TO 1910 PSI, PUMPED 0.3 BBL © 0.2 BPM PRESS 1650 PSI TO 1940 PSI, PUMPED 0.3 BBL @ 0.2 BPM PRESS 1770 PSI TO 2015 PSI, PUMPED 0.2 BBL © 0.2 BPM SQUEZZED 4.3 BBL, NEW TOC AT 6450'. 18:20 17:00 1.34 WHP BLED DOWN TO 1550 PSI AFTER 20 MIN, PRESS HAS FLATLINED. DROP BALL AND START CIRCULATING BIO INTO CT, HOLDING 1500 PSI ON WHP TO MAINTAIN 1:1 RETURNS. BALL AND BIO AT NOZZLE RIH. WT CHECK AT 7070' 15K #, CONTINUE RIH. www.peloton.com Page 1/2 Report Printed: 12/17/2010 t ell Progress Summary Report ConocoPhillips 2Z -23 Job Type: Drilling Support - Capital ALASKA Secondary Job Type: ZX52 Cementing Time Log End Time Start Time Dur (hrs) Operation 20:00 18:20 1.66 WASH DOWN TO 7395', HOLDING 1500 PSI WHP MAINTAINING 1:1 RETURNS, PU WT 17K #, WASH UP AND DOWN @ 20 FPM BETWEEN 7395' AND 7220' WHILE SIDE JETTING WITH BIO. BACK DOWN TO 7390', SEAWATER AT NOZZLE. POOH SWAPPING WELL TO SEAWATER, HOLDING WHP @ 1500 PSI MAINTAINING 1:1 RETURNS, UP WT 25K #. FREEZE PROTECTING WITH DIESEL FROM 2000' TO SURFACE. 22:00 20:00 2.00 CT AT SUFACE SHUT IN WELL WITH 1500 PSI ON THE TUBING. RDMO, NOTIFY DSO. www.peloton.com Page 2/2 Report Printed: 12/17/2010 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. November 15, 2010 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforating Record: 2Z -23 Run Date: 11/12/2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of. Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2Z -23 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 22544 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 _ V S klinton.woo��� Date: Signed: WO �a oil 8: Gas C` ,�+e WELL LOG MA/IfEl1/IIMAL PROAciiw MACINOSTIc 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 following: ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 1 j Correlation Log 07- Nov-10 2Z -23 EDE 50 -029- 22544 -00 2) NOY LAS -C)to 9 (0( i n Signed: Date Print Name:` PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAX: (907)245 -88952 E-MAIL: pdsa 8CaPo a(je(&f4' emoi?I1oq. om WESSITE : www.memorylog.com C Documents and SetlinpWiane Williams\DesktDp \Transmit_Corroco.doc WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. November 4, 2010 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MIT Caliper Log: 2Z -23 Run Date: 10/29/2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2Z -23 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 22544 -00 MIT Caliper Log 1 Color Log 50- 029- 22544 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 -273 -3527 Fax: 907-273-3535 klinton.wood @halfiburt6ri.c6m ' I S , Date: Signed: WELL LO TRANSMITTAL PROACTIVE DIAGNOSTIC SERVICES, I NC. I To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659 -5102 RE: Cased Hole /Open Hole /Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following Pr Active Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 1) Caliper Report 29 -0ct -10 2Z -23 1 Report/ EDE 50 -029- 22544 -00 2) 3, Signed: 1. Date ri �s Print Name:;a, PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE AK 99518 PHONE: (907)245 -8951 FAx: (907)24548952 E-MAIL: gdsanchor aQe(Mmernoryloci.com WEBSITE : lAwN.memoreylog.com CADocuments and Settings\Diane Williams \Desktop \Tiansmit_Conoco.docx t Memory Multi - Finger Caliper S V_ i Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 2Z -23 Log Date: October 29, 2010 Field: Kuparuk Log No.: SO# 7738872 State: Alaska Run No.: 1 API No.: 50- 029 - 22544 -00 Pipet Desc.: 3.5" 9.3 lb. L -80 EUE ABM Top Log Intvl: Surface Pipet Use: Tubing Bot. Log Intvl: 7,558 Ft. (MD) Inspection Type: Corrosive & Mechanical Damage Inspection COMMENTS: This caliper data is correlated to SLB !PROF dated August 10, 2005. This log was run to assess the condition of the tubing with respect to corrosive and mechanical damage, ' particularly in the vicinity of the proposed whipstock setting depth of 7,543'. The caliper recordings indicate the 3.5" tubing logged appears to be in poor condition from —7,360' to 7,558' (EOL), with multiple holes recorded from 7,502' to 7,532'. Recorded damage appears as deep line corrosion throughout this interval. The caliper recordings indicate an obstruction from 7,534' to 7,558', restricting the I.D. to 1.83" at 7,547'. A ' graph illustrating minimum recorded diameters on a joint-by-joint basis and a 3 -D log plot of the caliper recordings from 7,210' to the bottom of the tubing logged is included in this report. The caliper recordings indicate the remainder of the 3.5" tubing logged appears to be in good to poor condition with respect to corrosive and mechanical damage. Wall penetrations ranging from 20% to 50% wall thickness are recorded in 111 of the 251 joints logged. Recorded damage appears as isolated pitting from surface to -- 7,340'. No significant areas of cross - sectional wall loss are recorded throughout the tubing logged. This summary report is interpretation of data provided by Halliburton Well Services_ ' MAXIMUM RECORDED WALL PENETRATIONS: Multiple Holes (100 %) it. 242 @ 7,506 Ft. (MD) Possible Hole ( 86 %) it. 243 @ 7,532 Ft. (MD) Isolated pitting ( 50 %) it. 210 @ 6,542 Ft. (MD) Line corrosion ( 50 %) it. 235 @ 7,390 Ft. (MD) Line corrosion ( 48 %) it. 238 @ 7,448 Ft. (MD) ' MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS: No significant areas of cross - sectional wall loss (> 13 %) are recorded throughout the tubing logged. ' MAXIMUM RECORDED ID RESTRICTIONS: Obstruction Minimum I.D. = 1.83" it. 243 @ 7,547 Ft. (MD) No other significant I.D. restrictions are recorded throughout the tubing logged. Field Engineer: M. Biery Analyst: C. Waldrop Witness: B. Boehme ProActive Diagnostic Services, Inc. % P.G. 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 l a 5_d 10 ,--b ' �-G 1 • gggqq � — 1 !1: N !!!!!�lLA MEN 0 Joint 233 Isolated pitting 27% Wall Penetration - ggqff•ff,q�i i 731 _ 732 AN ... ... l�Jt!lS��salr!` 0 R" _ 1 � !! "Il0- !!!!!!!f MINIM — !!!I f3 !! 1 !m!!!mlIA ; ggqqqqql�; — - BEEN...INS � = ■+..iWON Mir. MIEW � .s -mm MOM MMMM Correlation of Recorded Damage to Borehole Profile ® Pipe 1 3.5 in (23.4' - 7531.8') Well: 2Z -23 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: October 29, 2010 I ■ Approx. Tool Deviation . Approx. Borehole Profile 1 27 25 796 50 1563 75 2337 100 3111 125 3885 S� Z s � a o p 150 4659 175 5434 ' 200 6208 ' 225 6981 GLM 1 IN) 2 243 7532 0 50 100 Damage Profile (% wall) /Tool Deviation (degrees) ' Bottom of Survey = 243 i i Minimum Diameter Profile i Well: 2Z -23 Survey Date; October 29, 2010 Field: Kuparuk Tool: UW MFC 24 No. Hal. Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA Tubing I.D.: 2.992 inches ' Minimum Measured Diameters (in.) 1.69 1.94 ''.19 2.44 2.69 2.94 0.1 = � hI 14.1 r 18 24 30 L 36 42 48 54 _ 60 i 66 _ 72 78 84 90 96 102 108 1 V 114 � 120 Z 126 e 132 138 144 150 1 156 162 168 174 18 186 192 198 =_ ' 204 210 216 222 ' 228 232 � 233 236 242 i i PDS Report Overview Body Region Analysis ' Well: 2Z -23 Survey Date: October 29, 2010 Field: Kuparuk Tool Type: UW MFC 24 No. Hal. Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Analyst: C. Waldro Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower (en. 3.5 ins 9.3 ppf L -80 EUE ABM 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) Damage Profile (% wall) j penetration body IIIIIIIIIIg metal loss body penetration body ti metal loss body 0 50 100 250 0 200 150 100 1 50 45 0 0 to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% f Number of joints analysed total = 254 e. 0 38 98 107 9 2 21 231 2 0 0 0 95 Damage Configuration ( body ) 200 145 ' 150 100 50 195 O isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole r.i nn 1 i INJ 2 240 Number of joints damaged total = 196 ' 186 0 8 0 2 Bottom of Survey = 243 Analysis Overview page 2 i PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE ABM Well: 2Z -23 Body Wall: 0.254 in Field: Kuparuk ' Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: October 29, 2010 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 1 23 0 0.02 9 2 2.90 PUP 1 27 0 0.03 11 2 2.95 1.1 58 0 0.01 5 1 2 2.93 PUP 1.2 65 0 0.02 8 2 2.95 PUP 1.3 71 t) 0.01 4 0 2.97 PUP 2 75 0 0.03 10 1 2.95 3 105 0 0.01 4 2 2.94 4 135 0 0.05 18 2 2.93 Shallow pitting. 5 164 0 0.04 17 2 2.94 Shallow pitting. 6 196 0 0.02 9 1 2.94 7 225 0 1 0.04 17 1 2 2.95 1 Shallow pitting. 8 256 0 0.02 7 1 2.95 9 287 0 0.02 7 2 2.94 10 317 0 0.05 20 2 2.95 Shallow pitting. 11 348 0 0.03 11 1 2.95 12 1 379 0 0.04 15 2 2.93 Shallow pitting. 13 410 0 0.02 9 1 2 2.95 14 441 0 1 0.03 13 1 2.95 Shallow pitting. 14.1 473 0 0.01 4 2 2.94 PUP 14.2 479 0 0 0 0 2.81 Camco'DS'Landinsz Nipple 14.3 483 0 0.01 2 1 2.96 PUP 15 486 0 0.02 9 2 2.94 16 1 517 0 0.04 14 2 2.94 Shallow pitting. 17 548 0 0.04 17 1 2.94 Shallow pitting. 18 579 ) 0.04 15 1 2.95 Shallow pitting. 19 610 0 0.01 5 2 2.95 ' 20 641 0 0.01 4 1 2.94 21 671 0 0.05 18 2 2.95 Shallow pitting. 22 702 0 0.03 11 2 2.92 23 1 734 0 0.04 14 2 2.95 Shallow pitting. ' 24 765 0 0.10 40 1 2 2.93 Isolated pitting. 25 796 U 0.03 10 1 2.94 26 827 0 0.09 35 2 2.94 Isolated pitting. 27 858 i) 0.09 34 2 2.95 Isolated pitting. 28 889 0 0.02 9 2 2.94 i 29 919 t 0.06 22 2 2.95 Isolated pitting. 30 950 0 0.06 22 2 2.94 Isolated pitting. 31 980 0 0.05 19 1 2 2.95 Shallow pitting. 32 1010 0 1 0.04 16 1 2.94 Shallow pitting. 33 1041 U 0.07 27 2 2.96 Isolated pitting. 34 1072 0 0.05 19 1 2.94 Shallow pitting. 35 1103 0 0.08 33 2 2.95 Isolated pitting. 36 1134 0.06 0.05 21 2 2.95 1 Isolated pitting. ' 37 1165 0 0.07 27 2 2.95 Isolated pitting. 38 1195 0 0.07 29 1 2 2.96 Isolated pitting. 39 1225 0 1 0.05 18 1 2.95 Shallow pitting. 40 1255 0 0.07 28 2 2.95 Isolated pitting. 1 41 1286 0 0.06 24 2 2.95 Isolated pitting. 42 1317 0 0.07 28 2 2.94 Isolated pitting. 43 1347 0 0.04 14 1 2.95 1 Shallow pitting. Penetration Body Metal Loss Body Page 1 PDS REPORT JOINT TABULATION SHEET ' Pipe: 3.5 in 9.3 ppf L -80 EUE ABM Well: 2Z -23 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: October 29, 2010 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (his.) (Ins.) % (Ins.) 0 50 100 44 1378 0 0.05 19 2 2.94 Shallow pitting. 45 1409 0 0.05 20 2 2.93 Shallow pitting. 46 1441 0 0.05 21 2 2.95 Isolated pittinsz. 47 1471 0 0.04 17 2 2.94 Shallow pitting. ' 48 1501 0 0.04 15 2 2.96 Shallow pitting. 49 1532 0 0.04 14 3 2.96 Shallow pitting. 50 1563 0 0.02 9 2 2.94 51 1594 U 0.03 12 2 2.94 52 1625 0 0.04 15 3 2.96 Shallow 6tting. 53 1 1655 0 0.06 25 1 2 2.95 1 Isolated pitting. 54 1686 a 0.05 21 3 2.96 Isolated pitting. 55 1717 0 0.08 31 2 2.96 Isolated 6tting. 56 1748 0 0.02 9 2 2.96 57 1779 U 0.04 14 2 2.98 Shallow pitting. 58 1810 0 0.04 15 2 2.97 Shallow pitting. 59 1841 0 0.03 11 2 2.95 60 1872 o 0.03 12 2 2.96 61 1903 0 0.03 11 2 2.96 62 1934 0 1 0.03 11 1 2 2.94 63 1966 0 0.03 11 2 2.97 64 1996 0 0.03 10 2 2.95 65 2028 0 0.05 19 3 2.96 Shallow ittin . 66 1 2059 0 0.05 20 3 2.94 Shallow pitting. 67 2090 0 0.03 13 2 2.96 Shallow pitting. 68 2121 0 0.03 11 1 2 2.96 69 2152 0 1 0.03 10 2.93 70 2183 0 1 0.03 11 2 2.94 71 2214 0 0.03 11 2 2.96 72 2245 0 0.03 12 2 2.93 73 1 2276 0 0.04 18 3 2.93 Shallow pitting. 74 2307 0 0.03 13 2 2.96 1 Shallow pitting. 75 2337 0 0.04 14 2 2.93 Shallow pitting. 76 2369 0 0.03 13 2 2.93 Shallow pitting. 77 2400 0 1 0.02 9 2 2.97 78 2430 0 0.05 20 3 2.93 Isolated pitting. 1 79 2461 0 0.04 15 2 2.94 Shallow pitting. 80 1 2492 0 0.04 16 2 2.95 1 Shallow pitting. 81 2523 0 0.05 18 3 2.94 Shallow pitting. 82 2553 0 0.03 11 1 2 2.95 ' 83 2584 (` 0.04 18 2 2.91 Shallow pitting. 84 2616 0 1 0.03 13 2 2.95 Shallow pitting. 85 2647 0 0.04 14 2 2.95 Shallow pitting. 86 1 2678 0 0.04 16 2 1 2.94 Shallow ittin . ' 87 2709 0 0.02 9 2 2.94 88 2740 0 0.04 16 2 2.94 Shallow pitting. 89 2771 0 0.03 12 2 2.93 90 2802 0 0.02 9 2 2.96 1 91 2833 1 0 0.03 10 2 2.94 92 2864 U 0.02 7 2 1 2.95 93 1 2895 U 0.04 15 2 1 2.93 Shallow pitting. Penetration Body Metal Loss Body Page 2 PDS REPORT JOINT TABULATION SHEET 1 Pipe: 3.5 in 9.3 ppf L -80 EUE ABM Well: 2Z -23 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: October 29, 2010 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 94 2927 0 0.04 17 1 2.96 Shallow pitting. 95 2956 0 0.03 12 3 2.94 96 2988 0 0.04 15 2 2.96 Shallow pitting. 97 3017 0 0.03 12 2 2.95 98 3048 0 0.03 13 2 2.93 Shallow pitting. 99 3080 0 0.02 9 2 2.94 100 3111 0 0.05 21 3 2.95 Isolated 6tting. 101 3142 0 0.02 9 2 2.94 102 3173 0 0.03 12 2 2.95 103 1 3203 0 0.05 20 3 2.92 Isolated pitting. 104 3235 0 0.06 25 1 3 2.94 Isolated pitting. 105 3266 0 0.03 10 2 2.92 106 3297 ) 0.04 18 2 2.93 Shallow pitting. 107 3328 U 0.05 18 2 2.95 Shallow pitting. 108 3359 0 0.04 17 2 2.93 Shallow pittin 109 3391 0 0.06 24 3 2.95 Isolated pitting. 110 1 3422 0 0.05 18 1 2 2.93 Shallow pitting. 111 3452 0 0.03 13 2 2.94 Shallow pitting. 112 3483 0 0.04 16 2 2.93 Shallow pitting. 113 3514 0 0.03 13 2 2.93 Shallow pitting. 114 3545 0 0.02 9 2 2.94 115 3576 ) 0.03 12 2 2.92 Shallow pitting. 116 3607 0 0.03 13 2 2.92 Shallow pittinm. 117 1 3638 0 0.05 18 1 2 2.92 Shallow pitting. 118 3669 0 0.07 26 2 2.94 Isolated pitting. 119 3700 0 0.06 24 3 2.95 Isolated pitting. 1 120 3730 0 0.05 21 2 2.93 Isolated 6tting . 121 3762 0 0.03 13 2 2.93 Shallow pitting. 122 3793 0 0.05 20 2 2.92 Shallow pitting. 123 3824 0 0.03 13 2 2.91 Shallow pitting. 124 3854 0 0.03 12 2 2.91 Shallow pitting. 125 1 3885 0 0.02 8 1 1 2.95 126 3913 0 1 0.03 10 2 2.95 127 3944 0 1 0.03 13 1 2.92 Shallow pitting. 128 3976 0 0.06 24 2 2.93 Isolated pitting. 129 4007 0 0.04 16 2 2.95 Shallow pitting. 130 4038 0 0.02 7 2 2.96 131 4069 0 0.03 12 2 2.93 132 4100 t) 0.04 16 1 1 2.89 Shallow pitting. ' 133 4131 0.05 19 2 2.95 Shallow pitting. 134 4162 0 0.07 26 2 2.96 Isolated vittinm. 135 4193 0 0.02 9 2 2.93 136 4224 0 0.06 22 2 2.90 Isolated pitting. 137 4255 0 0.06 23 2 2.95 Isolated pitting. 138 4286 0 0.05 20 2 2.95 Shallow pitting. 139 4317 0 0.05 19 1 2 2.93 Shallow ittin . 140 4348 0 0.03 12 3 2.95 141 4379 1 0 1 0.05 21 2 2.95 Isolated pitting. ' 142 4410 0 0.05 18 2 2.95 Shallow pitting. 143 4441 0 0.05 19 2 2.93 Shallow ittin . Penetration Body ' Metal Loss Body Page 3 PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L -80 EUE ABM Well: 2Z -23 Body Wall: 0.254 in Field: Kuparuk ' Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: October 29, 2010 Joint Jt. Depth Pen. Pen. Pen. Metal Min. FDamage Profile No. (Ft.) Upset Body % Loss LD. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 144 4472 0 0.05 19 2 2.95 Shallow pitting. 145 4503 0 0.06 24 2 2.94 Isolated pitting. 146 4534 0 0.05 20 2 2.94 Shallow pitting. 147 4566 0 0.04 15 2 2.95 Shallow pitting. ' 148 4596 11 0.05 20 2 2.93 Isolated pitting, 149 4627 0 0.06 25 2 2.93 Isolated pitting. 150 4659 0 0.04 17 2 2.95 Shallow pitting. 151 4689 0 0.06 23 3 2.92 Isolated pitting. 152 4721 0 0.10 38 2 2.96 Isolated Pitting. 1 153 4751 0 1 0.06 23 1 2 2.92 Isolated pitting. 154 4783 0 0.07 26 2 2.96 Isolated pitting. 155 4814 0 0.05 18 2 2.95 Shallow ittin . 156 4845 0 0.06 25 2 2.94 Isolated pitting. ' 157 4876 0 0.08 31 2 2.92 Isolated pitting. 158 4908 0 0.08 33 2 2.94 Isolated pitting. 159 4939 0 0.06 25 2 2.92 Isolated Pitting. 160 4970 0 0.07 27 1 2 2.91 1 Isolated pitting. 161 5001 0 0.04 16 2 2.94 Shallow pitting. 162 5031 0 0.08 30 2 2.93 Isolated pitting. 163 5062 0 0.07 272 2.94 Isolated pitting. 164 5093 0 0.07 28 2 2.92 Isolated tAtting. 165 5124 0 0.06 24 2 2.92 Isolated pitting. 166 5155 0 0.06 22 2 2.96 Isolated pitting. 167 5186 0 1 0.08 32 1 2 2.94 1 Isolated pitting. 168 5217 0 0.06 23 2 2.92 Isolated 6tting. 169 5249 0 0.07 26 2 2.95 Isolated pitting. ' 170 5279 0 0.05 19 2 2.92 Shallow pitting. 171 5310 0 0.07 28 4 2.95 Isolated pitting. 172 5341 0 0.06 23 2 2.94 Isolated pitting. 173 5372 0 0.07 29 2 2.96 1 Isolated pitting. 174 5403 0 1 0.08 31 1 3 2.96 Isolated pitting. 175 5434 0 0.06 24 2 2.89 Isolated pitting. 176 5466 0 0.06 24 2 2.95 Isolated Pitting. 177 5496 0 0.09 35 2 2.95 Isolated pitting. 178 5527 0 0.07 29 2 2.93 Isolated pitting. 179 5557 0 0.07 26 2 2.93 Isolated ittin . 180 5589 0 0.08 32 1 2 2.93 Isolated pitting. 181 5619 0 1 0.07 28 3 2.93 Isolated 6tting. 182 5652 0 0.09 34 2 2.92 Isolated pitting. 183 5682 0 0.07 29 3 1 2.92 Isolated pitting. 184 1 5713 0 0.09 35 3 2.92 Isolated pitting. 185 5745 0 0.07 26 2 2.93 Isolated pitting. 186 5776 0 0.09 36 2 2.93 Isolated pitting. ' 187 5806 0 0.08 31 1 2 2.92 Isolated pitting. 188 5837 0 0.10 39 2 2.96 Isolated pitting. 189 5868 0 0.10 39 3 2.94 1 Isolated 6tting. 190 5899 0 0.07 27 3 2.93 Isolated pitting. 191 1 5931 0 0.10 39 2 2.93 Isolated pitting. 192 5961 0 0.09 36 2 2.93 Isolated pitting. 193 5992 0 0.08 32 3 2.91 Isolated ittin . Lt. Deposits. Penetration Body Metal Loss Body Page 4 PDS REPORT JOINT TABULATION SHEET ' Pipe: 3.5 in 9.3 ppf L -80 EUE ABM Well: 2Z -23 Body Wall: 0.254 in Field: Kuparuk ' Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: October 29, 2010 Joint Jt, Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 194 6021 0.06 0.08 31 2 2.96 Isolated pitting. 195 6052 t) 0.07 28 2 2.96 Isolated pitting. 196 6082 0.07 28 2 2.92 Isolated pittin5z. 197 6114 t) 0.10 41 4 2.94 Isolated pitting. 198 6144 t) 0.08 31 3 2.91 Isolated Pitting, ' 199 6176 0 0.07 28 2 2.94 Isolated pitting. Lt. Deposits. 200 6208 0.06 0.10 39 1 2 2.96 Isolated pitting. 201 6238 0.06 0.08 32 3 2.94 Isolated pitting. 202 6269 0 0.10 39 2 2.93 Isolated ittin . ' 203 6301 0 0.10 39 2 2.95 Isolated pitting. 204 6331 0 0.11 42 3 2.92 1 Isolated pitting. 205 6363 0.07 0.10 39 3 2.94 Isolated pitting. 206 6394 0 0.09 34 2 2.93 Isolated pitting. 207 6426 0 0.06 23 1 2 2.96 Isolated pitting. 208 6455 0 0.09 34 2 2.93 Isolated pitting. 209 6486 0 0.09 33 2 2.96 Isolated pitting. 210 6516 0 0.13 50 2 2.91 Isolated pitting. Lt. Deposits. 1 211 6548 0.06 1 0.09 37 3 2.95 Isolated pitting. 212 6578 0 0.07 29 2 2.93 Isolated pitting. 213 6611 0 0.10 39 2 2.91 1 Isolated 6tting. 214 6641 0.06 0.09 1 35 3 2.95 Isolated pitting. 215 6672 0.06 0.10 38 2 2.93 Isolated pitting. ' 216 6704 0 0.07 29 3 2.95 Isolated pitting. 217 6735 0 0.09 35 2 2.91 Isolated pitting. 218 6766 0 0.08 31 2 2.93 Isolated r)ittinp,. 219 6796 0 0.06 24 2 2.94 Isolated pitting. 220 1 6826 0 1 0.07 28 1 2 2.95 1 Isolated 6tting. 221 6857 0 0.07 27 2 2.93 Isolated pitting. 222 6889 0 0.06 24 2 2.97 Isolated pitting. 223 6919 0 0.07 29 2 2.91 Isolated pitting. 224 6949 0 0.08 30 2 2.92 Isolated 6tting. 225 6981 0 0.07 29 3 2.92 Isolated pitting. 226 7012 U 0.08 31 2 2.95 Isolated pitting. 227 7042 0 0.08 30 2 2.94 1 Isolated pitting. ' 228 7074 0 0.05 21 2 2.96 Isolated ittin . 229 7105 0 0.06 22 3 2.93 Isolated pitting. 230 7135 0 0.05 18 2 2.93 Shallow pittinsz. 231 7165 0 0.06 24 2 2.94 Isolated pitting. 232 7196 t) 0.07 27 2 2.94 Isolated pitting. ' 232.1 7227 i) 0.02 9 4 1 2.94 PUP 232.2 1 7233 0 1 0 0 0 N/A GLM 1 Latch @ 2:30 232.3 7241 0 0.01 5 1 2.95 PUP 233 7245 0 0.07 27 2 2.95 Isolated pitting. 233.1 7276 O 0 0 0 2.81 Camco'W -1' Selective Nipple 233.2 7279 0 0.01 2 1 2.91 PUP 233.3 7286 0 0 0 1 0 1 3.00 Baker PBR 233.4 7300 t) 0 0 0 3.00 Baker'FHL' Packer 234 1 7307 0 1 0.04 16 6 2.94 Shallow pitting . ' 234.1 7338 0 0.01 2 2 2.91 PUP 234.2 7345 0 0 0 0 N A In'ection Mandrel - 2 Latch @ 7:30 Penetration Body Metal Loss Body Page 5 PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L -80 EUE ABM Well: 2Z -23 Body Wall: 0.254 in Field: Kuparuk ' Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: October 29, 2010 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (his.) (Ins.) % (Ins.) 0 50 100 ' 234.3 7354 0 0.05 19 2 185 PUP Shallow line corrosion. Lt. Deposits. 235 7360 0.08 0.13 50 6 2.93 Line corrosion. 236 7392 0.05 0.11 43 5 2.92 Line corrosion. 237 7411 0.06 0.10 40 1 6 2.91 Line corrosion. Lt. Deposits. 238 7431 0.02 0.12 48 6 2.92 Line corrosion. Lt. De osits. 239 7451 0.03 0.11 43 6 2.92 Line corrosion. 240 7470 U 0.11 44 6 2.92 Line corrosion. Lt. Deposits. 241 7490 0 0.12 46 6 2.93 Line corrosion. 242 7500 0.14 0.53 100 13 1 2.94 Multiple Holes! I' 243 7532 of m 0.22 86 11 1.83 Possible Hole! Obstruction. Penetration Body Metal Loss Body 1 Page J: s PDS Report Cross Sections ' Well: 2Z -23 Survey Date: October 29, 2010 Field: Kuparuk Tool Type: UW MFC 24 No. Hal. Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 ins 9.3 ppf L -80 EUE ABM Analyst: C. Waldro Cross Section for Joint 242 at depth 7506.36 ft Tool speed = 43 Nominal ID = 2.992 ' Nominal OD = 3.500 Remaining wall area = 90 % Tool deviation = 40 " 1 Finger 24 Penetration = 0.53 ins Multiple Holes 0.53 ins= 100% Wall Penetration HIGH SIDE = UP Cross Sections page 1 r _ PDS Report Cross Sections a Well: 2Z -23 Survey Date: October 29, 2010 Field: Kuparuk Tool Type: UW MFC 24 No. Hal. Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 ins 9.3 ppf L -80 EUE ABM Analyst: C. Waldro ' Cross Section for Joint 243 at depth 7532.27 ft Tool speed = 43 Nominal ID = 2.992 ' Upset OD = 3.500 Remaining wall area = 80 % In upset region Tool deviation = 42 " 1 Finger 24 Penetration = 0.218 ins Possible Hole 0.22 ins = 86% Wall Penetration HIGH SIDE = UP ' Cross Sections page 2 cli S PDS Report Cross Sections ' Well: 2Z -23 Survey Date: October 29, 2010 Field: Kuparuk Tool Type: UW MFC 24 No. Hal. Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 ins 9.3 ppf L -80 EUE ABM Analyst: C. Waldro Cross Section for joint 243 at depth 7546.74 ft Tool speed = 43 Nominal ID = 2.992 ' Nominal OD = 3.500 Remaining wall area = 100 % Tool deviation = 41 " r 1 ' Finger 12 Projection = -0.714 ins Obstruction Minimum I.D. = 1.83 ins HIGH SIDE = UP ' Cross Sections page 3 ConocoPhillips Alaska, Inc. KRU 2Z -23 ' 2Z -23 API: 500292254400 Well T INJ Angle a TS: 42 deg @ 7401 SSSV Type: NIPPLE Orig Completion: 2/12/1995 Angle Q TD: 40 deg@ 7972 NIP (493 -494, Annular Fluid: Last W /O: Rev Reason: TAG FILL ' OD:3.5001 Reference Log: Ref Log Date: Last Update: 11/3/2006 Last Tag: 7833 TD: 7972 ftKB Last Tag Date: 10/19/2006 Max Hole An Ie: 43 deg @ 6372 Casing String - ALL STRINGS Description Size Top Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 121 121 62.58 H40 SUR. CASING 9.625 0 4242 3465 40.00 L -80 PROD. CASING 7.000 0 7960 6232 26.00 L -80 Tubing String - TUBING NIP Size Top Bottom TVD Wt I Grade I Thread (7289 -7290, 3.500 0 7568 5933 9.30 L -80 EUE ABM OD:3.500) 2.875 1 7568 7597 5955 6.50 J -55 I EUE ABM Perforations Summa Interval TVD I Zone Status Ft SPF Date Type Comment 7400-7418 5807-5821 1 UNIT 18 12 3/30/1995 IPERF 30 deg. phasing, SWS 4 PBR p C -4 1/2" HSD HJ II (7299 -7300, 7445-7495 5841-5879 C- 3,C -2,C -1 50 12 3/30/1995 IPERF 30 deg. phasing, SWS 4 OD:3.500) 1/2" HSD HJ II 7678-7688 6017-6025 A -5 10 4 3/30/1995 IPERF 180 deg. phasing, SWS 4 ' 1/2" Uftra ac 7696-7726 6031-6054 A-4 30 4 3/30/1995 IPERF 180 deg. phasing, SWS 4 PKR 1/2" Ultra ac (7313 -7314, 7750-7770 6072-6087 A -3 20 4 3/30/1995 IPERF 180 deg. phasing, SWS 4 OD:6.151) ' 1/2" Ultra ac 7804-7809 6113 - 6117 A -3 5 4 3/30/1995 IPERF 180 deg. phasing, SWS 4 1/2" Uftra ac Injection Gas Lift Mandrels/Valves Mandrel/Valve St MD I TVD I Man I Man Type V Mfr V Type V OD Latch I Port I TRO Date Run Vlv ' 2(7357 -7358, Mfr Cmnt OD:6.018) 1 72461 56921 Camco I MMG -2 DMY 1.5 RK 1 0.000 L 0 1 5/6/1995 Pert Injection Mandrels/Valves (7400 -7418) St I MD I TVD I Man I Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Mfr Cmnt 2 1 73571 57751 Carrico I MMM I HFCV 1.5 RK 0.188 0 4(1/2006 Perf Other (plugs, equip., etc. - JEWELRY (7445 7495) Depth TVD Type Description ID 493 492 NIP Camco'DS' Landing 2.812 ' 7289 5724 NIP Camco'W -1' Selective 2.812 SLEEVE -C 7299 5732 PBR Baker 3.000 (7553 -7554, f 7313 5742 PKR Baker'FHL' 3.000 OD:3.500) 7553 5922 SLEEVE -C Camco'CB -1' Sliding SLeeve No Go Profile • CLOSED 11/25/2004 2.750 7571 5936 PKR TIW 'SS' 3.250 7587 5948 NIP Otis'XN' Ni le NO GO 2.250 7596 5955 SOS Baker 2.441 PKR 7597 5955 TTL 2.441 (7571-7572, General Notes OD:6.151) Date I Note 2/11/20001 Partial obstruction 7613' see 2/11/00 WSR NIP (7587 -7588, OD:2.875) TUBING (7568 -7597, D:2.875, I D:2.441) Perf ' (7678 -7688) Perf (7696 -7726) ' Perf (7750 -7770) ' Perf (78047809) MEMORANDUM To: Jim Regg ~ ~"Z(o~jc~ P.I. Supervisor ~( t >FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, August 25, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2Z-23 KLTPARUK RIV UNIT 2Z-23 Src: Inspector NON-CONFIDENTIAL C~ Reviewed B P.I. Suprv J~ Comm Well Name: KUPARUK RIV UNIT 2Z-23 Insp Num: mitCS100823063208 Rel Insp Num: API Well Number: 50-029-22544-00-00 Permit Number: 195-010-0 Inspector Name: Chuck Scheve Inspection Date: 8/22/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well zz-z3 ' yT pe Inj. ~ W TVD ~ 5742 ~ IA 600 _ 2020 + ___ 1970 1960 / P.T.D 1950100+ TypeTest SPT Test psi 1500 QA ~ 240 390 390 390 Interval aYRTST p~F P + Tubing 1200 1200 lzoo ]zoo Notes: pre-test pressures were observed for 30+ minutes and found stable. Wednesday, August 25, 2010 Page 1 of 1 ~ ~''~ . . ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 3, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~` Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: j~, 4,~Ir ~. t~~ ~~~tt ~^~~ ~i~,~.,~~t:~!~' ~ +} : - ~ t~ ~ ~.:..> _~.~ • ~~~Y~~~~~.~ r '~11~ ~ ~~ ~~~#~ ~~~~~~~ ~'~,~ ~~ ~~~~ ~~~~ ~. ~~~+m~ssrar~ ~;3'!C~°'~P~~~ i(,~ ~rd'~ 1, 1 !~ ~~7 +" ~~ Enclosed please find a spreadsheet~ with a list of wells from the Kuparu.k 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 September 20~` and October 13~` 2009. The corrosion inhibitor/sealant was pumped October 15th and 315t + November lst and 2°a 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. ~mcerely, ~ Perry Klei~n~ ConocoPhillips Well Integrity Projects Supervisor • ~ ~ ~-~ ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 11/3/09 2C. 2D. 2Z & 3K Pad Well Name API # PTD # fnitial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitod sealant date ft bbls ft al 2C-01 50029209620000 1830830 17" NA 17" NA 2.12 10/15/2009 2C-02 50029209720000 1830930 12" NA 12" NA 2.97 7 0/15/2009 2C-03 50029209680000 1830890 10" NA 10" NA 3.82 10/15/2009 2C-04 50029209730000 1830940 17" NA 17" NA 2.12 10/15/2009 2C-05 50029209780000 1830990 18" NA 18" NA 3.4 10/31/2009 2C-06 50029209790000 1831000 28" NA 28" NA 7.65 10/15/2009 2C-08 50029209740000 1830950 27" NA 27" NA 6.8 10/15/2009 2C-09 50029212370000 1842210 22" NA 22" NA 5.1 10l15l2009 2C-10 50029212300000 1842140 54' 5.5 22" 10/13/2009 4.67 10/31/2009 2C-11 50029212310000 1842150 38' 5.3 26" 10/13/2009 5.52 10/31/2009 2C-12 50029212220000 1842060 25' 4,5 26" 10/13l2009 6.8 10/31/2009 2C-13 50029212230000 1842070 20" NA 20" NA 3.4 10/15/2009 2D-01 50029211940000 184171Q 38" NA 38" NA 6.8 10l31/2009 2D-07 50029211690000 1841430 20" NA 20" NA 2.12 10/31/2009 2D-09 50029211370000 1841030 28" NA 28" NA 4.67 10/31/2009 2D-10 5002921135~000 1841010 21" NA 28" NA 2.97 11/1J2009 2D-11 50029211340000 1840990 19" NA 19" NA 2.55 11/1/2009 2D-12 50029211310000 1840940 18" NA 18" NA 2.55 11/1/2009 2D-15 50029211840000 1841600 NS NA NS NA 1.7 11/1/2009 2Z-01A 50029209530100 2071110 14" NA 14" NA 1.7 11/1/2009 2Z-02 50029209600000 1830800 18" NA 18" NA 5.1 11/2/2009 2Z-03 50029209640000 1830850 24" NA 24" NA 5.5 11/2/2009 2Z-06 50029209570000 1830770 10'9" 2.5 7" 9/20/2009 2.12 11l1/2009 2Z-14 50029213610000 1851070 24" NA 24" NA 3.4 11/1/2009 2Z-16 50029213630000 1851090 20" NA 20" NA 1.7 11/1l2009 2Z-18 50029218840000 1881330 37'6" 6.5 39" 9/20/2009 8.9 11 /2/2009 2Z-22 50029225240000 1941470 16" NA 16" NA 5.95 11/1/2009 2Z-23 50029225440000 1950100 17" NA 17" NA 3.4 11/1/2009 3K-103 50029233920000 2081150 29" NA 29" NA 11.9 11/2/2009 3K-108 50029233950000 2081300 24" NA 24" NA 4.25 11/2/2009 MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg .-:-J . ( P.I. Supervisor {<..éfr '5 Ifc,( 07 DATE: Wednesday, August 15,2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 22-23 KUPARUK RlV UNIT 22-23 FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv 0êz-- Comm Well Name: KUPARUK RIV UNIT 2Z-23 API Well Number: 50-029-22544-00-00 Inspector Name: Jeff Jones Insp Num: mitJJ070814104739 Permit Number: 195-010-0 Inspection Date: 8/13/2007 Rei Insp N urn: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 22-23 [Type Inj. ! N TVD 5742 .v IA I 1350 I 2180 ! 2140 I 2140 I ! ! I I I ! I P.T. 1950100 iTypeTe~t! SPT Test psi 1500 /l'OA ! 0 ! 0 i 0 0 ¡ I I I Interval 4YRTST vP/F P ,/ Tubing I 700 i 700 i 700 ! 700 ! ! Notes: 1 BBL diesel pumped. 1 well house inspected; no exceptions noted. /' NON-CONFIDENTIAL SCf.b'iNED AUG 2 32007 Wednesday, August 15,2007 Page 1 of 1 MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Regg / I to P.I. Supervisor Kè'tl b C; 1& DATE: Wednesday, May 31, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA mc 2Z-23 KUPARUK RIV UNIT 2Z-23 Src: Inspector 0\0 ~( ,C\ FROM: Jeff Jones Petroleum Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv . 'jßf2-- Comm We)) Name: KUPARUK RIV UNIT 2Z-23 API Well Number 50-029-22544-00-00 Inspector Name: Jeff Jones Insp Num: miÚJ060530164658 Permit Number: 195-0 I 0-0 Inspection Date: 5/30/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. _. [Type Inj. r I I Wen ! 2Z-23 W ¡TVD 5742 I IA I 1430 ì 2000 i 1980 i 1970 ! ! P.T. ! 1950100 iTypeTest 1 SPT ! Test psi 1500 I OA I 640 I 700 i 700 i 690 i i ì I I Tubing i 2700 I 2700 ¡ 2700 I 2700 ! ¡ Interval 4YRTST PIF P i i Notes 0.6 bbls diesel pumped. 1 well house inspected; no exceptions noted. C ~A--¡ \ "\ -\ê 'Y\.aY-- \./Jä-l ;,;'¿,... / l:J e.U 0jR- ~.. ..;... Cè'¡1oV-l L <;'S 1<;.1 (S ,.t....."'-""¡f G ¿"c'¡c1...e,( 1'\ € e_':,~l~(i:,L <" J reI,) ><.,J "';" /IA,6{"1" cuL¿'(.v,¿;,.{e /L r'\', .,. () ::;',4-- P,>e<:;:,¿'v'{" f Ú;"ùr ------// -j-' ?'t">~Si,,\.>e:. () ...:~. ' 1<4í? /.;.{r;( 010 (~-ii''' I' ""i,\,~- ~- -'. ',,",,' ..1-'> ~'1'; "',. ,.', ',;,;?'\j";f'\;.Io'J,.,l t.¡ _ ." Wednesday, May 31, 2006 Page 1 of 1 Schlumbepger 08/24/05 NO. 3456 19Ç-OIO Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job# Log Description Date BL 1E-18 J/» j .. C ì t, 11015713 LEAK DETECTION LOG 08/06/05 1 1 F-01 J S)... -.J. j 'í 11047354 PRODUCTION PROFILE W/DEFT 07/31/05 1 1Y-06A 19-¡-i J '1 11015712 PRODUCTION PROFILE W/DEFT 08/05/05 1 3J-06 ¡ S:;- - ).. J if 11056679 PRODUCTION PROFILE W/DEFT 08/19/05 1 1Y-31 l 'l3 - 010 11015708 PRODUCTION PROFILE W/DEFT 08/03/05 1 1B-10 19í-jJjÞ 11056671 PRODUCTION PROFILE W/DEFT 08/12/05 1 3G-10 ¡Clt.-· c iJ~( 11056670 INJECTION PROFILE 08/11/05 1 2Z-23 } qÇe_()ID 11015717 INJECTION PROFILE 08/10/05 1 2X-06 S~ -if D 11015711 INJECTION PROFILE 08/04/05 1 2X-07 /If j ··'I).J 11015710 INJECTION PROFILE 08/04/05 1 1 Y -04 / J 3 - , G. L 11047351 INJECTION PROFILE (REDO) 07/27/05 1 SIGNED: µoiLJ DATE: SCANNEC SEP 072005 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Kuparuk Color CD ~ -' ~d7°- \¡ $- ~~ S~· . dì- MEMORANDUM TO: Randy Reudrich Commissioner THRU: Jim Regg "'~{i~ P.I. Supervisor FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission ~ ~//2-~/o~ DATE: May 14, 2003 ~\7~\(~>'X SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska Inc. 2Z Pad 2Z-22, 2Z-23 KRU Kuparuk River Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. P.T.D.I 1941470 ITypetestl P ITestpsil 1500 I Casingl 1075I 2950I 2870I 2825 I P/F I P I Notes: Test fluid' 3.5 bbls diesel. I j. Packer Depth Pretest Initial 15 Min. 30 Min. vv "l I I ITMI I I I'°° I' ' rw'l P.T.D.I 195010 Type testI P I Testpsil 1500 I CasingI 400 I 24001 23701 23501 P/F I P I Notes: Test fluid: 2 bbls diesel. I Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover D= Differential Temperature Test O= Other (describe in notes) Test's Details May 14, 2003: I traveled to ConocoPhillips Alaska's Inc.'s (CPAl) Kuparuk River Field injection wells 2Z-22 and 2Z- 23, to' witness 4 year MIT's. Jared Break was the CPAI representative for the tests today. The pretest pressures on each well were monitored and found to be stable and the standard annulus pressure tests were then performed with both wells passing their MIT's. I inspected both well houses and no exceptions were noted. Summary: I witnessed successful MIT's on CPAI's water injection wells 2Z-22 and 2Z-23 in the Kuparuk River Field. Two well house inspections conducted. ,/// M.I.T.'s Performed' 2_ Number of Failures: _0 Total Time during tests' 2_ Attachments: Wellbore schematics (2) ' cc: MIT report form 5/12/00 L.G. MIT KRU 2Z-22, 2Z-23 5-14-03 JJ.xls 5/20/2003 ARCO Alaska, Inc. A NIP (493-494, ~ 0D:3.500) NIP (7289-729O, 0D:3.500) PBR (7299-73OO, 0D:3.500) PKR (7313-7314, 0D:6.151) Pen' (7400-7418) Pen' (7445-7495) SLEEVE (7553-7554, 0D:3.500) PKR (7571-7572, 0D:6.151) NO GO (7587-7588, 0D:2.875) TUBING (7568-7597, 0D:2.875, ID:2.441) Pen' (7678-7688) Pen' (7696-7726) Pen' (7750-7770) Pen' ~7804-7809) GKA 2Z-23 2Z-23 APl: 500292254400 SSSV Type: Camco 'DS' Landing I Nipple Annular Fluid:I Reference Log:I Last Tag:17716 Last Tag Date:l 3~25~00 Well Type: I INJ Orig Completion: 12/12J95 Last W/O:] Ref Log Date:I TD:17972 ffKB Max Hole Angle:143 deg @ 6372 Angle @ TS: 142 deg @ 7401 Angle @ TD: 40 deg @ 7972 Rev Reason: Tag fill, close CB-1 I bY ImO Last Update: 13/26/00 I Casing String - CONDUCTOR Size I T°P I 16.000 0 Casing String - SURFACE Size I T°P [ 9.625 0 Bottom TVD 121 121 Bottom ] 'I'VD 4242 3465 Casing String - PRODUCTION Size ] Top 7.000 0 Bottom TVD 7960 6232 Tubing String - TUBING 3.500 0 7568 5933 2.875 7568 7597 5955 Wt Grade Thread 62.58 H-40 Wt Grade Thread 40.00 L-80 Wt Grade Thread 26.00 L-80 Wt I Grade I Thread 9.30 L-80 EUE ABM 6.50 J-55 EUE ABM Perforations:Summary Interval TVD Zone Status Feet SPF Date Type Comment 7400-7418 5807-5821I UNIT I I 181 1213/30/951PERF 30deg. phasing, SWS41/2"HSD HJ 7445- 7495 5841 - 5879 -3,C-2,C- 50 12 3/30/95 IPERF 30 deg. phasing, SWS 4 1/2" HSD HJ II 7678- 7688 6017- 6025 ~ A-5 ~ 10 4 3/30/95 IPERF 180 de.q. phasing, SWS 4 1/2" Ultrapac 7696 - 7726 6031 6054 ! A-4 ~ I 301 4 3/30/95 IPERF 180 deg. phasing, SWS 4 1/2" Ultrapac 7750- 7770 6072- 6087 ! A-3 / 20/ 413/30/95 IPERF 180 deg. phasing, SWS 4 1/2" Ultra[ac 7804 - 7809 6113 - 6117 ! A-3 | I 51 413/30/9511PERF 1180 deg. phasing, SWS 4 1/2" Ultrapac Gas :LiffMandtelsNal~es stn MD TVD Man Man ~ Vifr vType VOD Latch Port TRO Date VIv I I I Mfr I Type Run Comment 1 7246 5692 Camco MMG-2 DMY I 1.5 RK 0.000 0 5/6/95 2 73571 57751 Camco l MMM I I DMY I 1.5 Othef::(~lU:gS; e~uip~, ~ti:.) ;:JEWELRY ii :. :. Depth TVD 'Type Description ID 4931 492 NIP Camco'DS' Landing 2.812 72891 57241 NIP Camco 'W-I' Selective 2.812 7299 5732 PBR Baker 3.000 7313 5742 PKR Baker 'FHL' 3.000 75531 59221 SLEEVE Camco 'CB-l' Sliding SLeeve (No Go Profile); CLOSED 3~25~2000 2.750 7571/ 59361 PKR TIW 'SS' 3.250 75871 59481 NO GO Otis 'XN' Nipple 2.250 7596/ 59551 SOS Baker 7597/ 59551 TTL 2.441 2.441 General :NOtes:; : Date Note 2/11/00 Partia obstruct on ~ 7613' (see 2111/00 WSR) PERMIT 95-010 95-010 95-010 DATA CBL CON/FINAL .L~5850-7788 CDR/FINAL '-L':--4100-7900 95-010 USIT ....-L~4100-7900 ,-"L-"'5850-'7816 Page: 'i Date: 12/'01/96 RUN DATE_RECVD 1 03/07/95 1 03/30/95 1 03/30/95 1 03/;07/95 Ar'e dr'y ditch samples r'equ~red'? Was the well cored? yes _~ Are we '11 Well is COMMENTS tests r'equi red? yes in compliance Initial ~ ~ . .~_ ........... ,# ~/..~ yes I(~) And r'ecei ved? ye~---~ An_alysis & description r'ece~'ved?.~_tLe-s--- no n~__~Rece'"i ved? yes no --' ALASKA OIL AND GAS CONSERVATION COM 'SION WELL COMPLETION OR RECOMPLETION REPORT-.AND LOG ,- 1 Status of Well Classih~Catj~n.{)fService Well .-' ? OIL ~ GAS C~ SUSPENDED C~] ABANDONED [--] SERVICE r~] Classification chan~jed/to WAG In.i, ector 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 95-10 3 Address 8 APl Number P.O. Box 100360, Anchoracje, AK 99510-0360 50-029-22544 4 Location of well at surface ' -~;~'~1~ 9 Unit or Lease Name 1304' FSI_, 334' FEL, Sec. 11, T11 N, R9E, UM ~ Kuparuk River Unit At Top Producing Interval i~lt~~. 10 Well Number ~.. H~. 2Z-23 At Total Depth J.---..~.~,~---~- ~ 11 Field and Pool 1036' FSI_, 235' FWL, Sec. 11, T11 N, R9E UM KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. RKB 41', Pad 71'I ADL 25646, ALK 2577 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp, or Aband. 15 Water Depth, if offshore 116 No. of Completions Feb. 5, 1995 Feb. 10, 1995 March 31, 1995 (CompI) NA feet MSLI 1 7972' M D & 6242' TV D 7870' M D & 6163' TVD YES r'~ NO ,._, NA feet MD 1 APPROX 22 Type Electdc or Other Logs Run GR, CDR, CDN, CCL, USIT, CBT 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT GRADE TOP BTM HOLE SIZE CEIVENT luECORD 16" 62.5" H-40 Surf 121' 24" +_200 sx ASI 9.625" 36" J-55 Surf 4242' 12.25" 890 sx ASIII Lead, 480 sx Class G tail 7" 26" L-80 Surf 7960' 8.5" 338 sx Class G Tail 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2', 9.3#, J-55 7597' 7571' 4 spf 7804'- 7809' MD 6113' - 6117"1'VD 4 spf 7750' - 7770' MD 6072' - 6087' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 4 spf 7696' - 7726' MD 6031' - 6054' 'I'VD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 4 spf 7678' - 7688' MD 6017' - 6025' TVD 12 spf 7445' - 7495' MD 5841' - 5879' TVD 12 spf 7400' - 7418' M D 5807' - 5821' TVD 27 PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD 1~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. I ECEIVED A!aska 0Jj & ~as Cons. Anchorc , ~ Form 10-407 Submit in duplicate Rev. 7-1-80 ~ ON REVERSE SIDE ~ 30. 1' ~OGIC ~RS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 7401' 5808' Base Kuparuk C 7501' 5883' Top Kuparuk A 7669' 6010' Base Kuparuk A 7847' 6146' R'ECEIVED JUN -9 1995 Alaska 0il & Gas Cons. Commission · Anchor, .~, LIST OF Al-rACHMENTS I hereby certify that the foregoin0 is true and correct to the best of my knowleoe. Signed~~ ~I~~-- ~ "~..~"~, ~ Title~[ ~ ~,, ~ ~o DATE ~::)/~ ~_ ~'~'"' INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- . ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 05/01/95 Page: 1 ARCO Alaska Inc. DAILY DR/LLING REPORT WELL:2Z-23 RIG:PARKER 245 WI: 55% SECURITY:0 WELLID: AK8079 AFE: AK8079 TYPE:DEV AFE EST:$ OM/ 1860M AREA/CNTY:NORTH SLOPE BOROUGH STATE:AK API NUMBER:50-029-22544 FIELD: KUPARUKRIVER SPUD:02/05/95 START COMP: FINAL: 02/06/95 (1) TD: 1370'(1370) SUPV:RLM 02/07/95 (2) TD: 4252'(2882) SUPV:RLM 02/08/95 (3) TD: 4252' ( 0) SUPV: JT 02/09/95 (4) TD: 7410'(3158) SUPV:JT 02/10/95 (5) TD: 7945' (535) SUPV: JT 02/11/95 (6) TD: 7945'( 0) SUPV:JT 02/12/95 (7) TD: 7874'( 0) SUPV:JT MW: 9.3 PV/YP: 21/33 APIWL: 11.4 DRILLING Move from 2Z-22 to 2Z-23. Accept rig at 1630 hrs. 2/5/95. Spud well at 2130 hrs. 2/5/95. Directional drill 12.25" hole from 121' to 1370'. DAILY:S134,040 CUM:$134,040 ETD:SO EFC:$134,040 MW: 10.0 PV/YP: 18/12 APIWL: 7.8 TRIP. POOH TO RUN 9.625 CSG. Directional drill 12.25" hole 1370' to 4252'. High line power failure; bearings in brake linkage damaged trying to stop top drive and drill string. Bearings replaced w/o down time. Short trip to heavy drill pipe. Pumped out from 1650' to 1150' due to swabbing. Hole circulated clean. Accident %2; Parker employee; reports filed. DAILY:S77,485 CUM:$211,525 ETD:SO EFC:$211,525 MW: 8.6 PV/YP: 2/ 1 APIWL: 20.0 RIH Run 109 jts of 9-5/8", 40%, L-80, BTC casing to 4241'. Cement casing w/308 bbls of lead cement and 97 bbls of tail cement. Test all BOPE. DAILY: $175,117 CUM: $386,642 ETD:SO EFC: $386,642 MW: 11.4 DRILLING Drilled f/4262' to 7410'. DAILY:SO CUM:$386,642 PV/YP: 19/ 6 APIWL: 4.8 ETD:SO EFC:$386,642 MW: 11.4 DRILLING Drilled f/7410' t/7945'. DAILY:S98,245 CUM:$484,887 PV/YP: 30/20 APIWL: 4.4 ETD:SO EFC:$484,887 MW: 11.4 PV/YP: 26/14 APIWL: 3.8 RUNNING CASING Drilled f/7945 t/7972. Held safety meeting and run 7", 26%, L-80, BTC-Mod casing as per plan. DAILY:S96,407 CUM:$581,294 ETD:SO EFC:$581,294 MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 MOVING RIG Run 158 jts 7", 26%, L-80, BTC-Mod casing as per plan. DAILY: $202,344 CUM: $783,638 ETD: $0 EFC: $783,638 RECEIVED JUN 9 I A.%ska Oil & 6~.s Cons, Comr~]is~ion Anchor~ , Date: 05/01/95 Page: 2 ARCO Alaska Inc. DAILY DRILLING REPORT REMEDIAL AND COMPLETION OPERATIONS WELL: WELLID: AK8079 AREA/CNTY: FIELD: SPUD: RIG:NORDIC WI: 0% SECURITY:0 AFE: AK8079' TYPE:DEV AFE EST:$ OM/ OM STATE: API NUMBER: START COMP: FINAL: 03/29/95 (8) TD: 7972' PB: 7870' SUPV:DEB MOVING RIG MW: 11.4 NACL/NABR Released rig from 1R-33 @0500 hfs, 3/29/95. Moving rig to 2Z-23. DAILY:S12,600 CUM:$12,600 ETD:SO EFC:$12,600 03/30/95 (9) TD: 7972' PB: 7870' SUPV:DEB PERFORATING MW:ll.4 NACL/NABR Accept rig @ 1130 hrs, 3/29/95. Test BOPE. Test 7" casing. Perforate 'A' and 'C' sands. 5 guns shot as of 0600. DAILY: $39,052 CUM: $51,652 ETD:SO EFC:$51,652 03/31/95 (10) TD: 7972' PB: 7870' SUPV:DEB RUNNING 3-1/2" COMPLETION ASSEMBLY MW: 11.4 NACL/NABR Continue perforating 'A' and 'C' sands.RIH and set packer. Run 3-1/2" selective single completion assembly. DAILY:S95,517 CUM:$147,169 ETD:SO EFC:$51,652 04/01/95 (11) TD: 7972' PB: 7870' SUPV:DEB RIG RELEASED MW:ll.4 NACL/NABR Stab seals into TIW packer. Locate out & verify position with weight indicator. Pressure tubing to 350 psi & verify tubing & seal assembly integrity. Pressure up to 2500 psi & set Baker 'FHL' packer. Test tubing to 2500 psi, OK. Test annulus to 2500 psi, OK. Set BPV. Test packoffs and tree, OK. Secure well. Release rig. DAILY:S96,343 CUM:$243,512 ETD:SO EFC:$243,512 End of WellSummary for Well:AK8079 RECEIVED PA~ ~,~, ~,~**** ****--*************************************** **~***~*~ SUR~EY ANALYSIS COMPANY ARCO ALASKA WBLL HAME 2Z-23 LOCA?ION 1 I(UPAR~ LOCATION 2 ALASEA ~ATE: lO-FEB-?5 ~NETIC BECLIHA?ION 28~68 GRID COHVERGEHCE AHOLE 0,00 I~LL HUMBER 0 MD ft ft dec~ 121.0 121.00 165.0 165,00 0,50 259,0 258.96 2,25 281,3 281,20 0,68 373,7 373,35 2,11 ~7.1 558,9 648.6 739,4 82?,5 921,7 1012.2 1102,1 1194,6 1290,4 466.0? 2,60 5"56,47 643,87 2,91 731,3~ 1,63 817,36 2,15 904,28 2,10 988,51 1,87 1070,80 2,6t 1153,17' 3,64 1235.63 3,56 1382,8 1312,09 3,42 1475.4 1385,95 2,65 1569,6 1458,24 2,76 1754,4 1597,94 -O,g6 1942,8 1741,17 -0,07 2219.5 1949,2~ 1+~ 2.502,1 2159,66 -0,13 2781,7 2368,30 -0,15 3062,1 2577,41 0,24 3344,0 2788,44 -0,76 3538,0 3814,4 4097,5 4170,6 4410,4 4691,3 4970,5 5250,5 5528,4 5809,4 2934,10 0,45 3141,26 -0',31 3354,99 -0,66 3410.55 -0,15 35?2,82 0,11 3804,91 0,74 4012,38 1,32 4218,34 -0.01 4423,12 -0,22 4631,14 -0,38 60?O,8 4840,b-5 -0,28 6371.6 5047,61 1,46 6653,5 5253,61 -0,33 6934,6 ~60,93 -0+64 7215.8 5669,96 -0,16 ************* AHADRILL SURVEY ANALYSIS .************* CIRCULAR ARC CL~I~ CHG I RAT AZIt CHG CUMA~ CH(; deg. deg/lOOft deg deg 2Z-23 ll~BN_RA?E CI~SUF~ I~OL_FACF. DI~ deg/lOOft ft deg deg/lOOft 0,00 0,00 0,00 0,00 0,50 1,14 191,00 191,00 434,09 2,75 2,35' 58.00 249,00 &l,70 3,43 3,04 11,00 260,00 49,38 5,53 2.28 -5,62 254.38 23,73 -6,34 -2,45 2,03 1,08 8,14 2,79 22,17 276,55 11.72 3,90 -5,82 270,73 14,63 3,24 -2,20 268.53 16,26 1,79 1,84 2/'0,37 18,41 2,39 0,98 271,35 0,26 -0,i2 1,59 -2,51 20,51 2,28 0,24 271,~) 22,38 2,07 -0,11 271,48 25,19 3,13 1,43 272,?1 28,84 3,94 -0,54 272,36 32,40 3,72 -2,41 269+96 DLSET d~/lOOft~*2 41,61 0,23 -6,33 262,85 41,30 -0,11 2,5? 265,44 40,63 -0,23 -1,16 264,28 40,49 -0,20 -1,84 262,44 40.~ 0.05- 0.93 263.37 -3,26 0,94 -0,41 -2,52 0.39 41,34 0,26 1,17 264+53 42,66 0,47 3,30 267,84 . 42,65 -0,01 -1,13 266,71 42,43 -0,08 0,12 266,83 42,04 -0,14 -0,13 266,70 0,42 1,18 -0,40 0,04 -0,05 41,77 -0,10 0,04 266,74 43,22 0,52 0,41 267,15 42,89 -0,12 ~0,04 267,1I 42,06 -0,30 -1,32 265,79 41,89. -0,06 -t.~5 264,43 0,01 0.15 -0.01 -0,47 -0,48 35.82 3,71 -1,50 268,46 38,46 2,85 -0,21 268.25 41,22 2,?3 0,27 268,52 40,56 -0,36 -1,16 267,~ 40,49 -0,04 3,00 270,37 , 41,95 0,53 -1,84' 268,52 41,82 -0,05 1,67 270, I9 41,68 -0,05 0,82 2.71,01 41,92 0,0? -5,8? 265,13 41,16 -0,27 4,05 269,17 -I,62 -23,04 14,43 3,82 0,12 -0+22 -24,75 2,75 2.86. 1,03 0,29 -26,64 3,70 2,94 0,08 -0,63 -29,48 131,67 0,55 1.29 1,59 -20,72 20,04 1,04 0,26 -0,67 -43,31 40,51 0,69 0,13 0.59 -52,38 97.13 0.40 0,10 0,2? -65,38 105,17 0,20 0,07 -2,10 -70,15 86,64 1,40 0,43 1,44 -34,32 93,18 0,?9 0.15 2,58 56,76 3,92 1.71 0,78 18,52 4,05 0,14 -0.26 10,85 3,29 0,85 -1,48 17.61 1,87 1,~6 2,76 14.57 2,41 0,59 -6,09 2,27 2,28 0,14 -8,93 1,21 2,07 0.23 -12,49 12,25 3,19 1,25 -16,90 4,12 3,95 0,82 -3,48 8,12 3,93 0,02 -70,54 86,21 2,17 0,61 -62,69' 101,36 0,63 0,56 -57.06 131.44 0,36 0,10 -54,37 97,68 1,65 1,77 -71.89 107.32 0.26 0.58 -35,81 46,43 0,38 0.04 -34,53 60.34 0,92 0,19 -36,76 91,48 0,27 0,23 -37,33 159,71 0,08 0,07 -44,31 79.90 0,14 0,02 -36,27 0,00 0,I0 0,01 -39.42 10.82 0,53 0.15 -41,19 177,81 0,12 0,15 -40,72 133,78 0,43 0,11 -37,88 168,13 0,33 0,04 0,00 0,00 0,00 0,19 0,00 1,14 2,58 1,27 67.65 2,68 1.64 1.50 46,80 4,02 6,03 0,00 0,00 2,33 1,84 P,~:E ilO, 3 2Z-23 ************* ANAl)RILL ********mx-**** SlaY ANALYSIS .************* CIRCULAR ,~C M~THOD******** ~ TUD INC_C~ CL~It~_CHG I_RATE AZM_CHG CUMAZM_CHG I1JRN_RATE CIJ3SUEE TDDL_FACP. DLS I)LSI~? ft ft deg deg deg/lOOft deg deg deg/lOOft ft deg. deg/lOOft deg/lOOft.x~2 7402,8 ~09,37 -0.15 41.74 -0.08 -0,74 263.70 -0.~ 7~?0,6 59~.45 -0,93 40.82 -0,49 0,51 264.21 0,27 7777.0 6092,37 -0,80 40,02 -0,43 -0,36 263.84 -0,19 7870.6 6164,04 0,05 40.07 0,05 1,22 265,06 1.30 PREk~E~I'~ TO T~ 7972,0 6241,65 0.00 40.07 0,00 0.54 265.60 0.53 -30,33 107,17 0,27 0,03 -24,60 160,32 0.53 0,13 -19,17 16;3.72 0,45 0.04 -16,~ 86,73 0,84 0,42 -35,85 100,62 0,~ 0,4~ ARCO Alaska, Inc. · -j Date' March 24, 1995 Transmittal #: 9216 RETURN TO: ARCO Alaska, Inc. Attn: Bdan Hebert Kuparuk Operations File Clerk ATO-1119 B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are t.he following open hole items. receipt and return one signed copy of this transmittal. Please acknowledge c~ ~--/5'~1R-33 c/.~...~ ~:~.., 1R-34 ,~ 5'-' t-E, 2T-21 c]5'---'/,.3' 2T-21 c/~- 1 _/-./-~1 R-32 ...2Z-23 ~'5''~ ltJ 2Z-23 CDR Final Pdnt CDR Final Pdnt CDR Depth Corrected CDN Depth Corrected Slim GR MWD Depth Corrected CDR Depth Shifted CDN Depth Shifted . ¢~,./z ,, ,,_.~2Z-22' CDR Depth Shifted ~'"/'7' (/2Z-22 CDN Depth Shifted Acknowledged:~~, ~~ 12/28/94 1/13/95 Feb16-21/95 Feb16,21/95 Dec11 - 14/94 Feb7-10/95 Feb7-10/95 Feb1-4/95 Feb1-4/95 Date: Ref#95009 Ref#95060 Ref#95077 Ref#95077 Ref#95024 Ref#50-029-22544 Ref#50-029-22544 Ref#50-029-22524 Ref#50-029-22524 DISTRIBUTION' Mr. Vernon E Pringle, Jr. (Geology) DeGIoyer and MacNaughton One Energy Square Dallas, TX 75206 Sharon AIIsup-Drake DS Development ATO- 1205 RECEIVED MAR ~ 0 ~995 Clifton Posey Ge~le~la 0J! & Gas Cons. C0mmlssIorl ATO 1251 Anchorage Erickson/Zuspan NSK Central Files NSK 69 ~·Larry Grant (+Sepia) AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Sandy Lemke ATO 1336 ARCO Alaska, Inc. Date' March 3, 1995 Transmittal Cf: 9205 RETURN TO: ARCO Alaska, Inc. ATTN: Brian Hebert Kuparuk Operations File Clerk ATO-1119B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following Cased Hole items. receipt and return one signed copy of this transmittal. 2Z-23 2Z-23 2Z-22 Kuparuk River Unit 2/20/95 Cement Bond Log CBT Kuparuk River Unit 2/20/95 Ultrasonic Imager Cement Log USIT Kuparuk River Unit 2/21/95 Cement Bond Log CBT Kuparuk River Unit 2/21/95 Ultrasonic Imager Cement Log USIT Receipt ' ~~ Acknowledge te' DISTRIBUTION' Sharon AIIsup-Drake DS Development ATO-1205 Larry Grant (+sepia) AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Please acknowledge 5850-7788 5850-7816 6200-8166 6200-819O RECEIVED MAR 7 1995 Alaska 0il & Gas Cons. Commission E ricksoll~l~ NSK Central Files NSK-box 69 AI~kSKA OIL AND GAS · CONSERVATION COMMISSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 February 1, 1995 Michael Zanghi Drill Site Dev. Supervisor ARCO Alaska, Inc. P O Box 100360 Anchorage, AK '99510-0360 Re: Kuparuk River Unit 2Z-23 ARCO Alaska, Inc. Permit No: 95-10 Sur. Loc. 1304'FSL, 334'FEL, Sec. 11, TllN, R9E, UM Btmhole Loc. 1023'FSL, 216'FWL, Sec. 11, TllN, R9E, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill dOes not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field pager at 659-3607. Chairman BY ORDER OF THE COMMISSION dlf/Enclosures _ .. cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA Ab.~KA OIL AND GAS CONSERVATION COMMI ON PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill D lb Type of Well Exploratory ~] Sb'atigraphic Test D Development Oil X Re-Entry r'~ Deepen O Service D Development Gas O Single Zone X Multiple Zone r-~ 2., Name of Operator 5. Datum Elevation (DF or KB) 10. F~eld and Pool ARCO Alaska, Inc. RKB 41', Pad 71' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25646, ALK 2577 4. Location of well at surface 7. Unit or property Name 1 1. Type Bond (see 2O AAC 25.O25) 1304' FSL, 334' FEL, Sec. 11, T11N, R9E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET) 8. Well number Number 1048' FSL, 639' FWL, Sec. 11, T11N, R9E, UM 2Z-23 #U-630610 At total depth 9, Approximate spud date Amount 1023' FSL, 216' FWL, Sec. 11, T11N, R9E, UM 2/2/95 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MO and 'I'VD) property line 2Z-16 8028' MD 216'~ TD feet 14.9' ~ 100' MD feet 2560 6268' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 300' feet Maximum hole angle 42.2° M~x~rnsur~ace 2056 pslg At total depth (TVD) 3300 P~ 18. Casing program Settin~i Depth size Specifications Top Bottom Quanfi~ of cement Hole Casing Weight Grade Coupling Len~lth MD TVD MD TVD tinclude stac~e dataI 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' ±200 CF 12.25" 9.625" 36.0# J-55 BTC 4216' 41' 41' 4257' 3473' 890 Sx Arcticset III & HF-ERW 480 Sx Class G 8.5" 7" 26.0# L-80 BTCMOE 7987' 41' 41' 8028' 6268' 3005x ClassG HF-ERW Top 500' above Kuparuk 1 9. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet ' Casing Length Size Cemented .~ t"~ Measured depth True VerticaJ depth Conductor Surface Intermediate Production Perforation depth: measured ~['~'~3~' '.,~ true vertical ~, ~J~, ~ ~3,-~ 20. Attachments F~ling fee X Property plat D BOPSketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot D Refraction analysis D Seabed report D 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~[~/~... ~/~~/~ Titleuse Drill Site Dev. Supervisor Date Permit Number I AEl.~mber ~" See cover letter for ES--- ! 0 I 5 0- 0,~ C/ _ p, ~5''-/"/ ' 0 (' ? 5 other rec~uirements Conditions of approve' Sam~es r~quired I--i Yes ~ No M~d ~og ~equ~red I--I Yes i~ No Hydrogen sulfidemeasures D Yes r~ No Directional survey required ~ Yes [~ No Required working pressure for BOPE [~] 2M ~' 3M ~ 5M [~ 10U [~] 15M Other:Original Signed By - evid W. Johnston order of © ! _. Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 GENERAL DRIllING PROCEDURE KUPARUK RIVER FIELD 2Z-23 , . . . . . . . 10. 11. 12. 13. 14. 15. 16. 17. 18. Perforate and run completion assembly. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig. Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (4,257')according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole to total depth (8,028') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 7" casing. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) ND BOPE. NU tubinghead & full opening valve for cased hole logging. Secure well and release rig. Run cased hole cement evaluation. ND full opening valve and NU master valve and cap. Move in and rig up Nordic #1. Install and test BOPE. Pressure test 7" casing to 3500 psi. Set and pressure test packer. DRILLING FLUID PROGRAM Well 2Z-23 Spud to 9-5/8" surface casing Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids 9.0-10.0 15-25 15-35 50-80' 5-15 15-4O 10-12 9.5-10 __.10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Weight up to TD 11.4 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 2,056 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 2Z-23 is 2Z-16. As designed, the minimum distance between the two wells would be 14.9' @ 100' MD. Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of the last well drilled. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The annulus will be sealed with 225 sx of cement followed by Arctic pack upon completion of fluid pumping. Risks in the 2Z-23 drilling area include lost circulation and high pressures in the Kuparuk formation. Lost circulation above the Kuparuk will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. The 7" casing will be topset above the Kuparuk and a 5" liner run to TD if lost circulation cannot be controlled with LCM and reduction of circulating pressure alone. Efforts to reduce Kuparuk geopressure at the target location and careful analysis of pressure data from offset wells show that a mud weight of 11.4 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 9-5/8" casing shoe will be tested to an equivalent mud weight of 12.5 ppg upon drilling out of the surface casing. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. ARCO ALASKA, Inc. Structure : Pod 2Z Well: 2S Field : Kuparuk River Unit Location : North Slope, Alaska !Created by : jones For: D PETRASI-I Date plotted : lO-Nov-9¢ Plot Reference is 23 Version #6. Coordinotes ore in feet reference slot True Verticol Depths ore reference RKB. --- Baker Hughes INTEQ 300 _ 300 600_ _ gOO_ _ 1200_ _ 1500_ _ _ 2100_ _ 2400_ _ 2700_ _ $000_ 3600_ ~00_ _ 4200_ _ 4500_ _ 4800_ _ 5100_ _ 5400_ 5700_ 6000_ 6300 6600 3OO I I <-- West 5100 4800 4500 4200 3900 3600 3300 3000 2700 240~ 21 O0 1800 1500 1200 900 600 i ESllldATEDI~BELEVA130N:l13,1 I I I I I I I I I I f I I I I I I I I I I I I I I I I I I I I TD LOCATION:I KOP TVO=300 TMD=300 DE~=O _ . . - - - - 1, .oo . ..... 18.00 I~d~n 3 OE'~ / ~,.oe \ \ / / ,., ~.oo I sec. ~1, T, lU. ~S I ~ ~.00 ~ 42.~ E~ ~D=1~2 ~D=1706 D~=494 ~0=7~96 ~ D~=4~15 ~ SO~H 256 , WEST 4307 . DEG W t ~.u s~ ~ P S 34 ~K SNOS ~27~ ~D~26 DEP~2 . B/ W ~ ~DS ~=3273 ~D=3987 D~=2026 K--IO ~--3773 ~D-~62 DEP-2479 _ ..... A~RAGD ANGLE Scale 1 · 150.00 300 0 300 I I I I i 6oo 5oo ESTIMATED SURFACE LOCAI'K)N: 1304' FSL. 334' FEL SEC. 11. T1 IN. RgE Vertical Section on 266.60 azimuth with reference 0.00 N, 0.00 E from slot #23 Scale 1 : 150.00 i i i i I i i i i i i i i i i i i i i i ~ t i i i i I i i i i i i 300 600 900 1200 1500 1 $00 21 00 24~O 2700 3000 3,7,003600 3900 4200 4.500 4800 5100 . , uti ~ G~S Go~s. Oom...iss'to~'m'~ 42.17 DEG ~ ~D=62~ DEP=~38 T~RG~ - T/ ZON~ D ~=5800 ~D=7396 DE~={315 ~ ~ ~ ~/ ZONE A ~=5999 TM0=7665 OEP=4495 B/ KUP SNOS ~0~0 ~0~828 ~=4~ ~ ~ ,ARCO ALASKA, Inc. Structure : Pod 2Z Field : Kuparuk River Unit Location : North Slope, Alaska, <-- West Scole l. 20.00 600 560 520 48~) 440 400 360 .t20 280 240 200 160 ! 20 80 40 0 40 80 120 160 200 241) I I I I I [ I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 1 ' X /51~ ~ 17~ 1720 16~. _1~ _ 1560 _ I 5~ ,,.~. '~ :!~'t!i~, ~, _,,~ 12~. . ~ I1~ ~1~ /,:: ~. ~ ~ ¢~-'~'/'- x,x I I I I I I I I I ~ 560 520 ~ 4~ ~ 5~ 520 2~ 2~ 2~ ~ ~ ~ 20 ~ 40 0 ~ ~ 120 ~ ~ 200 <-- West Scale I 2000 ,ARCO ALASKA, Inc. Structure : Pod 2Z Field : Kuparuk River Unit Location : North Slope, Alaska, <~ West Scde 1 2o.oo 1360 1320 1280 1240 1200 1 I$0 1120 1080 1040 1000 g$o 920 880 840 800 760 720 680 640 600 ,560 520 16801 184'0l 1560t !520fl , 1~80. 440. 1400. · 1320. 124o~--- PROPO~ 1200. 11601 1120.~ 1040 !000 960 92O 880 _ 0 c',t 840 .. -~ 8oo ~ 17O0 {6,*0 1700 !1600 1800 1560 1320 12~) 1240 1200 1160 1120 1080 10~0 1000 960 020 880 840 800 760 720 680 640 603 560 520 <-- West : oo 520 Casing Design / Cement Calculations 23-Jan-95 Well Number: 2Z-23B Surface Csg MD: Surface Csg TVD: Production Csg MD: Production Csg 'FVD: Top of West Sak, TMD: Top of Kuparuk, TMD: Top of Target, C Sands, TVD: Estimated Pressure: Surface Casing Choice: Production Csg Choice: Production Casing Frac. Pressure 4,257 ft 3,473 ft 8,028 ft 6,268 ft 3,326 ft 7,396 ft 5,813 ft 3300 psi i2:~?~iii~?~ii?~ii?:i~i~:iiii?~ii?~i~i~?:?~!~iiii::?:i~i:~i~i~iiiii!i~ii~ii~i~i~i~:i~i~i:~i!i:~?~iii!iii!?~iii!iii ** See Page 4 3,500 psi Maximum anticipated surface pressure TVD surface shoe = 3,473 ft {(13.5'0.052)-0.11}*TVDshoe =[ 2,056 psiI Estimated BH pressure at top of target zone Estimated Pressure= Top of Target, TVD = Overbalance, psi= Anticipated Mud Weight = 3,300.0 ppg 5,813 ft 150 psi 11.4 PPgl Surface lead: Top West Sak, TMD = 3,326 ft Design lead bottom 500 ft above the Top of West Sak -- 2,826 ft Annular area = 0.3132 cf/If Lead length * Annulus area = 935 cf Excess factor = 85% Cement volume required = 1,729 cf Yield for Permafrost Cmt = 1.94 Cement volume required =[ 890 sxJ Surface tail: TM D shoe = 4,257 ft (surface TD- 500' above West Sak) * (Annulus area) = 448 cf Length of cmt inside csg = 80 ft Internal csg volume = 0.4257 cf/If Cmt required in casing = 34 cf Total cmt = 482 cf Excess factor = 15% Cement volume required = 555 cf Yield for Class G cmt = 1.15 Cement volume required =1 480 sx! Casing Design / Cement Calculations 23-Jan-95 Production tail. TMD = 8,O28 ft Top of Target, TMD = 7,396 ft Want TOC 500' above top of target = 6,896 ft 5" casing tail top (100' above C sand) =[ 8,028 ftJ 5" Annulus area (9" Hole) = 0.3054 7" Annulus area (9" Hole) = 0.1745 (5" Casing Top-TOC)*7" Annulus area + (5" to TD)* 5" Annulus area = 198 cf Length of cmt wanted in csg = 80 ft Internal csg volume = 0.0997 Cmt required in casing = 8 cf Total cmt = 206 cf Excess factor = 75% Cement volume required = 360 cf Yield for Class G cmt -- 1.19 Cement volume required =[ 300 sxJ TENSION - Minimum Design Factors are: T(_~b)=l.5 and T(j~)=I.I~ Surface (Pipe Body): Casing Rated For: Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (WEft) Buoyancy = Weight of displaced mud Length Casing Wt (lb/fi) Dead Wt in Air Buoyancy = Tension (Pipe Body) Design Factor Surface (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (WEft) Buoyancy -- Weight of displaced mud Casing Rated For: Length = Casing Wt (lb/fi) = Dead Wt in Air -- Buoyancy = Tension (Joint Strength) = Design Factor =[ Production (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (WEft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (lb/fi) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =! Production (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (WEft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (lb/fi) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =[ 916000 lb 4,257 ft 40.00 Ib/ft 170280.0 lb 28907.3 lb 141372.7 lb 979000 lb 4,257 ft 40.00 lb/fi 170280.0 lb 28907.3 lb 141372.7 lb 6.9! 604000 lb 8,028 ft 26.00 Ib/ft 208728.0 lb 35930.0 lb 172798.0 lb 3.5] 667000 lb 8,028 ft 26.00 Ib/ft 208728.0 lb 35930.0 lb 172798.0 lb Casing Design / Cement Calculations 23-Jan-95 BURST- Minimum Design Factor = 1.1 Surface Casing: Burst = Maximum surface pressure Casing Rated For: Max Shut-in Pres = Design Factor =1 5750 psi 2056.0 psi 2.8J Production Csg: 1. Design Case - Tubing leak while well is SI Inside pres=Csg Frac pres (3500 psi)+Mud Wt*.052*TVD Outside Pres=Backup Gradient (8.9ppg *0.052*TVD) Net Pressure = Pressure inside-Pressure outside Design Factor = Rating / Net Pressure Casing Rated For: Inside pressure Outside Pressure Net Pressure Design Factor 7240 psi 7220 psi 2901 psi 4319 psi 1.71 COLLAPSE - Minimym Design Factor = 1.0 Surface Casing 1. Design Case - Lost circulation and Fluid level drops to 2000' TVD with 9.0 # Mud 2. Ext. Pres=Mud Wt*0.052*TVD-(2000'TVD of 9# Mud) Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =1 3090 psi 0.593 Ib/ft 1125 psi~ 2.71 Production Csg 1. Worst Case - Full evacuation of casing 2. Mud weight on outside = Mud Wt * 0.052 * TVD Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =1 5410 psi 0.593 Ib/ft 3720 psi 1.51 Casing Design / Cement Calculations 23-Jan-95 Surface Casing Choices OD ID Ib/ft Grade Metal X-Section Jt Strength Body Strength 1 9.625 8.681 47 L-80 13.5724 sq. in. 1161000 lb 1086000 lb 2 9.625 8.835 40 L-80 11..4538 sq. in. 979000 lb 916000 lb 3 9.625 8.921 36 J-55 10.2545 sq. in. 639000 lb 564000 lb 4 10.750 9.950 45.5 J-55 13.0062 sq. in. 931000 lb 715000 lb Collapse Burnt 4750 psi 6870 psi 3090 psi 5750 psi 2020 psi 3520 psi 2090 psi 3580 psi Production Casing Choices OD ID Ib/ft Grade Metal X-Section Jt Strength Body Strength I 7.000 6.276 26 L-80 7.5491 sq. in. 667000 lb 604000 lb I 5.000 4.276 18 L-80 5.2746 sq. in. 376000 lb 422000 lb 2 7.000 6.276 26 J-55 7.5491 sq. in. 490000 lb 415000 lb Collapse Burst 5410 psi 7240 psi 10490 psi 10140 psi 4320 psi 4980 psi ' 'UPARUK RIVER UNI', 20" DIVERTER SCHEMATIC 6 4 3 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. . MAINTENANCE & OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" CONDUCTOR. 2. SLIP-ON WELD STARTING HEAD. 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE. 4. 20" - 2000 PSI DRILLING SPOOL WITH ONE 16" OUTLET. 5. ONE 16" HCR KNIFE VALVE WITH 16" DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20" - 2000 PSI ANNULAR PREVENTER. ~.~sCa u~'~ & GaS Gons. Oorn~ss'~oa DKP 11/9,~J4 , 6 13 5/8" 5000 PSI-? OP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. ?_ ASSURETHAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER UMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST I I 1. FILL BOP STACK AND MANIFOLD WiTH WATER. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE UNE VALVES. ~ CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE UNES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, UNES, AND CHOKES WiTH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BUND RAMS AND TEST TO 3000 PSI FOR 3 MINUTES. BLEED TO ZERO PSI. 10. OPEN BUND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND ENES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI FOR 3 MINUTES. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD 11" - 3000 PSt CASING HEAD 3. 11' - 3000 PSI X 13-5/8" - 5000 PSi SPACER 4. 13-5/8" - 5(X30 PSI PIPE RAMS 5. 13-5/8" - 5000 PS~ DRLG SPOOL W/ CHOKE AND KILL UNES & 195/8" - 5000 PSi DOUBLE RAM W/ PIPE RAMS ON TOP, BUND RAMS ON BTM 7. 13-5J8" - 5000 PSI ANNULAR WELL PERMIT CHECKLIST oo,. H o UNIT# PROGRAM: exp [] dev~ redrll [] serv [] ON/OFF SHORE 0 ~/ ADMINISTRATION DATE ENGINEERING APPR DATE GEOLOGY DATE 1. Permit fee attached ................... 2. Lease number appropriate ............... 3. Unique well name and number .............. 4. Well located in a defined pool ............. 5. Well located proper distance from drlg unit boundary. 6. Well located proper distance from other wells ...... · 7. Sufficient acreage available in drilling unit ...... 8. If deviated, is wellbore plat included ......... 9. Operator only affected party .............. 10. Operator has appropriate bond in force ......... 11. Permit can be issued without conservation order ..... 12. Permit can be issued without administrative approval. 13. Can permit be approved before 15-day wait ........ 14. Conductor string provided ............... ~ N 15. Surface casing protects all known USDWs ........ N 16. CMT vol adequate to circulate on conductor & surf csg..~ N 17. CMT vol adequate to tie-in long string to surf csg . . . Y 18. CMT will cover all known productive horizons ...... N 19. Casing designs adequate for C, T, B & permafrost .... 20. Adequate tankage or reserve pit ............ N 21. If a re-drill, has a 10-403 for abndnmnt been approved..-Y-----N- 22. Adequate wellbore separation proposed .......... ~-~- -- ~ N ~/~ ~ ~~ · ~~ ~. ~ - ~~_~__ 23. If diverter required, is it adequate .......... N 25.24. BOPEsDrilling fluid pr°gram schematic & equip list adequate i YYY~ Nadequate ' N 26. BOPE press rating adequate; test to ~'~:>~:~:> psig.~ N " 27. Choke manifold complies w/API RP-53 (May 84) ...... 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............. Y 30. Permit can be issued w/o hydrogen sulfide measures .... Y N 31. Data presented on potential over~Tess~re zones ..... Y N 32. Seismic analysis 9f s~s zones .......... Y N 33. Seabed conditio~~vey (if off-shore) ......... Y N 34. Contact ~/phonefor weekly progress reports ..... Y N [exploratory only] GEOLOGY: ENGINEERINC: COMMISSION: T~ '"~,~ ~,- Comments/Instructions: HOW/Jo - A:~FORMS~cheklist rev 03/94 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. ALASKA COMPUTING CENTER *mmmmmmmmmmm~mmmmmmmmmmmmmmmm* *------- SCHLUMBERGER -------* RECEIVED MAY O~ lgg~ ~asJ~a Qil,a Gas Oonl~, i~mitt~§~h COMPANY N~ME : ARCO ALASKA, INC, WELL NANE : 2Z-23 FIELD ZA~E : KUPARUK 'RIVER UNIT BOROUGH : NORTH SLOPE STATE : ALASKA API MU~BER g. 50-029-22544-00 REFERENCE NO : 9504[ IS Ca¢,e Verification l, istinq Chlumberger AlasKa ComPut!no Center 17-APR-1995 13:47 **** REEL HEADER **** SERVICE NAME : EbIT DATF : q5t03/!6 OPICIN : FL!C REEl, NAME : 95063 CONTINUATION ~ : PREVIOUS REFL : CON~ENT : ARC~ ALASKA, I~C.,KUPARWK R1VE~ UNIT, ~Z-23. 50-029-22544-00 **** TaPE HEAOER **** SERVICE NA~E : EDIT DATF : 95/03/16 O~IGIH ~ FLIC T~P~ NA~E : 950~3 CONTIMU~TI[]~ # ~ 1 P~EVIOUS TAPE CO~ENT : ARCO ALASKA, I[~C.,~PAR~K RIVER [INIT, 2Z-2], 50-029-22544-00 TAPF HEADER KItPARUK RIVER MWD/M~D bOGS # WELL NA~E: API NUMBER: OPERATOR: LOG~IMG COMPANY: T~PF CREATION DATE: JOB DATA LO~GING ENGINEER: SURFACE LOC~TION SECTION: TOWNSHIP: FNL: FWL~ ELEVATION(FT FROM MSt, O) KELLY BUSHING: PER,ICE FLOOP; GROUND LEVEL: WELI, CASING RECORD BIT R!JN ! 9~063 NICObS !$T STRING ~N~ 8T~ING 2Z-23 500292254400 ARCO At, ASKS. lb-MAR-95 BIT RUN 2 BIT RUN 3 1 1 9~ 1304 334 TOPDRIVE 111.60 70.60 OPEN HOLE CASING DRILLERS BIT SIZE (IN)SIZE (IN) DEPTH 9.625 424~,0 PAGE: TaPe verification !.0istinq 17-APR-19g5 1]:47 ~CblUmberger Alaska Comput~n~ Center 3RD ST~I~G PRODUCTION STR!~G R~RKS: DRILLED INTER¥~L: 424~' - 7972' WFLI. DRILLED 7-FEB THROUGH lO-FEB-95 $ LIS FORMAT DATA LIS FORMAT DATA PA~E: 2 FILF NA~E : EDIT ,001 S~RVICE ~ FLIC VERSION : 00~CO1 FIDF TYPE : LO LAST FILE : FIL~ WEADER FILE NUMBER: 1 EDITED ~ERGED MWD Depth $~lited and clipped curves; all bit DFPT~ ! CREME~T: 0 5000 F!LF SD~ARY LDW~ TOOL CODE START DEPTH STOP DEPTH [;[''''''''''' '''''''''''4~30,0 ''''''''''7830,0 CDN 4230 0 7900,0 BaSE.LINE CUR¥:E FUR SHiFTS~ .GRCH,CBT CURVE $~IFT DATA (MEASURED DEPTH) 88888,0 7738~0 7716:,~ 7707,, 7593,5 7564 5 7403 0 7383 5 7353 0 7304 0 7279 5 7~45 5 ----------EQUIVALENT UNSHIFTED DEPTH-----,----. GR 88881.5 773~o5 7710,5 770~,5 7681.0 7667.0 7605,5 7588.0 7557 5 7375,5 7345.0 7~96,5 727!,5 7238.0 IS Tape verification I, ist~n~ ChlUm~erger Alaska Computino Center 17-APR-1995 13:47 7! 71 7{) 70 70 7O 69 68 67 67 67 67 66 66 66 64 6O 59 45.0 77 5 44 5 27 0 92,5 57,0 22.0 82,0 63,0 32 5 06:0 91.5 81 0 30 5 68 0 83 0 53 5 32 5 31 0 33 5 83 5 71 0 53!5 O0 0 ~ER~ED DATA SOURCE LDWG TOO[, CODE CDR CON 7137.0 7127,0 7o~0.0 7070.0 7037.5 70~9,5 6985.0 6848,5 6774.0 6756,5 6725.5 6699.0 6684.0 6672,5 6546.5 6460,0 6175,5 6346,0 6223 5 6022[0 5924 5 5874.5 5863.0 5847,0 93,5 BIT REiN Mil, ERGE T:Op !, 4230,0 1 4230,0 MERGE B~SE 7830,0 7900,0 THE DEpT){ ADJUSTMENTS SHOWN ABOVE REFLECT T~E MWD GR TO THE CBT/GR (PDC RAN WITH MAGNETIC MARKED bINE) DATED 20 FEB-95,.~ ALL OTH~ CURVES WERE C~RR'IED WiTH THE GR S~FT, THIS F~LE CONTAINS THE VERY ENHANCED ORO PROCESSED RESISTIVITY DATA WITH 2' AVERAGE THE GRCH'CBT IS INCLUDED IN THIS FILE, $ # LIS FORMAT DATA PAGE{ 3 ,IS Tape VerXficattoD I.,istinq ~Chlumberger Alaska Computing Center 17-APR-1995 13:47 DATA FORMAT SPECIFICATIO~ RECORD ** ** SET TYPE - 64EF ** TYPE REPR CODE VALUE 1 6~ 0 2 66 0 3 73 60 4 66 5 66 6 73 7 65 8 68 0,5 9 65 FT 11 66 17 1~ 68 13 66 0 14 65 FT 15 66 68 16 66 I 0 66 0 ** SET TYPE - CHAN ** .... ,........................,.-......,......,.......-........................ NAMM ERV U IT SERVICE API lPI AP' AP1 FILE NU B NUMB SIZE REPR PROCESS ID ORDER # bOG TYPE CLASS MOD NUMB SA~P ELEM CODE (HEX} DMPT FT 61~1R3 O0 000 O0 0 I I ! 4 68 0000000000 G/C3 610183 O0 000 O0 0 ~ 1 1 4 68 0000000000 RHOB DRHO ~WO G/C] 619183 O0 000 O0 0 1 I 1 4 68 0000000000 PEF ~WD BN/E 619183 O0 000 O0 0 1 1 1 4 68 0000000000 CALN ~WD IN 61918~ O0 000 O0 0 1 1 1 4 68 0000000000 NPH! M~D PU-S 619183 O0 000 O0 0 1 I 1 4 68 0000000000 RA ~WD OHMM 619183 O0 000 O0 0 1 I 1 4 68 0000000000 RP ~WO OHMM 619183 O0 000 O0 0 1 1 1 4 68 0000000000 DER ~WD OHMM 619183 O0 000 O0 0 1 1 I 4 68 0000000000 V~P ~WD OHMM 619183 0'0 000 O0 0 I 1 1 4 68 0000000000 VRA UWD OHMN 6191~3 O0 000 O0 0 I 1 1 4 68 0000000000 ROP ~O FPHR 619183 O0 000 O0 0 1 1 1 4 68 0000000000 GR ~0 GAPI 619183 O0 000 O0 0 1 1 1 4 68 0000000000 F~T ~WD HR 6191~3 O0 000 O0 0 1 i 1 4 68 0000000000 GRCH CBT GAPI 6191~3 O0 000 O0 0 1 I t 4 68 0000000000 PAGE: ** DATA ** DMPT, C~LN ~D DE~'~WD GR.NWD 999o2~0 NPHI,MWD 999~250 RA,MWD -999 ~50 .. MWD '999.250 VRP,MWD 099.~50 VRA'MWD -999 250 ROP MWD '999.250 FET.MWD -99o.250 GRCH.CBT -999 ~50 -999.: 50 t7,437 I8 Tam_e Ver$.fication List~.ng 17-AP~-1995 13:47 Chlumberger Alaska Computing Center PAGE: DEPT, 4095.000 ~HOB.~qwD -999,250 DRHO,MWD C~LN,~WD -9Q9,250 NPHi,~WD 58.300 ~A,MWD DEP.~w~ -999.250 ~RP.~qwD -ggg,250 VRA,MWD GR,~WD -999,250 FET.~WD -999,250 ~BCH,CBT END ~W DATA =999 250 -999~250 -999,~50 -999,250 PEF,MWD RP,~WD ROP,~WD -999,250 -999.250 -999.250 **** FILE TRAILE~ FIL~ NAME : EDIT ,001 SERVICE : FLIC VFRSION : 001COl DAT~ : o5/0]/16 M~X REC SIZE : 1024 FIL~ TYPE : L~Sv FILE **** FILE HEADER FILE NAME : EDIT ,002 VERSION : oo1co! DAT~ : 95/03/16 M~X REC SIZE : FILE.TYPE : LO LAST FILE : FILF ~E&DER FIL~ NUMBER 2 RAW 'MAD Curves and log header data for each bit run in separate files, BIT RUN NUMBER: I D~PTH INCREMENT: 0,5000 FIb~ SUMMARY LDWG TOOL CODE START DEPTM . ................. .... CD~ 423 CDf~ 4~30,0 $ LOG HEADER DATA DATE LOGGED: SOFTWA~E~ SURFACE SOFTWAR~ VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (M~MORY or REAS-TIME): TD D~ILLER (FT): TOP LOG INTER'VAb (FT): STOP DEPTH 00,0 7~ 30.0 7'FEB'95 FAST 2.5 MEMORY 7972 0 4~30:0 ~IS Tape verification Listing ;chlumberger AlasKa Computing Center 17-APR-~995 13:47 ~OTTO~ bOG INTERVAL (FT): FIT ROTATING SPEFD (RP~): uOLE INCLINATION (DEG) ~INIMU~ ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RES! IVIT¥ CON NEUTRON/POROSITY $ 80REHOLE AND CASING DATA OPEN HOLE BlT SIZE (IN): DRILLERS CASING DEPTH (FT): POREHOtE CONDITIONS MUD TYPE: ~UD DENSITY (LB/G]: MUD VISCOSITY MUD ~UD CHLORIDES (DP~)~ FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OH~M) AT TEMPERATURE (DEGF)~ ~UD AT MEASURED TEMPERATURE (MT): ~UD ~T MAX CIRCUbATIMG T~MPERATURE ~UD FILTRATE AT (MT): MUD CAKE AT (~T): NEUTRON TOOb MATRIX: MATRIX DENSITY: HObE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ)~ RF, M~RKS: 7972.0 TOOL NUMBER RGSO 1 NDS052 8 5OO 11,40 155.0 2,300 1,690 SANDSTONE 2.65 1'ooo ******* RUN 1 ********** DRII, LED I~'TERVAL 4252' RESISTIVITY MEASURE~ED]T 6~,04~ FRO~ BIT GAMMA RAY MEASURE~E~! 5.46 F OM BlT D~NSITY M~AS~RE~EMT 3 ,14' FROM BIT NEUTRON ~EASURE~,~ENT 1~9,1~' FROM BIT # LIS FORMAT DATA 84.0 84.0 PAGE: IS Tape Veriflcatlon Listt. nq chlumberger AlasKa ComputiDO Center 17-APR-!9o5 13:47 PAGE{ ** ~A FOR~T SPMCIFICATXOM RECORD ** ** SET TYPE - 64EB ** TYPE REP~ CODE VALUE ) 66 0 2 66 0 3 73 64 4 66 5 66 6 73 7 65 8 68 0,5 9 65 FT 1! 66 16 12 68 13 66 0 14 65 FT !5 66 68 16 66 1 0 66 ! #mmmmmmmmmmmmm#mmmmmmmmm~mm RO$~ DPO~ DRH~ LWl PEF LW1 DCAL TNPM LW1 ATR PSR D~R ROP LWl GR CALN TAB Lwl TaBD ** SET TYPE - CMAN ** ........... .... ..... . .... ..-............,.-.........,,-..........-....... NAME SERV UN ...SERVICE API API API Ap! FILE NU B NUMB SI REPR PROCESS ID ORDE~ ~ LOG TYPE CLASS ~OD NUmB SAMP ELMS CODE (HEX) ............ ooooo oo ...... .............. ;;""""'""'"oooooooooo G/C3 619183 O0 000 O0 0 2 I I 4 68 0000000000 PU 619183 O0 G/C3 619183 O0 BN/E 619183 O0 IN 619183 O0 PU 619183 O0 OHM~ 619183 O0 OHM~ 61918~ O0 OMM~ 61918 O0 FPHR 61918~ O0 GAPI 619183 O0 IM 619183 O0 OHM~ 619183 O0 M~ 619183 O0 HR 6191~3 O0 000 O0 0 ~ I I 4 68 0000000000 000 O0 0 2 I I 4 68 0000000000 000 O0 0 2 1 1 4 68 0000000000 000 O0 0 ~ I I 4 68 0000000000 000 O0 0 2 1 I 4 68 0000000000 000 O0 0 2 1 1 4 68 0000000000 000 O0 0 ~ 1 I 4 68 0000000000 000 O0 0 ~ I I 4 68 0000000000 000 O0 0 2 I I 4 68 0000000000 000 O0 0 2 I I 4 68 0000000000 000 O0 0 2 I I 4 68 0000000000 000 O0 0 2 I I 4 68 0000000000 000 O0 0 2 I I 4 68 0000000000 000 O0 0 2 I 1 4 68 0000000000 . DFPT 7971,000 PEF~LWl -999,250 PS~,LWI -999,250 C~LM, LW1 -999.250 ~ . b W 1 DER bWl SM LW! '"999,25 0 .-.999,25'0 ..999"250 ~I8 Ta~e Verification Llstln~ ,ChlUmberger AlasKa Computing Center 17-APR-!995 13:47 PAGEt DEPT. 4101.500 ROS2.LW! -999.250 DPOR.LW1 PEF.LW1 -999.250 DCAL.LW1 -999 250 TNPH.LWl PS~.[.,W~. -999.250 OER.LW1 -999~250 ROP.LW1 CAL~.LWI -999.250 SN.LW! -999.250 TAB,LW! -999,250 58.300 AT~.LWl -999.950 GReLW1 -999.~50 TABD.LW1 -999.250 -999,250 -999,250 -999,250 **** FILE TRAILER FILE ~A~E : EDIT .002 SERVICE = FLIC V~RSION : O01CO1 D~TF : 95/03/16 MaX R~C SIZ~ : 1024 FIL~ TYPE : LO LAST FILE **** TAPE TRAILER ***, $~RVICE NAME : EDIT DATK : 95/03/~6 TAPE ~A~E : 9506] CONTINUATION # : 1 PREVIOUS TAPE : CO~E~T : ARCO ALASKA, INC.,KUPARUK RIVER UNIT~ 2Z-23, 50-029-22544-00 **** REEL TRAILER SERVICE NAME : EDIT DATE : 95/03/~6 ORIGIN : FLIC EEY NA~E : 95063 ONTINUATION # : PREVIOUS RE~5 COMMENT : ARCO ALASKA, INC,,KUPARUK RIVER UNIT, 2Z-23, 50-029-22544,00
