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Home My WebLink About197-222 . • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 micElvar February 14, 2011 AMNED FEB 2 5 &LANK cal Commissioner Dan Seamount Gas Coos. Cession Alaska Oil & Gas Commission AtilCilWe►Qa 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 _ \\ e Commissioner Dan S am ount: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement 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 corrosion inhibitor /sealant was pumped February 10 -12, 2011.The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907 - 659 -7043, if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Kuparuk Field Date 2/15/2011 1B,1D,1E,1Q,1Y13F,3G,3J PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date e ft ; ; itls ft gal 1B -01 50029204650000 1800400 SF N/A 19" N/A 1.4 2/11 /2011 1D-119 D -119 50029228360000 1972220 2" N/A 23" N/A 4.2 2/10/2011 1E -117 50029232510000 2050260 12" N/A 12" N/A 4.2 2/12/2011 1E -121 50029232380000 2042460 6" N/A 18" N/A 4.4 2/12/2011 1Q-21 50029225910000 1951330 5" N/A 5" N/A - 5.2 2/12/2011 1Q-22 50029225950000 1951400 5" N/A 5" N/A 3.2 2/12/2011 1Y-06A 50029209580100 1971340 6" N/A 6" N/A 5.2 2/12/2011 1Y -08 50029209440000 1830620 6" N/A 6" N/A 3.3 2/12/2011 3F -19A 50029226800100 2040160 8" N/A 8" N/A 3.4 2/11/2011 3G -16 50103201350000 1901040 16" N/A 18" N/A - 3 2/11/2011 3J -17 50029227000000 1961460 SF N/A 19" N/A 3.3 2/11/2011 i • • 10. 1G-01 — AA 2B.035 issued 7/30/2008. 9. 1 F -16A — Well name is 1 F -16A. IA DD failed 4/12/2007, but MITs are listed to have passed since. Well last injected 4/2007. AA 2B.018 was issued in October 2007, but no injection has occurred into the well. Looking at the pressure plot, it is shown that the IA pressure appears to have been bled off in October and November. Was there well work conducted, maybe plug setting? There is email traffic exchanged regarding "what if" for an OA pressure sensor. Such have been installed on other wells, is that possible here? What are the plans for the well? 8. 1D-40A — Well name is 1D-40A. MITIA failed -- 10/1/2009. Well last injected 9/09. -- -� 7. 1D-119 — Single casing well. MITIA failed 7/16/2010. Well last injected 6/2010. 6. 1D-106 — Single casing well. MITIA failed 7/16/2010. Well last injected 6/2010. Comments on the sheet indicate you have located the deep leak. 5. 1C-133 — Single casing well. MITIA failed 5/21/2010. Well last injected 5/2010. 4. 1C-10 — AA 2B.036 issued 8/25/2008. From: Maunder, Thomas E (DOA) Sent: Monday, January 03, 2011 11:13 AM To: 'NSK Problem Well Supv' Cc: NSK Well Integrity Proj SIANNED JAN 0 2011 Subject: RE: ConocoPhillips Monthly Injector Report - Dec 2010 Martin, et al, I am conducting a review of December's Monthly report. I have just gotten started and wanted to pass back the comments /questions I am developing. I also am doing some editing /formatting on the spreadsheet to facilitate printing it off when necessary. I have only edited the 1A -07, 1A -12 and 1 B -02 in the attached spreadsheet. The edits are highlighted in yellow. Can these changes be accommodated without a lot of hassle ?? Thanks in advance for looking at this. Tom Maunder, PE AOGCC 3. 1 B -02 — TxIA communication reported 5/6/09. Well last operated 6/09. 2. 1A-12 — AA 2B.049 issued 6/9/2010. 1. 1A -07 — It is noted that an MITIA failed on 11/13/09, however I have not been able to find that information in our files. I have an email from July 28,2009 that reports failure of a diagnostic MITIA, that the well will be SI, added to the monthly report and diagnostic troubleshooting will begin as soon as feasibly possible. On December 15, 2009 it was reported that a surface casing leak was suspected and that the well is SI and on the monthly report. According to our injection records, the well has not operated since April, 2008. From: NSK Problem Well Supv [ mailto :n1617 @conocophillips.com] Sent: Saturday, January 01, 2011 10:55 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: ConocoPhillips Monthly Injector Report - Dec 2010 • • ConocoPhillips Well 1D-119 Injection Data • Tbg Psi IA Psi • OA Psi I 4000 3500 3000 - . 15) 2500 U) a 2000 x 1500 1000 - 500 0 - - — - - - - — - - - - — 09/10 10/10 11/10 12/10 01/11 Date J PTD 197 -222 Single casing (monobore) well. Reason: Failed MITIA 7/16/2010 Well last injected 6/10 08/14/10 - Set plug at 3804' to secure well • • ConocoPhillips Well 1D-119 Injection Data • Water Injection *Gas Injection I 4000 3500 - 3000 - .2) 2500 - N Q a 2000 - 2 1500 - 1000 - 500 1 0 0 0.2 0.4 0.6 0.8 1 Injection Rate, bwpd or mscfpd Date of Water Gas Injected Tubing IA Pressure OA Pressure Injection Injected (mscfpd) Pressure (psi) (psi) (bwpd) (psi) 31- Dec -10 0 0 473 59 0 30- Dec -10 0 0 474 59 0 29- Dec -10 0 0 472 59 0 28- Dec -10 0 0 471 59 0 27- Dec -10 0 0 476 59 0 26- Dec -10 0 0 483 59 0 25- Dec -10 0 0 488 59 24- Dec -10 0 0 494 59 23- Dec -10 0 0 500 59 0 22- Dec -10 0 0 514 59 21- Dec -10 0 0 515 59 20- Dec -10 0 0 508 59 19- Dec -10 0 0 502 59 0 18- Dec -10 0 0 498 59 0 17- Dec -10 0 0 502 59 16- Dec -10 0 0 509 59 15- Dec -10 0 0 514 59 14- Dec -10 0 0 509 59 13- Dec -10 0 0 511 59 12- Dec -10 0 0 507 59 0 11- Dec -10 0 0 506 59 10- Dec -10 0 0 509 59 9- Dec -10 0 0 508 59 8- Dec -10 0 0 505 59 7- Dec -10 0 0 505 59 6- Dec -10 0 0 510 59 5- Dec -10 0 0 515 59 • • 4- Dec -10 0 0 516 59 0 3- Dec -10 0 0 524 59 2- Dec -10 0 0 531 59 1- Dec -10 0 0 527 60 0 30- Nov -10 0 0 526 59 29- Nov -10 0 0 538 59 28- Nov -10 0 0 543 59 27- Nov -10 0 0 545 59 26- Nov -10 0 0 548 59 0 25- Nov -10 0 0 551 60 24- Nov -10 0 0 555 59 23- Nov -10 0 0 558 59 22- Nov -10 0 0 554 59 21- Nov -10 0 0 553 59 0 20- Nov -10 0 0 551 59 19- Nov -10 0 0 549 59 18- Nov -10 0 0 553 60 0 17- Nov -10 0 0 546 59 0 16- Nov -10 0 0 541 60 0 15- Nov -10 0 0 540 60 0 14- Nov -10 0 0 551 60 13- Nov -10 0 0 569 60 12- Nov -10 0 0 572 60 0 11- Nov -10 0 0 574 60 10- Nov -10 0 0 575 60 9- Nov -10 0 0 580 60 0 8- Nov -10 0 0 584 60 7- Nov -10 0 0 585 60 6- Nov -10 0 0 588 60 5- Nov -10 0 0 592 60 4- Nov -10 0 0 586 60 0 3- Nov -10 0 0 585 60 0 2- Nov -10 0 0 590 60 1- Nov -10 0 0 593 60 31- Oct -10 0 0 593 60 30- Oct -10 0 0 592 60 0 29- Oct -10 0 0 590 60 28- Oct -10 0 0 585 60 27- Oct -10 0 0 591 60 26- Oct -10 0 0 593 60 25- Oct -10 0 0 597 60 24- Oct -10 0 0 598 60 23- Oct -10 0 0 598 60 0 22- Oct -10 0 0 597 60 21- Oct -10 0 0 592 60 20- Oct -10 0 0 600 60 19- Oct -10 0 0 601 60 0 18- Oct -10 0 0 598 60 0 17- Oct -10 0 0 595 60 0 16- Oct -10 0 0 595 60 15- Oct -10 0 0 596 60 14- Oct -10 0 0 597 60 • • 13- Oct -10 0 0 597 60 12- Oct -10 0 0 596 60 11- Oct -10 0 0 596 60 10- Oct -10 0 0 594 60 9- Oct -10 0 0 594 60 8- Oct -10 0 0 595 60 7- Oct -10 0 0 604 60 0 6- Oct -10 0 0 608 60 5- Oct -10 0 0 609 60 4- Oct -10 0 0 608 60 0 3- Oct -10 0 0 607 60 2- Oct -10 0 0 605 60 • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Setting Record: 1D-119 Run Date: 8/14/2010 r~h~y •~.~ ~ ;', 1 t, ~ r > .. August 16, 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 1D-119 Digital Data in LAS format, Digital Log Image file 50-029-22836-00 1 CD Rom 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.wo lliu~ co.~... ~f~ ~~~ l~~! W ~~ ~ ,~ ~~ ~ ; , Date: 1 ~~ L ~ s Signed: ill ~~ :~. ~~1~°~°° c Page 1 of 1 Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.com] Sent: Sunday, July 18, 2010 3:26 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj; CPF1 Prod Engr; CPF1 DS Lead Techs; Gang!, Melissa A; Pierson, Chris R Subject: 1D -119 (PTD# 197 -222) Report Of Failed MITIA Attachments: 1D-119 Wellbore Schematic.pdf; 1D-119 TIO Plot.pdf Jim/Tom /Guy, West Sak injector 1 D -119 (PTD# 197 -222) failed an MITIAs on 7/16/10 as witnessed by Bob Noble. The well has been shut in since 6/5/10 for reservoir pressure management and will remain so until the communication can be repaired. The well will also be added to the monthly injector report. Attached are a wellbore schematic and 90 TIO plot. Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907 - 659 -7224 Cell 907 - 943 -1720 / 1999 Pager 907- 659 -7000 #909 241000 JAN 0 2 1/3/2011 Well Name 1D-119 Notes: Report Of Failed SW MITIA End Date 8/1/2010 Days 120 Start Date 4/3/2010 Annular Communication Surveillance 1200 WHP -- — - 160 IAP OAP 140 WHT P m t 1000 1 120 800 I -- 100 LL • - cm 0 0. 600 80 w - 60 400 40 200 — 20 0 , -0 Apr -10 May -10 Jun -10 Jul -10 450 a 400 _ . DGI 350 - MGI a 300 -" E ., 250 - ..'SWI 200 BLPD U 2 150 -d 100 50 0- i 1 Apr -10 May -10 Jun -10 Jul -10 Date MEMORANDUM To: Jim Regg / P.I. Supervisor l ( ~ l z~" ~ i ° FROM: $ob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, July 23, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC ID-119 KUPARUK RIV U WSAK 1D-119 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~_ Comm Well Name: KUPARUK RIV U WSAK 1D-I 19 Insp Num: mitRCN100718141413 Rel Insp Num: API Well Number: s0-029-22836-00-00 Permit Number: 197-222-0 Inspector Name: Bob Noble Inspection Date: 7/16/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1D-n9' Type Inj. N i TVD 3564 IA 10 10 P.T.D 19n22o ~ TypeTest SPT Test psi ]soo '~ OA Interval avRTST p/F F ~ Tubing sus sus Notes: pumped 5 BBLs of fluid and no increase in pressure. So I told Jim to load the well and bleed off the gas and we would do it later. n,, ~ r ~, ~'~~~ ~' ,~I t~s :~ 1 L` `t' Friday, July 23, 2010 Page 1 of 1 Fy~~ L Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ~/ /~ i UGU~- -- ~ ~~ ~. „~; Log Description `~,e'~~114a ~~ 6~9 b~wX, NO. 5125 • Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 03/03/09 3H-33 604C-00006 USIT _ 02/09/09 1 1 1 D-130 ANHY-00049 INJECTION PROFILE l~ •.: GI's - 02/12/09 1 1 2A-26 ANHY-00053 PERF/SBHP SURVEY ~ _ - C. (• ~ 02/16/09 1 1 3H-33 AYS4-00039 SFRT - 02/23/09 1 1 3C-06 8146-00005 GLS C! '- ~ 02/23/09 1 1 2N-318 8146-00006 SBHP SURVEY _ / ~ (} 02/24/09 1 1 3H-33 B04C-00006 SONIC SCANNER - i' (~ 02/09/09 1 1 3J-06 8146-00008 PRODUCTION PROFILE _ 02/27/09 1 1 1 D-119 AYS4-00044 INJECTION PROFILE ~ _. ~ ,~ 02/28/09 1 1 3G-03 AYS4-00043 PRODUCTION PROFILE - t' - 02!27/09 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317: Thank you. ~~~ L~ TR~411/ll~/T1`,4L ProActive Diagnostic 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. lease 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 . Anchorage, AK 99518 Fax (907) 2458952 ,1 Caliper R ce 2) MTT MTT 25-Feb-09 1 D~119 1 Report / E~ 50-029-22836.00 25-Feb-09 1 D-122 1 Report r ~_ ,_._ ~~ ~. __-- I ~ ~r - ~ ~ ~~~~ ~~' f; /' ~i , ~t i / ~~, + ~ ti ! ,~ ,- Signed : ~ ~ ! ~ ~ ~ ` -~, Print Name: - ---- -_--- -_ Date 50-029-22905-00 -~, =JJ PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245$8952 E-WAIL : ~~ ~~. . ~~ q ~;~ ~'3C~': $:~i~ ;3~ WEBSITE r;xJv,~ ~ ~~ ~~ "r3~ ,~~3 s --_-~ - C:\Doctunen~ and Settings\Owns\Desktop\Transmit_Conow.docx ~~ • • Memory Caliper & Magnetic Thickness Taal Log Results Summary Company: ConocoPhillipsAlaska, Inc. Well: 1D-119 Log Date: February 25, 2009 Field: Kuparuk Log No.: 10542 State: Alaska Run No.: 4 (2"d MIT/3'~ MTT) API No.: 50-029-22836-00 Pipet Desc.: 3.5" 9.3 Ib L-80 ABM-EUE Top Log Intvl.: Surtace Pipet Use: Tubing Bot. Log Intvl.: 3,880 Ft. {MD) Pipet Desc.: 5.5" 15.5 Ib L-80 MBTC Tap Log Intvl.: Surface Pipet Use: Production Casing Bot. Log Intvt.: 210 Ft. (MD) Pipe3 Desc.: 16" 62.58 Ib. H~40 Welded Top Log Intvl.: Surface Pipe3 Use: Conductor Pipe Bot. Log Intvl.: 121 Ft. {MD) '~ ^ Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS The caliper log is tied into the YK1 Nfpp/e @ 3, 736' (Drfl/er's Depth), white the MTT data is tied info the 1 Mandrel Hanger @ 0'. This is the second time this well has been logged with a PDS caliper and the third time with the 12 Arm Magnetic Thickness Tool (MTT). The Magnetic Thickness Tool responds to the total thickness of metal of the 3.5" tubing and 5.5" production casing, with some influence from the 16" conductor pipe. Passes at SHz, 8Hz, 10Hz and 12Hz were made at 20 fpm, with the 5Hz pass selected for analysis in this report. Due to the concentric pipe strings in the log interval, the MTT response is qualitative -indicating an overall increase or decrease in metal surrounding the tool, but not distinguishing in which pipe string the change in ' metal thickness occurs. '' INTERPRETATION OF CALIPER LOG RESULTS This log was run to assess the condition of the 3.5" tubing and liner with respect to corrosive and mechanical damage. The caliper recordings indicate that the 3.5" tubing and liner appear to be in good to poor condition, with a maximum penetration of 57% recorded in a line of pits in joint 55 (1,736'). Recorded damage appears in the form of isolated pitting, often in a line, and shallow corrosion. No significant areas of cross-sectional wall loss or I.D. restrictions are recorded. The caliper recordings indicate buckling from surface to -3,680'. A 3-D log plot of fihe caliper recordings across an interval of buckling from surface to 1,000' is included in this report. This is the second time a PDS Catiper has been run in this well and the tubing and liner logged. A ' comparison between the current and previous log (July 28, 2005) indicates an increase in corrosive damage from --650' to 2,400' during the time between logs. A graph illustrating the difference in maximum recorded penetrations on a joint-by joint basis between logs is included in this report. ',' 3.5" TUBING -MAXIMUM RECORDED WALL PENETRATIONS: Line of Pits (57°~) Jt. 55 @ 1,736 Ft. (MD) Line of Pits (53%) Jt. 85 @ 2,679 Ft. {MD) ~I' Line of Pits (53%) Jt. 117 @ 3,707 Ft. (MD) Line of Pits (47%) Jt. 54 @ 1,729 Ft. (MD) ~ Line of Pits (46°k) Jt. 74 @ 2,350 Ft. (MDj ProActive Ciagnostic SerJices, Inc. ,~ P.O. Box 1369, Stafford, 7X 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PCS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 • • 3.5" TUBING -MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 8%) are recorded. 3.5" TUBING -MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded. COMPARISON TO PREVIOUS MTT LOG RES41LTS ' A comparison of the current log data recorded at 5Hz to the previous data recorded at 10Hz (October 6, 2007) indicates a slight decrease in overall metal volume over the interval from 4' to 15' and 23' to 48' as recorded by the MTT. A log plot overlay of the average metal thicknesses recorded by the MTT for the ' current and previous logs (October 6, 2007 and December 13, 2006) is included in this report. The interval of significant metal loss indicated from 13' to 24' in the previous log is indicated very similarly in ' the current log, but the current 5Hz pass data shows a more consistent metal loss response through this interval. The ability of the 5Hz frequency to permeate more meta than the 10Hz frequency is believed to be responsible for a more stage tool response and provides a more fully representative picture of this interval of metal loss. In the 2007 and 20061ogs, calibration samples were only taken within the concentric pipe that included the conductor. As a result, calculated metal thickness below the conductor appears to show metal loss due to the absence of the extra metal from the conductor pipe. The current log includes an additional calibration applied below the conductor, so the calculated metal thickness no longer reflects a loss due to the absence of the conductor. INTERPRETATION OF MTT LOG RESULTS The 5Hz MTT log results cover the interval from surtace to 210'. Changes in metal volume are relative to the calibration points at 55' and 140', where the readings are assumed to represent undamaged pipe. All other readings are relative to these reference points. A maximum overall metal volume loss of 13% is indicated in joint 1 (12' - 26') in the 5Hz pass. A fog plot of the MTT recordings at 5Hz is included in this report. The Delta Metal Thickness (%) curve in this plot refers to total metal surrounding the MTT tool. Other intervals of overall meta! loss are indicated in the 5Hz pass as follows: 4' - 9' 2% to 4% circumferential metal loss 12' - 26' 2% to 13°~ circumferential metal loss, no significant isolated pits indicated 26' - 40' 2°~ to 4% crcumferencial metal loss indicated, though masked by tubing collar at 36'. 68' - 79' 2% to 3% circumferential metal loss 146' -151' 1 °~6 to 4% circumferential metal loss The percent circumferential metal loss expressed in this summary is a percentage of the total metal that the tool is responding to, which includes influences from the 3.S", 5.5" and 16" pipe. If all of the metal loss is specifrc to the 5.5" production casing, the percent metal Ions from that pipe alone is probably higher than the numbers expressed. Some of the metal loss indicated could be ftom either the 3.5" tubing or 16" conductor. Field engineer: G. Etherton Analyst: C. Waldrop (MIT), HY. Yang (MTT) Witness: C. Fitzpatrick ProActive Diagnostic Services, Inc. / P.O, Bax 1369, Stafford, TX 77497 Phone: (281} or (888} 565-9085 Fax: (281) 565-1369 E-mat(: PDS a~•memorylog.cam Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 ' • • PDS Multifinger Caliper 3D Log Plot S ~ ~~ Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 1 D-119 Date : February 25, 2009 ' Description : Detail of Caliper Recordings Across Interval of Buckling from Surface to 1,000' Comments Depth Max ID (1/1000 in.) (Off-Center) Image Map (Centered) Image Map 1ft:750ft 2500 3500 0° 90° 180° 270° 0° 0° 90° 180° 270° 0° Min ID (1/1000 in.) 2500 3500 Nominal ID (111000 in.) 2500 3500 -~ - - - ___ Tree °' _ _:.__ - _ - Pup Jt. _ ...:. Joint 1 50 Buckling _ R'~ _.. Pup Jt. - . Joint 2 ~ - _. 100 - _ ~ ~- Joint 3 _, • ~ ~ Joint a 150 I t---~- - .. _ _ Joint 5 Buckling „~,,y,re. -t-~-- - - - 200 _ Joint 6 ._~._... Joint? i _ _ __. t-. i __ } - _ ,- ~__ - _ Buckling 250 fi-- i _, , _ •- ~i _ ~ - _ Joint 8 - ~ - _ ~~~~ Buckling _ 300 Joint 9 ~. - ~...:> Joint 10 { 5` 350 Joint 11 z, _^ ~._.. Buckling _~ ~ _ . Joint 12 400 - ~ ~ ~- __.._. '"!1 ~ .~ Joint 13 - ~ _ _ - 450 Joint 14 _ ~~ .: f~111~rr.-- - . - .. • • 500 ~ Buckling . Joint 16 _~_-~-_ _ Joint 17 550 Joint 18 Buckling - - ~, ~., Joint 19 - - Buckling 650 Joint 20 _ Yrw J' ` ~ - ,. ~ Joint 21 - - --- -- - , . - Joint 22 Buckling 700 - - - i _. - Joint 23 75 _ - ~,y.. 0 Joint 24 ~ ~ _ __- __ ~ Joint 25 800 , ~ ~ Buckling - y :LL.,... Joint 26 - 850 Joint 27 " Buckling ~ ~ ~ ~ - -- . ` -- ~ --- ~.. Joint 28 900 ~ - x:,~ ~ . Buckling i~I ~j~ ~ ~._, ., Joint 29 -- ~ ~ ~ . _ _ _ _~ . _ 950 Joint 30 ~'~"" ~~ , Joint 31 -- a~~ -. "~^° Buckling __ Nominal ID (1/1000 in.) l............„ ........................................................ 2500 3500~ Min ID (1/1000 in.) 2500 3500 Comments Depth Max ID (1/1000 in.) Off-Center Ima a Map Centered) Ima a Map 1ft:750ft 2500 3500 0' 90° 180° 270° 0° 0° 90° 180° 270' 0° • i ~,_. Welh 1D-119 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Maximum Recorded Penetration Comparison To Previous Survey Date: February 25, 2009 Prev. Date: July 28, 2005 Tool: UW MFC 24 No. 218183 Tubing: 3.5' 9.31b L-80 Overlay 0 M 5 ax. Rec. 0 1 Pen (mils) 00 150 20 0 5 15 25 , : 35 .. i 45 I 55 ~ E 65 g Z 1: 'S 75 85 95 105 115 118.3 ^ February 25, 2009 ^ July 28, 2005 flifFarF+n~a • Correlation of Recorded Damage to Borehole Profile Pipe 1 3.5 in (37.3' - 3870.3') Well: 1 D-119 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: February 25, 2009 . A pprox. Tool Deviation ^ A pprox. Borehol e Profil e 40 324 636 949 1262 1574 1888 ,i c s Y 2202 ~, 2512 2824 3139 3452 GLM 1 120 3839 121 ~ - -__ - - 3870 0 5 0 1 00 Da mage Profile (% wall) / Tool D eviatio n (degr ees) Bottom of Survey = 121 1 ~ 10 20 30 40 50 v 60 ~ Z ~ 70 O (r~ 90 100 d 110 -- - - PDS Report Overview S~ Body Region Analysis Well: 1 D•119 Survey Date: February 25, 2009 Field: Kuparuk Tool Type: UW MFC 24 No. 218183 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Anal st: C. Waldro Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.3 f L$0 2.992 ins 3.756 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body metal loss body 150 - 100 50 0 0 to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% Number of ~oints anal sed total = 127 pene. 0 16 14 69 28 0 loss 18 109 0 0 0 0 Damage Configuration (body ) 100 8U (i0 4() 20 0 isolated general line ring hole /puss pitting corrosion rnrrosion corrosion ible hole Number of ~oints dama ed total = 96 85 11 0 0 0 Damage Profile (°~ wall) ~ penetration body metal loss body 0 50 100 0 49 99 GLM 1 Bottom of Survey = 121 Analysis Overview page 2 • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 Well: 1 D-119 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.382 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: February 25, 2009 Joint No. Jt. Depth (Ft.) I'~~n. I II~,~~I !Im.l Pen. Body (Ins.) Pc~n. °i~, ~~~t.il I cs `%, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 37 O 0. 7 2. P P U .02 ' .90 B cklin . 1.1 71 U 6 I 91 PUP 74 a 0.0 ~) 2.92 3 105 U 2 ~) ~ .91 4 137 U 0.0 7 I 2. 2 5 167 U 0.03 11 1 2.92 B cklin . 6 199 U .01 6 1 .9 7 0 u 0 9 ~ 2.9 cklin . 8 261 O 0 9 I .92 Bu lin . 9 t) 0. ~) 1 2.9 10 324 O 0.02 £3 .93 1 356 tt .02 9 I 2.89 B klin . 12 387 c ~ .02 £3 1 2.9 1 419 u 0 02 7 I 14 450 a 0.03 I1 2.9 15 481 c) 0.04 1 £i ' 2.93 Buckli 1 12 t) 0.05 1') .91 17 54 t) 0. 3 I t I .92 18 573 t) 0. 4 17 .9 klin . 19 604 t) 0 03 l s I 2.93 Buck in . 0 636 t) 0.03 1tJ n 2.92 21 667 t1 0. 4 15 I 1 22 698 t) 0.05 I ~) _' 2.93 Bucklin . 3 7 0 t) .06 ' ~ I .9 late itf 24 761 t) 0.08 >1 I 2.9 Isolated ittin . 5 7 t) 0.05 Zt1 ~ .93 Bucklin . 26 824 O 0.06 13 Z 2.92 Isolated ittin . 27 856 l) 0.06 24 2.9 Buc lin .Isolated ittin . 28 887 O 0.09 ;5 _' 2.9 Buc lin Is late ~ttin . 29 919 O 0.05 1 £t ~ 1 30 949 t) 0.05 ~l) _' 2.94 Isolated itti 1 981 l) 0.07 2(~ I B cklin Isol ted it ~n . 32 1013 t) 0.06 24 ~' .91 Isolated itti 33 1044 l1 0.05 ~' I Z 2.91 Isolat i ti 34 1075 U 0.09 ~4 ~ 2.93 Bucklin .Isolated 'ttin . 35 1107 t) 0.06 ~'~ 9 Isolated ittin . 36 1138 t~ 0.08 31 I 2.9 Bucklin .Isolated 'ttin . 37 1168 t ~ 0.07 Z 7 ? 2. 1 I lated i ti 38 1199 U 0.08 Su 3 2.92 Bucklin .Isolated ittin . 39 12' 1 t? 0.08 s1 .93 Line of i s. 40 1262 t) 0.09 35 ~ 2.91 Line of its. 41 293 U 0.09 35 .92 Isolated ittin . 42 1323 t) 0.11 4:3 _' 2.93 Bucklin .Isolated ittin . 4 13 4 U 0.07 2£i .93 Bucklin I olated i 'n . 44 1385 O .11 4 ; 2.91 Isolated ittin Lt De sits. 45 417 n 0.09 >;" 2. 4 Isol to ittin . 46 1448 a 0.07 !') -1 2.91 Isolated ittin . 47 1480 t) 0.07 _'' ~ 2.93 Buckli .Isolated ittin 48 1511 U 0.08 91 _' 2.92 Bucklin .Isolated ittin . _ Penetration Body Metal Loss Body Page 1 • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 Well: 1 D-119 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.382 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: February 25, 2009 Joint No. Jt. Depth (Ft.) I'c•n. l)(xe~1 Ilrn.) Pen. Body (Ins.) I'~~n. ih ~1~•i,~l I ~ ~~5 ~~ Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 49 154 U 0 07 ?ti ~' 2.92 Iso a ed ittin . 50 1574 U 0.10 s~) _' 2.92 Buckli .Line of its. 51 1 0 u 0.11 4_i ', .93 ucklin L'ne of its. 52 1637 a 0.10 41 2.91 Line of its. Lt. De sits. 3 668 U .10 ~') .91 B cklin .Lin of ~ts. 54 1700 U 0.1 47 s 2.93 Line of i 55 1731 t) 0.14 57 _' 2.92 Bucklin .Line of its. 56 176 U.Ut; 0.10 ~~) 5 2. 6 Line of i Lt De sits. 57 1794 0 0.11 ~5 ' 2.9 cklin .Line of its. 8 18 U 0.11 X15 ~ 2.91 &i klin .Line of i 59 857 U 0 09 ~7 s 2.93 ucklin Line of i 60 888 +) 0.11 -14 ~ 2. 1 Line of its. 61 1 0 +).ur, 0.12 ~1(> s .91 Buc lin ine of i 2 1951 !) 0.11 ~< 2.91 Li f i 63 1982 t? 0.09 s; 2.92 a of its. 64 2013 !) 0.09 3-1 -1 2. 1 B klin ine of its. 5 045 U 0.11 4 ~' 2.91 L~ne of its. 66 076 t) 0.10 39 ~ .92 B cklin Line o its. 67 2108 (i 0. 6 24 _' 2.93 u klin .Lin of i 6 2139 +! 0. 9 34 2.92 kli .Line of its. 69 171 ±) 0.0 34 2.93 i e of i 7 2202 ~! 0.09 i6 2.89 Li of its. Lt. De its 71 2232 t! 0.10 3~) 2.93 Line of i 72 2263 t! 0.10 41 3 2.91 Bucklin .Line of 'ts. 73 4 ~) 0 09 i 5 f 74 2326 U 0.12 46 3 2.91 Line of its. 75 2357 U 0.09 37 4 2.9 Bucklin ine of i 76 2387 i) 0.09 35 i 2.89 Bucklin ,Line of its. 77 2418 +).+)- 0.12 4 i .9 Bucklin ine of its. 78 2449 +) 0.11 ~1 ~' 2.91 Line of its. 79 248 i) 0.11 43 ~ 2.93 Li of i 80 2512 i! 0.10 41 ~' 2.92 Line of its. Lt. De sits. 81 543 a 0.09 35 :.' .92 Buckli .Line of 'ts. 82 2574 U 0.08 ,1 ! 2.91 B cklin .Line of its. 83 605 i) 0.11 45 -l 2.91 Line of its. 84 2637 i1 0.07 19 ; 2.89 Bucklin .Line of its. Lt. De osits. 85 668 U 0.1 i3 ~ 2.93 Bucklin .Line of its. 86 2700 i! 0.07 1~ ~ 2.94 Bucklin .Line of its. 87 2731 ±! 0.09 36 j 2.93 Li a of its. 88 2762 i! 0.09 4 ..' 2.91 Line of its. 89 793 U 0.08 31 s 2.9 Bucklin .Line of its. 90 2824 O.(16 0.10 41 ~ 2.91 Line of its. 91 2856 O 0.10 39 2.9 Lin of its. 92 2887 !) 0.09 36 2.92 Buc lin .Line of its. 9 918 !! 0.10 3~) ~ .92 Lin of its. Lt. De si . 94 2950 t) 0.09 35 2.93 Bucklin .Line of its. 95 2981 !) .09 35 .91 Line of its. Lt. Ue sits. 96 3013 !) 0.11 43 -t 2.93 Line of its. 97 3044 0.08 s' 4 2.93 Buckli .Line of its. 98 3076 0.10 ~~) ~' 2.92 Line of its. l.t. De osits. _ Penetration Body Metal Loss Body Page 2 • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 Well: 1 D-119 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.382 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: February 25, 2009 Joint No. Jt. Depth (Ft.) I'c~n. ~ )h•c~i Iln~.) Pen. Body (Ins.) Pc~n. "4, ~1~~t.~l I cis. `;> Min. LD• (Ins.) Comments Damage Profile (°~6 wall) 0 SO 100 99 3107 0 0.07 3u _' 2.94 i of its. 10 3139 0 0. 1 41 5 2 cklin Li e of its. 101 3170 0 .09 ~(~ ~ .9 ~ne f its. 10 32 2 ~~ 0.0 ~ ; ..' 2.91 L'ne of its. Lt. De its. 103 3 33 ~) 0.08 ~1 .92 Line of its. 1 4 3265 tt 0.0 ,-i 2.9 Bucklin .Line of its 105 3295 U 0.07 ;i~ 2.91 Bucklin .Line of its. 106 332 0 0. 0 -lU .93 Line of ils. 107 3357 U 0.0 36 ine of its. 108 3389 i 1 0 08 i ? 2.93 Bucklin .Line of its. 109 34 0 ~> 0. 9 35 -1 .93 B cklin in o its. 110 3452 c ~ 0.08 a 1 .91 Line of i 11 3483 i ~ 0.08 1 .91 B cklin .Line f its 1 3515 ~ ~ .0 <' .91 Line of its. L . De si 1 54 ~) 0.0 i:; 2.91 u klin Li e of its. 14 3576 a 0.08 ;0 s 2.92 Line of its. 115 3607 U 0.07 Z8 _' 2.92 Line its. 11 3639 l~ .08 30 _' 2.93 Buc in .Line of i 116.1 3670 ~ ~ 0.04 15 _' .91 P P 116.2 3685 0 0 0 i~ N A M 1 Latch ®3:00 116. 3691 ~~ 0.06 24 £i 2.92 PUP 'n f i . 117 370 a 0.13 53 ~ 2.90 Li o i . 117 1 373 ~~ 0 U t! 2.81 mco'W-1' Selective Ni le 118 3738 ~ ~ 0.11 41 2.93 Line of its. 1 3 7 u 1 ~ u 94 PUP 118.2 3776 ~) 0 0 ~) 3.00 Baker GBH-22 Locaror Seal Assembl 118.3 3788 U 0 0 U N A 'n r Ha r 118.4 3798 l1 0.05 I ~) 2 2.92 PUP To of 3.5" Liner 1 19 3808 0.06 0.11 44 2.94 ine o i 1 0 3839 0.12 0.16 63 > 2.92 Perforations. Lt De sits. 1 1 3870 0 0.1 62 2.92 Perfor lions. Lt. De sits. ® Penetration Body Metal Loss Body Page 3 ~~ ~~ PDS Report Cross Sections Well: 1D-119 Survey Date: February 25, 2009 Field: Kuparuk Toot Type: UW MFC 24 No. 218183 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 ins 9.3 ppf L-80 Analyst: C. Waldrop Cross Section for Joint 55 at depth 1735.71 ft Tool speed = 43 Nominal ID = 2.492 Nominal OD = 3.500 Remaining wall area = 98 Tool deviation = 9 ° finger 1 Penetration = 0.144 ins Line of pits 0.14 ins = 57% Wall Penetration HICH SIDE = UP ~~ • Cross Sections page 1 ~~ ~c~ PDS Report Cross Sections Welt: 1D-119 Survey Date: February 25, 2009 Field: Kuparuk Tool Type; UW MFC 24 No. 218183 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 ins 9.3 ppf L-80 Analyst: C. Waldrop Cross Section for Joint 85 at depth 2679.07 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 97 Tool deviation = 27 ° Finger 10 Penetration = 0.134 ins Line of pits 0.13 ins = 53% Wall Penetration HIGH SIDE = UP i Cross Sections page 2 Comparison to Previous (I~T Logs Overlay P~~ ~~~ sE.~s, ~~. February 25, 2009, October 6, 2007 and December 13, 2006 Database File: d:lwarriorldatal1d-1191comp.db Dataset Pathname: 1/1/complmerge1 Presentation Format: 24COMP~1 Dataset Creation: Fri Feb 2719:25:13 2009 Charted by: Depth in Feet scaled 1:150 -40 Delta Metal Thickness 2007 (10 Hz) (%) 40 -40 Delta Metal Thickness 2006 (10 Hz) (%) 40 -40 Delta Metal Thickness 2009 (5Hz) (%) 40 0 Metal Thickness 20 40 60 of 16" sa 1 D-~9 Recorded Magnetic Thick~s Log Data - 5Hz Pass P ~~~ SE.~~~, ~~. (Surface to 210') February 25, 2009 Database File: 1d119.db Dataset Pathname: 5Hz.1 Presentation Format: 1.4 scale Dataset Creation: Thu Feb 26 22:15:11 2009 by Calc Warrior 7.0 STD Cas Charted by: Depth in Feet scaled 1:150 -50 Delta Metal Thickness (%) 50 1.4 MTT Phase Shift -Sensor 01 (5 Hz) {rad) 11. 0 LSPD (ft/min) 200 -7.4 MTT Phase Shift -Sensor 12 (5Hz) (rad) 2. -- -- - --- __ - ~ ~ -_ - - - ___- - -- ___ ~ , - Tree __._ - = ~_ - ~., ~ - ~Ilar ---~-- .,... , ~---- - _ Hanger `~ "- ~ - ' I ! ~ ? ~' Collar ~ - - - - _ 4 6 4% Metal Loss Metal Thickness Jt. 1 2a Metal Loss 5„ 4% Metal Loss ~ 5.5" Collar Jt. 2 60 Metal Loss-~ Bottom of 16" Cor Jt. 3 5.5' Collar • ~~ 100 3.5" Collar Jt. 4 1?0 5.5" Colla 5" Colla 140 Jt. 5 t_-1- ~ Jt. 6 Metal Thickness -~---~--~ 180 3.5" Jt. 7 ~~ Delta Metal Thickness (%) 50 1.4 MTT Phase Shift -Sensor 01 (5 Hz) {rad) 11.4 LSPD (ft/min) ~00 -7.4 MTT Phase Shift -Sensor 12 (5Hz) (rad) ~.6 KRU 1 D-119 ConocoPhillips Alaska, Inc. 1 -118 API: 500292283600 Well T INJ An le TS: d TUBING SSSV Type: NONE Orig 12/16/1997 Angle @ TD: 18 deg @4515 (03777, oo:s.soo, Com letion: io:z.a3a> Annular Fluid: dsl/39'o KCI Last W/O: Rev Reason: TAG FILL Reference Lo Ref Log Date: Last Update: 7/8/2006 'R~~cN Last Ta : 4132 TD: 4515 ftK6 are. o; Last Tag 7/4/2006 Max Hole 31 deg @ 2529 "~755D) Date: An le: C 'n Stri - TR S Descr' don Size To Bottom TVD Wt Grade Thread NAP CONDUCTOR 16.000 0 121 121 62.58 H-40 Welded (37363737, OD:3.500) PRODUCTION 5.500 0 3777 3565 15.50 L-80 MBTC LINER 3.500 3777 4500 4247 9.30 L-80 EUE Tu ' 8trin -TUBING sEa~ Si e o Bottom TVD Wt re e Thread (37763T7a, a ooo oo 3.500 0 3777 3565 9.30 L-80 ABM-EUE . : ) Perforations Su mmer Interval TVD Zone Staves Ft PF Date T Com en 3856 - 3892 3639 - 3673 WS D 36 4 5/1/1998 IPERF 2.5" HC, DP, 180 deg hasin 90 de orient Pert t3e5s-3asz) 3922 - 3960 3701 - 3737 WS B 38 4 5/1/1998 IPERF 2.5" HC, DP, 180 deg hasin 90 de orient LINER 3970 - 3980 3746 - 3755 WS A4 10 4 5/1/1998 IPERF 2.5" HC, DP, 180 deg (37n-a5oo, hasin 90 de orient ~iats~aoj 3980 - 4000 3755 - 3774 WS A4 20 4 /30/199 IPERF 2.5" HC, DP, 180 deg hasin 90 de orient Pert 4008 - 4022 3782 - 3795 WS A3 14 4 /30/199 IPERF 2.5" HC, DP, 180 deg (39223960) hasin 90 de orient 4032 - 4048 3804 - 3819 WS A3 16 4 /30/199 IPERF 2.5" HC, DP, 180 deg hasin 90 d orient 4048 - 4068 3819 - 3838 WS A3 20 4 4/8/1998 IPERF 2.5" HC, DP, 180 deg PeA (397o-3sao> hasin 90 de orient Pert 4087 - 4097 3856 - 3866 WS A2 10 4 4/8/1998 IPERF 2.5" HC, DP, 180 deg (3400°) hasin 90 de orient 4107 - 4145 3875 - 3911 WS A2 38 4 4/8/1998 IPERF 2.5" HC, DP, 180 deg hasin 90 de orient 4170 - 4180 3934 - 3944 WS A2 10 4 4/7/1998 IPERF 2.5" HC, DP, 180 deg Pert hasin , 90 d orient (~~~) Gas LiR M ardrala NeN St MD TVD Men Man Type V Mfr V Type V OD Letch Port TRO Date Vlv Mfr Run Cmnt 1 3684 3478 BST ATX DMY 1.0 T-1 0.000 0 2/16/199 Other u s a- J R De th TVD T Descri don ID ~" 3736 3526 NIP Camco 'W-1' Selective Ni le 2.813 (ao3z-aoas) 3776 3564 SEAL Baker GBH-22 Locator Seal Ass 3.000 Pert 4500 4247 Shoe Gemoco 0.000 (aoae-aosa) Pert (aoe7-aos7) Part (4107-4145) Pert (4170180) ARCO Alaska, Inc, CASII'3G i TUBING !LINER DETAIL 3-9/Z° Tubirt4 tMor~o6or+e) WELL: 9 b-7'19 West Sak, Kuparuk DAT>w: 12116197 1 Of 4 PAGES .~uaro".~.ar~ .n ~ ~ ITEMS ,w.• ..................~.....,.....~ COMPLi~i':. DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH TOPS RKB to Tubin Nan er Lockdowns -Parker R' #245 38.76 Vetaa Gra 3-1/2"Tubin Han er $ u 3.07 38.76 1 Jt 3 -112", 9.3#, L-80, A3M-EUE Tubi S aae but Pu 3-112" Tubin 31.55 2.28 41.83 73.38 115 Jts 3-112", 9.3# l-80, A611~-EUE Tubin Pu Joint 3-1/2°Tubin 3584.62 14.52 75.65 3670.28 G/JY0 #~ 1 Jt 1 Jt BST 3-112" x 1" ATX, UV, T-1 latch 4.700" OD 2.8!6T' drift 6.88 Pu Joint, 3-1 J2' Tubin 14.t}8 3-112". 9.3#. L-80, ABAfl-EUE Tubin 30.37 CAMCO 3-1/2" 1N-1 Piip 2.812" ID Selective Profile 1.96 3-1/2", 9.3#, L-80, ABhA-EUE Tubin 31.50 Pu Joint, 3-112" Tubir~ 6.13 Baker GBH 22 locator Seal Assembl Lflcator = > .84 12.72' Overall 11.8+`i' Seal As , 4" OD seals Bottom of locator =_» 3.684.80 3691.68 3705.76 3736.13 3738.03 3769.58 3775.72 3776.56 Note: Seals are stabbed into 4" tD Seai Bore Extension at XO ir- 5-1 " x 3-112" Casi -see Casin Detail S aced out with Locator --1' u~ frflm landed 'tian_ _ ._„_ r~r__~.... enx~-rr ~ 1., 1fKfK~t r1n ~R-e~ glodcs. Ran 1 18 joints of tubing. ~~~~s,,..z~W,.~a..,....,. --- - NQ Lead thread compound On al€ connsctions (National = BOl ZOt10) Tubi is non - Parker Rig #245 Dril{in Su ervisar. Don F Breeden ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907j 659-5102 RE : Cased Hole/C+pen Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ M7T) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska], Inc. Petrotechnical Data Center Attn: Andy Farmer LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 and v~ c ~q~-aaa ProActive Diagnostic Services, lnc. U3 C (~ `~j - (3~J Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax. (907 245.8951 1 j MTT 06-0ct-07 1 D~119 1 Report 50029-22836.00 2j Ml"1• 07~Oct-07 1 D~128 1 Report ;50~29~~',000 .''~~~ Signed : - Date : J Print Name: ~(.~.L~.s~_IY~-~` t ~ •p•~ _ . PROACTIVE DIAGNOSTIC SEFtYICES, MC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 9951$ PHONE: (907)245-8951 FAX: (907)2458952 E-MAID: Ia~isae*~~*~6~~~~cs~~s~,~~~r~s,~~r: WEBSrrE::+rP,nv.~-se~~~af:^~€~.~~rsa D:uVtaster_CopY OQ_PDSANG2Q~aclZ_P(ocdlDishiMdionllYansauttal_SheetsCRa[~smit_Odginat_New.doc ~I 1 I. Memory Magnetic Thickness Tool Log ResuMts Summary Company: ConocoPhillips Alaska, Inc. Well: 1D-119 Log Date: October 6, 2047 Field: Kuparuk Log No.: 8638 State: Alaska Run No.: 2 API No.: 50-029-22836-00 Pipet Desc.: 3.5" 9.3 tb L-80 EUE 8RD Top Log Intvl.: Surface Pipet Use: Tubing Bot. Lag Intvl.: 192 Ft. (MD) Pipet Desc.: 5.5" 15.5 Ib L-80 BTCM Top Log Intvl.: Surface Pipet Use: Production Casing Bot. Log Intvl.: 192 Ft. (MD) Pipe3 Desc.: 16" 62.58 Ib. H-40 Welded Top Lag Intvl.: Surface Pipe3 Use: Conductor Pipe Bot. Log Intvl.: 121 Ft. {MD) Inspection Type : Assess Changes in Corrosive Damage (Meta! Loss) to Production Casing. ' COMMENTS: This MTT data is ded into the Mandrel Hanger ~ 0' Depth. This is the second log of this well with the 12 Arm Magnetic Thickness Tool (MTT). The Magnetic Thickness Tool responds to the total thickness of metal of the 3.5" tubing and 5.5" production casing, with some influence from the 16" conductor pipe. Due to the ~ncentric pipe strings in the log interval, the MTT response is qualitative -indicating an overall increase or decrease in metal surrounding the tool, but not distinguishing in which pipe string the change in metal thickness occurs. In this log, the MTT was calibrated down hole {57'), where the readings are assumed to represent undamaged #ubing and casing. All other readings are relative to this reference point, which include influences from the 3.5' tubing, 5.5" casing, and 16" conductor pipe. COMPARISON TO PREVIOUS MTT LOG RESULTS A comparison between the current log and the previous {December 13, 2006) indicates a slight increase in metal loss over the interval from 15' to 25' as recorded by the MTT. A log plot overlay of the average metal thicknesses recorded by the MTT for the current and previous log is included in this report The indication of less metal below the conductor in this log compared to the previous appears to be a calibration feature rather than metal loss. INTERPRETATION OF MTT LOG RESULTS The MTT fag results cover the interval from surtace to 192'. A log plat of the entire pass, plus a detailed section of any interval showing damage is included in this report. The Delta Metal Thickness {%) curve in these plots refers to total metal surrounding the MTT tool. A maximum of 14% circumferential metal loss is recorded in the interval between 13' - 24'. A 10°~ isolated metal loss is recorded at 8'. A 4% isolated metal loss is recorded at 4'. The percent circumferential metal loss expressed in this summary is a percentage of the total metal tha# the tool is responding to, which includes influences from the 3.5", 5.5" and 16" pipe. If all of the metal loss is specific to the 5.5" production casing, the percent metal lass from that pipe alone is probably higher than the ' numb rs x ressed. o e of the metal foss indicated could be from either the 3.5" tubin or 16" conductor. e e p S m g ' Field Engineer: K. A9iller Analyst: ilA. Lawrence & J. Burton Witness: C. Kennedy ProActive Diagnostic Services, U.c. / P.O. Box 1369, Stafford, TX 77497 Phone: (28i) or (888) 565-9085 Fax: (281} 565-1369 E-mail: PDSCamemoryiog.com Prudhoe Bay Field Office Phone: (907} 659-2307 Fax: (907) 659-2314 1 ~ uTc ~~~-aaa Comparison to Previous~TT Log Overlay October 6, 2007 and December 13, 2006 ~~ ~~~~ SE~q w~. Database File: comp.db Dataset Pathname: ruNcomp Presentation Format: 24COMP-1 Dataset Creation: Fri Oct 1910:57:4 2007 Charted by: Depth in Feet scaled 1:150 -50 Delta Metal Thickness 2007 50 -50 Delta Metal Thickness 2006 50 -10 Delta Metal Thickness 0 thickness 2007 10 20 30 40 50 60 70 80 JO 100 110 120 130 140 150 160 170 180 190 -50 Delta Metal Thickness 2007 50 -50 Delta Metal Thickness 2006 50 n ~~ C ~~ ~~~ ~~~ ~~ Magnetic Thickness T~(10 HZ Pass} October 6, 2007 Database File: d:lwarriorldatal1d-11911d-119.db Dataset Pathname: run!_mpkl_ Presentation Format: 24SCAL--1 Dataset Creation: Fri Oct 19 09:40:06 2007 Charted by: Depth in Feet scaled 1:50 -50 Delta Metal Thickness 50 2.4 MTTP01 1~.4 0 Line Speed -200 -6.4 MTTP12 3.6 re I e (Not Pictured) I Han ger (Not Pictu red 3.5" Gollar Pup Jt. (Not Pictu red 5 5 " C ll . o ar Metal Loss R 10% Metal Los s 10 3.5" ~' ` ,_ Jt. 1 ~' ~ 1 4% Me tal L oss ~~ ~> s ConocoPhillips Alaska, Inc. KRU 7D-179 1 D-118 API: 500292283600 Well T INJ An le TS: d T"B~"~ SSSV Type: NONE Orig 12/16/1997 Angle @ TD: 18 deg @4515 (0-3777, OD:3.500, Com letion: 1D2 4~) Annular Fluid: dsl/3% KCI Last W/O: Rev Reason: TAG FILL Reference Lo Ref Log Date: Last Update: 7!8/2006 ' ROD ~ m" ~ Last Ta : 4132 TD: 4515 ftK6 ta 0°:5.500, I' i Last Tag 7/4/2006 Max Hole 31 deg @ 2529 ''1550) ~ Date: An le: ~ C 'n - AL T 1 G - Descri lion Size To Bottom TVD Wt Grade Thread "~P CONDUCTOR 16.000 0 121 121 62.58 H-40 Welded (30D:3.500) PRODUCTION 5.500 0 3777 3565 15.50 L-80 MBTC LINER 3.500 3777 4500 4247 9.30 L-80 EUE Tu ' Strin -TUBING sEa~ Size To Bottom TVD Wt Grade Thread (377s377e, OD:4 000) 3.500 0 3777 3565 9.30 L-80 ABM-EUE . Perorations S umma Interval TVD Zone Ft PF Date T C 3856 - 3892 3639 - 3673 WS D 36 4 5/1/1998 IPERF 2.5" HC, DP, 180 deg hasin 90 de orient PeR (3s56.3ssz> 3922 -3960 3701 - 3737 WS B 38 4 5/1/1998 IPERF 2.5" HC, DP, 180 deg hasin 90 d orient LINER 3970 - 3980 3746 - 3755 WS A4 10 4 5/1/1998 IPERF 2.5" HC, DP, 180 deg 13777-4soo. hasin , 90 d orient wte5 of 3980 - 4000 3755 - 3774 WS A4 20 4 /30/199 IPERF 2.5" HC, DP, 180 deg hasin 90 d orient Pert 4008 - 4022 3782 - 3795 WS A3 14 4 /30/199 IPERF 2.5" HC, DP, 180 deg (39zz-3sso) hasin 90 d orient 4032 - 4048 3804 - 3819 WS A3 16 4 /30/199 IPERF 2.5" HC, DP, 180 deg hasin 90 de orient 4048 - 4068 3819 - 3838 WS A3 20 4 4/8/1998 IPERF 2.5" HC, DP, 180 deg Port (39703980) hasin 90 de orient Pert 4087 - 4097 3856 - 3866 WS A2 10 4 4/8/1998 IPERF 2.5" HC, DP, 180 deg (3980-4000) hasin 90 de orient 4107 - 4145 3875 - 3911 WS A2 38 4 4/8/1998 IPERF 2.5" HC, DP, 180 deg hasin 90 d orient 4170 - 4180 3934 - 3944 WS A2 10 4 4/7/1998 IPERF 2.5" HC, DP, 180 deg Pert hasin , 90 de orient tin) Gas L' M ardr elves St MD TVD Man Man Type V Mfr V Type V OD Latch Port TRO Date Vlv Mfr Run Cmnt 1 3684 3478 BST ATX DMY 1.0 T-1 0.000 0 2/16/199 r u tc. - J Y De th TVD T escri lion ID Pert 3736 3526 NIP Camco 'W-1' Selective Ni le 2.813 (ao3z4o4a) 3776 3564 SEAL Baker GBH-22 Locator Seal Ass 3.000 Pen 4500 4247 Shoe Gemoco 0.000 (ao4&eosa) Pert (40874097) Pert (41074145) Pert (4170-4180) . . ~ ConocoPhillips Alaska RECEIVED JUL 1 0 Z007 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Alaska Oil & Gas Cons. Commission Anchorage July 6, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 '}- ¡jtANNED JUt 1 J 2007 \ o{\ ~ ¥ Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells :trom the Kuparuk field (KRU). Some of these wells were found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of approx. 1.0 foot. The remaining volume of annular void subsequently was filled with a corrosion inhibiter engineered to prevent water :trom 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. . Please M.J. Loveland at 907-659-7043, if you have any questions. ConocoPhillips Well Integrity Project Supervisor . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTO# cement pumped cement date inhibitor sealant date ft bbls ft gal 1 0-09 198-065 23" na 5 6/912007 10-101 200-183 2" na 3.2 6/912007 10-102 200-075 2" na 3.2 6/9/2007 10-103 202-096 5" na 8 6/912007 1O-105a 201-202 25" na 38 6/9/2007 10-106 197-240 2" na 3.2 6/9/2007 10-107 200-177 2" na 3.2 6/9/2007 10-108 198-187 8" na 12.8 6/9/2007 10-113 198-178 2" na 1 6/9/2007 10-114 198-159 2" na 1 6/9/2007 10-115 197-232 2" na 1 6/912007 10-116 198-172 2" na 1 6/912007 10-117 197-237 2" na 1 6/912007 10-118 197-229 2" na 1 6/912007 10-119 197-222 2" na 1 61912007 10-122 198-149 2" na 1 6/912007 10-123 198-170 2" na 1 6/9/2007 1O-125a 200-044 2" na 1 619/2007 10-126 198-108 2" na 1 6/9/2007 10-127 198-109 8" na 2.5 6/912007 10-128 198-133 2" na 1 6/9/2007 10-129 197-213 2" na 1 6/9/2007 10-130 197-183 23" na 5 6/9/2007 Kuparuk Field June 9,2007 . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Howard Okland 333 West 7th Avenue Suite 1 00 Anchorage, Alaska 99501 (907) 659-5102 RE: Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowfedge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C S/'; ~.~~~~arc::n c' ~~ ,,> ~(;;/.,,, Anchorage, AK 99518 Fax: (907) 245-8952 (, é ,.. 2· r'Df< 'tf: 1 ¿j .. Jl 0 10-119 MTT Log MTT Log 12-0ec-06 U..:cC e03 - 08'7 13-0ec-06 UJ: c.. /0 .?- d Ð d 1) 2) 3) 4) 5) 6) 7) 1 Report 1 Report 1C - 174 Print Name: ^ J t ¡ ." I·· I: ¡ ! ,. {;- {/ ~. l /JI '. JJ C /¡.1 /I-~T ¡ iil t? /J1/.J t I p1. kfZ (1 Oa~~ ~I';'ì---j -5-< ,:1. ; 11':''-·. :~, S:,)'-~ ''3n,:::~ , ,., "'."-·~,-~·~;"f"',,, ,.',. ,-, - - Signed: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: :O:;::$..'.;iC'·i,;èPJ32,C2!!.¿;!,¿,-,'tl'_::C,3.::C)¡'!! WEBSITE: }Fh~N.S¡¿;;;V]ç¡;"\·'-:;>?¡:;C;J1 D,\OO _ PDSANC- 2006\Z _ W ordlDistributionlTI1iI1SmittaJ _ Sheetsl TI1iI1Smit_ OriginaJ.doc I I I I I I I I I I I I I I I I I I I . . Memory Magnetic Thickness Tool log Results Summary Company: ConocoPhi/lips Alaska, Inc. Well: 10-119 Log Date: Oecember 13, 2006 Field: Kuparuk Log No. : 7631 State: Alaska Run No.: 1 API No.: 50-029-22836-00 Pipe1 Desc.: 3.5" 9.3 Ib L-80 EUE 8RD Top Log Intv/.: Surface Pipe1 Use: Tubing Bot. Log Intvl.: 190 Ft (MD) Pipe2 Desc.: 5.5" 15.5 Ib L-80 BTCM Top Log Intv/.: Surface Pipe2 Use: Production Casing Bot. Log Intvl.: 190 Ft. (MO) Pipe3 Desc.: 16" 62.58 lb. H-40 Welded Top Log Intvl.: Surface Pipe3 Use: Conductor Pipe Bot. Log Intv!.: 121 Ft. (MD) Inspection Type: Assess External Co"osive Damage (Metal Loss) to Production Casing. COMMENTS: This MTT data is tied into the Mandrel Hanger @ 0' Depth. This is the first log of this well with the 12 Arm Magnetic Thickness Tool (MTT). The Magnetic Thickness Tool responds to the total thickness of metal of the 3.5" tubing and 5.5" production casing, with some influence from the 16" conductor pipe. Due to the concentric pipe strings in the log interval, the MTT response is qualitative - indicating an overall increase or decrease in metal surrounding the tool, but not distinguishing in which pipe string the change in metal thickness occurs. In this log, the MTT was calibrated down hole (70'), where the readings are assumed to represent undamaged tubing and casing. All other readings are relative to this reference point, which include influences from the 3.5" tubing, 5.5" casing, and 16" conductor pipe. INTERPRETATION OF MTT LOG RESULTS: The MTT log results cover the interval from surface to 190'. A log plot of the entire pass, plus a detailed section of any interval showing damage is included in this report. The Delta Metal Thickness (%) curve in these plots refers to total metal surrounding the MTT tool. A maximum of 11% circumferential metal loss is recorded in the interval between 13' - 24'. A 2% isolated metal loss is recorded at 4'. The percent circumferential metal loss expressed in this summary is a percentage of the total metal that the tool is responding to, which includes influences from the 3.5",5.5" and 16" pipe. If all of the metal loss is specific to the 5.5" production casing, the percent metal loss from that pipe alone is probably higher than the numbers expressed. Some of the metal loss indicated could be from either the 3.5" tubing or 16" conductor. RECEIVED DEC 1 9 2006 I Field Engineer: J. Halvorsen Ala~ka Oil & Gas Cons. Commission Witness: AnaI:JM.Bf8ick I Analyst: M. Tahtouh & J. Burton ProActive D!agr1ostjc Services, !-"l.~}. 1369, Stafford, 7749: Phone: (281) or (888) 565-9085 Fax; 565-1.369 E-mail: PDS@memorylog.com 0rudhoe Bav Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 UT~ tc)'7- -9C):J I I I I I I cl2s Magnetic Thickness T (10HZ Pass) PROAcrIvE ÐiAq""""lc SER";CES; INC. Database File: d\warrior\data\1d-119\1 d-119.db Dataset Pathname: 10hz. 1 Presentation Format: 2.4 scale Dataset Creation: Thu Dee 1409:13:062006 by Calc Sondex Warrior V7.0 Charted by: Depth in Feet scaled 1150 . .---. - -50 Delta Metal Thickness (%) 50 2.4 MTTP01 (rad) 12.4 0 Line Speed (ft/min) -200 -6.4 MTTP12 (rad) 3.6 =rtEì -20 II J ¡ t± -10 ~... .- Tree Hanger - -55" Collar I I Pup Jt Metal 1055- ... Ie-- I 1 ~ i 10 4 Yr- 3.5" ~ .....' ./i" ...J i I{ =#= Jt 1 $ = , 1 '1 11% Metal Loss- 20 ~ I~. 1"'- ........ I·~ t.. *", ... I '.... ",. ....... - ....- . . I) J ----- ~ "- ¡ - f--- - .5" Collar 30 - 1+ Pup Jt. - ::::= I t I .5" Collar· - --- I 40 - I ;¡o ........3! ....5.5" Collar .- ~ I ¡ç;- ~->-- .......... . -- E--- - ,-- -- 50 I 3.5" fl Jt 2 60 - If ¡~ - - ~ .....~ - - 3.5" Collar- - 70 - - 3.5" .... '-- Jt. 3 ~ .-----.. .-. - - - , ~ I " i I "'1 ¡L. - Bottom of 16" Conductor ---I " --- .,/> (+./ k-- If' , , , , on (' 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 11 ov t It ~ ,>!~> ~ I ~ 1--- I I 1_ "c" :> b ~~ - ::> ;> I> ...-5.5" Collar ::;::::; ,......~ ::::;;p ~,. r- f:> _Cc' .--:::=> ~ - ~ .; ¡ ~ ¡¡¡ 1 - 90 - t - f: 0_- ¡....... - -~ ~ ,~ :;¡i!!!JJ/i! 100 r-- ~ 3.5" CollaL - I : ~ I 110 ff 3.5" - --.- o- r-- Jt 4 --- -- c--- <: ¡--- 120 ? t2 <:..c. 7 m '" Collar <: f" ----' .--- 0.·0'."·· r ,! >- 130 ~ l ~- 35" Collar ~,. ---., - ::& .':S :::>- ;:: -- .- ..- f--i . = 140 3.5" =i Jt. 5 j }- I 1 -- -.---0 -.-.. FAt 150 I -- ............. <.- r-- ~ : .. .5" ,«ollar ....£:. "" mS"COllar c--- , ~" lBt'! 'f , '-- ;:. ........ - :> ~:=:> Þ.,.. ¡e c--- \ F f---.. ~ I 170 \ : ~ ) I I l I tr --à- ,-_J_ ::JI' 3.5" , r Jt. 6 -., I ~ '" .~ I I 180 l \ ~ I ¡....- '" ~ I -50 Delta Metal Thickness (%) 50 2.4 MTTP01 (rad) 12.4 0 Line Speed (ftlmìn) -200 -6.4 MTTP12 (rad) 3.6 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 "") JS Magnetic Thickness T (10HZ Pass) "'" p~ DIAqN05rIc SERvicES, INC. Database File: d\warrior\data\1d-119 top metalloss\1d-119.db Dataset Pathname: 10hz.1 Presentation Format: 2.4 scale Dataset Creation: Thu Dee 1409:13:062006 by Calc Sondex Warrior V7.0 Charted by: Depth in Feet scaled 150 -50 Delta Metal Thickness ('Yo) 50 2.4 MTIP01 (rad) 12.4 0 Line Speed (ft/min) -200 -6.4 MTIP12 (rad) 3.6 ,..--- Tree ! Hanger u Pup Jt. ....~ t - ..---- ~ -- -. ..... 3.5" Collar- ~ ) f5 5.5" Collar ~1 I I I > :- 3Þ:~ 2% Metal loss .! <: ( ( ,'E i~~ "'¿ i¿ .~ ! - 'iTe--· - .¿ " " 5> --+-- ~ , I~::; < '/ -.. - ~------ .- ___n__ ---- --- '" { '~> ( jl I { í ! { 10 > I) ) I ~ ¡ ~ ~ ~ ! ~ f < ~ iJ - - f-- \ "> \ ) !/ r ) ì ! } ) ) l/ /' ~ / / í i J I 3.5" !1 7 l 7 I! I l / Jt. 1 > ;> ¡ ) '> ) ) ) } ) ì ) ;, I ;, '> ? I I J .01..- 11% r~Lœ:- 20 '> -<I ! '~ '-. ~ \ I') \1 (: \, 1\ \1 \, '~ \ .'C \\ \ \, \ \ \ 1\\ '::~ \. Ì\ r', I " \ I~ < . ~ ~ \ I I I,,:, i I I 1 If J 1 ¿ ! ì I \ -----~- - -50 Delta Metal Thickness ('Yo) 50 2.4 MTIP01 (rad) 12.4 0 Line Speed (ft/rnin) -200 -6.4 MTIP12 (rad) 3.6 I KRU 1D-119 I i1 ¡)"' 19 API: 500292283600 Well Tvoe: INJ AnDie <â) TS: dea <â) TUBING SSSV Tvoe: NONE Oria Completion: 12116/1997 Anale <â) TD: 18 deg <â) 4515 (0-3777, Annular Fluid: ds1/3% KCI Last W/O: Rev Reason: Taaaed Tar 00:3.500, Reference Loa: Ref Loa Date: Last Update: 4/1512005 10:2.438) Last Tao: 3842' Tar TD: 4515 ftKB 4/1012005 Max Hole Annie: 31 den @ 2529 ...... "'I:;SiH: Nl..M 'RODUCTION DescriDtion Size TOD Bottom ND Wt Grade Thread (0-3777, CONDUCTOR 16.000 0 121 121 62.58 H-40 Welded 00:5.500, PRODUCTION 5.500 0 3777 3565 15.50 L-80 MBTC Wt:15.50) LINER 3.500 3777 4500 4247 9.30 L-80 EUE ITuDil'l/J\Stril'l/J\.... UI:§ING Size I Ton I Bottom I ND I Wt I Grade I Thread NIP 3.500 / 0 / 3777 / 3565 I 9.30 / L-80 / (3736-3737. "" 00:3.500) Interval ND lone Status Ft SPF Date TVDe Comment 3856 - 3892 3639 3673 WSD 36 4 5/1/1998 IPERF 2.5" HC, DP, 180 deg phasing, 90 dea orient SEAL 3922 - 3960 3701 - 3737 WSS 38 4 5/1/1998 IPERF 2.5" HC, DP, 180 deg phasing, (3776-3778, 90 den orient 00:4.000) 3970 - 3980 3746 3755 WSM 10 4 5/1/1998 IPERF 2.5" HC, DP, 180 deg phasing, 90 dea orient 3980 - 4000 3755 - 3774 WSM 20 4 4/30/1998 IPERF 2.5" HC, DP, 180 deg phasing, 90 deo orient - 4008 - 4022 3782 - 3795 WSA3 14 4 4/30/1998 IPERF 2.5" HC, DP, 180 deg phasing, Perf 90 den orient (3856-3892) -.- 4032 - 4048 3804 - 3819 WSA3 16 4 4130/1998 IPERF 2.5" HC, DP, 180 deg phasing, - 90 deo orient LINER -- - 4048 - 4068 3819 - 3838 WSA3 20 4 41811998 IPERF 2.5" HC, DP, 180 deg phasing, (3777-4500, .-- - 90 dea orient 00:3.500, - 4087 - 4097 3856 - 3866 WSA2 10 4 41811998 IPERF 2.5" He, DP, 180 deg phasing, Wt9.30) ."-"- --- 90 deo orient ::.= 4107 4145 3875 - 3911 WSA2 38 4 41811998 IPERF 2.5" He, DP, 180 deg phasing, Perf 90 dea orient (3922-3960) - 4170-4180 3934 < 3944 WSA2 10 4 41711998 IPERF 2.5" He, DP, 180 deg phasing, -- 90 den orient II">..,,,J --.- St MD NO Man Mfr Man Type V Mfr V Type I V 00 I Latch Port I IRO I Date Vlv - Run Cmnt Perf 1 )84 3478 BST ATX DMY I 1.0 T-1 / 0.000 0 /12116/19971 (3970-3980) \êaÜiD..et, .1.,.·1!;:\JV1 .RY Perf (3980-4000) -- DeDtl! ND TVDe DescriDtion ID - - 3736 3526 NIP Camco 'W-1' Selective Nipple 2.813 -.- -.- 3776 3564 SEAL Baker GBH-22 Locator Seal Assv 3.000 - - 4500 4247 Shoe Gemoco 0.000 Perf -- (4008-4022) --- -, -- - -.- - ---- Perf - (4032-4048) - - Perf - (4048-4068) - - - - -- Perf - (4087-4097) -- - - '- - -- -- --- Perf - (4107-4145) Perf - (4170-4180) - I I I I I I I I I I I I I I I I I 08/09/06 Sc~IIn~.Pg8I' RECEIVED (' \-:: NO. 3910 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth AUG 1 0 2006 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 .-a OK & Gas ConS. commission Anchorage ur~:gt-dd) Field: Kuparuk Well BL CD Color Job# Log Description Date 1 J-127 11216302 USIT 06/05/06 1 1D-119 11249924 INJECTION PROFILE 07/05/06 1 2L-321 11235382 LDL 07/24/06 1 2V-13 11235385 SBHP SURVEY 07/26/06 1 1Q-13 11249936 INJECTION PROFILE 08/02/06 1 1 Q-26 11249937 PROD PROFILE W/DEFT 08/03/06 1 1R-14 11235386 PROD PROFILE W/DEFT 08/03/06 1 1 G-09 11249938 INJECTION PROFILE 08/04/06 1 3N-16 11235389 SBHP SURVEY 08/05/06 1 1 E-112 11285935 MEM INJECTION PROFILE 08/05/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor ..---, \<>?4Ú j'-{'/ -""'Ii ( !(Z':;/OG DATE: Wednesday, July 12,2006 SUBJECT: Mechanical Integrity Tests CONOCOPHllLIPS ALASKA INC lD-] ]9 KUPARUK RIV U WSAK lD-119 l')...-'-1/ 1'~ \q FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv 5F3~ Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV U WSAK 10-119 API Well Number 50-029-22836-00-00 Inspector Name: Jeff Jones Insp Num: miUJ060711174812 Permit Number: 197-222-0 Inspection Date: 7/10/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well , lD-1I9 IT I· I I 3564 I IA I 200 2060 ]980 ]970 I , I ype nJ. i W ! TVD i I I I P.T. 1972220 !TypeTest ! SPT : Test psi I ]500 I OA I I i I I I I I I / Tubing! 1100 j ! 1100 i i Interval 4YRTST P/F P 1125 llOO I I Notes Monobore injector, 0.7 bbls diesel pumped. 1 well house inspected; no exceptions noted. Wednesday, July 12, 2006 Page 1 of I TUBING (0-3777, 00:3.500, 10:2.438) 'RooucnON (0-3777, 00:5.500, Wt:15.50) NIP (3736-3737, 00:3.500) SEAL (3776-3778, 00:4.000) Perf (3856-3892) LINER (3777-4500, 00:3.500. Wt:9.30) Perf (3922-3960) Perf (3970-3980) Perf (3980-4000) Perf (4008-4022) Perf (4032-4048) Perf (4048-4068) Perf (4087-4097) Perf (4107-4145) Perf (4170-4180) e e ConocoPhilUps Alaska, tn~. 110-119 KRU 1 D-119 Well T e:! INJ Or! Com letion: 12/16/1997 LastW/O:1 Ref Log Date: TO: 14515 ftKB Max Hole An Ie: 31 2529 To o o 3777 Bottom 121 3777 4500 TVD 121 3565 4247 Bottom 3777 TVD 3565 4 20 4 14 4 I 4/30/1998 I I ! 16 4 , 4/30/1998 ' I 20 4 I 4/8/1998 1 10 4 I IPERF 38 4 IPERF 10 4 ¡PERF V Mfr 1 V Type Vlv I Cmnt DMY Descri tion ID Camco 'W-1' Selective Ni Ie 2.813 Baker GBH-22 Locator Seal Ass 3.000 Gemoco 0.000 ~ =3 ~ ---1 - ----' --I -I ---¡ ---¡ -----J --j ---l i -------J - ------J I ---¡ I - I --i I I I I I I I I l D-119 (PID 1972220) & ID-139 (PID 2000490) Passing MIIIA ... ) ) Subject: ID-119 (PTD 1972220) & ID-139 (PTD 2000490) Passing MITIA reports. From: NSK Problem Well Supv <n1617@conocophillips.com> Date: Tue, 26 Ju12005 09:34:30 -0800r)~t.fì '?Þ>Il6. To: Thomas Maunder <tom_maunder@admin.state.ak.us>, James Regg o...-J <jim _regg@admîn.state.ak.us>, bob _fleckenstein@admin.state.ak.us Tom & Jim, Attached are passing MITT & MITIA data forms for 1 D-119 & 1 D-139 completed on 7/25/05. These test were performed to verify wellbore integrity of these mono-annulus injectors. The 1 D-119 was initially MITIA'd to 1500 psi on 7/20/05. The MITIA completed on 7/25/05 is at the higher pressure of 2500 psi. 1 D-119 was the first and only injector tested at the lower pressure, all subsequent integrity verification MITIAs have been at 2500 psi. The 1D-139 MITIA was performed with a plug set in the tbg and both an MITT and MITIA passed. There are six more mono-annulus injectors at 1 D that will be tested to verify integrity over the next week. Testing is 50% complete as 6 wells have been tested so far. Please let me know if you have any questions. Marie McConnell Problem Well Supervisor 659-7224 '" 'f:A\'~\~'\.~¡¡:Y (: ç 0 9; ~¡ <2·. oni] 0\"" ',I ..' ~ . \; t,...,t,., q,.H.c. ¡I (.>.. _'" ,..h, «MIT KRU 1D-139 07-25-05.xls» «MIT KRU 1D-119 07-25-05.xls» Content-Description: MIT KRU ID-139 07-25-05.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 Content-Description: MIT KRU ID-119 07-25-05.xls MIT KRU ID-119 07-25-05.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 1 of 1 7/26/2005 2:06 PM ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConoeoPhillips Alaska Inc. West Sak 1 KRUI 10-119 07/25/05 Arend 1 Rodgers - AES 1~1'- ~~J.- ~ 1\'lkch Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us o P Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas 'nj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey 0= Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) MIT Report Form Revised: 06/19/02 MIT KRU 10-119 07-25-05.xls ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test I Q7,",";J; (þ'2- .jþØ~l (~z,þ~ Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us OPERA TOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConoeoPhillips Alaska Inc. West Sak I KRU/ 10-11 9 07/20/05 Arend / Rodgers - AES o P o P Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: Test Details: ..... r~ CI 20nr. ¡~¡f~ þ,¡J;"J ~i E~) J.\ U G 'll ~J.. '" ..1 '\J~tI,ß~~" ",..~ .-..... TYPE INJ Codes F = Fresh Water Inj G = Gas 'nj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey 0= Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = other (describe in notes) MIT Report Form Revised: 06/19/02 MIT KRU 10-119 07-20-05.xls ,,,...--....., MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille O. TaylorèDi DATE: July 11, 2002 Chair tØ!j. . .. SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder ; Phillips Alaska P.I. Supervisor C) Æ);" 10 Pad , . '- ~ 10-10,10-119,10-120,1D-130 FROM: John Crisp Kuparuk River Field Petroleum Inspector Kuparuk River Unit NON- CONFIDENTIAL Well 4 P 4 P 4 P 4 P Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval 1= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover 0= Other (describe in notes) Test's Details 4 MIT's witnessed, no failures. M.I.T.'s performed: ~ Attachments: Number of Failures: º Total Time during tests: 3 hrs. cc: SCANNED AUG 0 1 2001 M IT report form 5/12/00 L.G. MIT PAI1D 07-11-02jc.xls 7/24/2002 l~ L- et ~.J~ THE MATERIAL UNDER THIS COVER HAS BEEN - MICROFILMED ON OR BEFORE JANUARY 03, 2001 . f 4fI þ , - 11 ~ - ..;¡ . IJ P ·w - - M IAL UNDER - - - - - - MAR K E R C:LORl\MFß.M.OOC ---~------------ -- ----- -- -- -- -- -------- Well Compliance Report File on Left side of folder - - - -- - - --- ----------- 197-222-0 MD 04515 r" T Name TVD 04261' KUPARUK RIV U WSAK ID-119 50- 029-22836-00 ARCO ¿Pletion Date: /4/8/98 Completed Status: 1 WINJ Current: Interval Sent Received T/C/D --- - - --- - - ----- D 8221 ~/ SPERRY MPT/GR/EWR4 L CBL ~L Fff\iA L ~L ~L 121-4515 OH 1/14/98 1/14/98 CH 5 3/27/98 3/25/98 OH 1/14/98 1/14/98 OH 1/14/98 1/14/98 CH 5 4/22/99 5/13/99 OH 1/13/98 1/14/98 3610-4296 L DGRJEWR4-MD L DGRJEWR4-TVD 121-4261 L INJP-SPINITEM/ PRES 3810-4230 R MWD SRVY Daily Well Ops JJjt,Jl1 ~RRY 0.-4515. tjL8L~l Are Dry Ditch Samples Required? yes ~d Received? ~.--..Wl~_ Analysis Description Receivéd:YêslTo"=·~"_·· Sampl\: Sël:~ -C' - Was the well cored? yes 1-' nO~)J"~ Comments: ------ - ~_[i-n~ _.~ - ----------- ---------- ~ ---- -- ------ ----- -- -- Monday, May 01,2000 Page 1 of 1 STATE OF ALASKA AL J OIL AND GAS CONSERVATION COt\. -SION REPOR. OF SUNDRY WELL OPERÃTIONS 1. Operations performed: Operation Shutdown _ Pull tubin Stimulate_ Alter casin 5. Type of Well: Development 41 ' RKB, Pad 71 Exploratory ----' 1. Unit or Property: Stratagrapic ----' Service ~ Ku aruk River Unit 8. Well number: 1 D- 119 9. Permit number/approval number: 97 - 222 10. API number: 50-029-22836-00 11. Field/Pool: Ku aruk River Field I West Sak Oil Pool Perforate _X 2. Name of Operator: ARC 0 Alaska, Inc. 3. Address: P.O. Box 100360 Anchora e, AK 99510-0360 4. Location of well at surface: 151' FNL, 598' FEL, See 23, T11 N, R 1 OE, UM At top of productive Interval: 78' FSL, 1528'FEL,See14,T11N,R10E,UM At effective depth: 132'FSL,1714'FEL,See14,T11N,R10E,UM At total depth: 138' FSL, 1738' FEL, See 14, T11N, R10E, UM 12. Present well condition summary Total Depth: measured true vertical 4515 feet Plugs (measured) _ None 4261 feet Effective Deptl measured true vertical 4438 feet Junk (measured) None 4198 feet Production 724' 3.5" Cemented Measured depth 9 cu yds High Earty 121' 325 Sx AS III LW & 3777' 445 Sx Class G wi 60 Sx AS I top jab Included in 5.5" csg 4501' True vertical depth 121' 3566' Casing Conductor Surface Length 80' 4460' Size 16" 5.5" 4248' Uner Perforation Depth measured 3856'-3892'; 3922'-3960'; 3970'-4000', 4008'-4022', 4032'-4068' 4087' -4097'; 41 07'-4145'; 4170'-4180' true vertical 3639'-3673'; 3701'-3737'; 3746'-3774', 3782'-3795', 3804'-3838' 3856'-3866'; 3875'-3911'; 3934'-3944' Tubing (size, grade, and measured depth) 3-1/2", 9.3 Ib/tt, L-80 @ 3777 Packers and SSSV (type and measured depth) Baker Seal Bore Extension @ 3778'; SSSV: None 13. Stimulation or cement squeeze summary Perforate well on 4/30/98 & 5/1/98. Intervals treated (measured) 3856'-3892'; 3922'-3960'; 3970'-3980'; 3980'-4000'; 4008'-4022'; 4032'-4048' Treatment description including volumes used and final pressure Perforate usin 2.5" HC uns wi DP char es @ 4s f, 180 de hosed & 90 de oriented, fp was 550 psi. Representitive Daily Average Production or Injection Data ¡f"",,¡ ~1 ~ C<' i r I /\ ~ I i re"l I t ---'I. I ¡ \¡ '=0\ i "'~)l\e",=,.f'i;~; \~_ 14. Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation o o 75 200 1025 Subse uent to 0 eration 15. Attachments MIT form Copies of Logs and Surveys run _ Daily Report of Well Operations -.X Oil Gas 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ()j), .. Tlfte: Producfton Engineering SupeNisor Dote Form 10-404 Rev 0 o o 850 16. Status of well classification as: 15 1025 Sus ended Service X 8/uI1'1 SUBMIT IN DUPUCAT ARCO Alaska, Inc. ...~ ~~ KUPARUK RIVER UNIT ELL SERVICE REPORT K1 (D-119(W4-6» WELL JOB SCOPE JOB NUMBER 1 D-119 PERFORATE, PERF SUPPORT 0406982349.2 DATE DAIL Y WORK UNIT NUMBER 05/01/98 PERFORATE - FINISH PERF WS INJ 2128 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 3 @ Yes 0 No @ Yes 0 No BARTZ JONES FIELD AFC# CC# DAILY COST ACCUM COST Signed ESTI MATE AK9013 18WSTF7SC $20,584 $55,084 Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Rnal Outer Ann 925 PSI 550 PSI 950 PSI OPSI OPSI OPSI DAILY SUMMARY SWS (BARTZ & CREW) MADE 5 RUNS & FINISHED PERFORATED FROM 3856' TO 3892',3922' TO 3960' & 3970' TO 3980'. RETURNED WELL TO INJ @ 20:15. TIME LOG ENTRY 10:15 SWS (BARTZ & CREW) & LRS MIRU, HELD TGSM. MU GUN & PT LUBRICATOR TO 3000#. 12:00 RIH WI 10', 2.5" HC, 4 SPF, DP, 180 DEG PHASED, 90 DEGORIENT, WHILE PUMPING 25 BBLS HOT DIESEL @ .5 BPM, 1100#. CORRILATE TO CBT LOG 2-25-98 & PERF FROM 3970' TO 3980'. 13:00 POH & LD GUNS, ALL SHOTS FIRED. 13:30 MU GUN, PT LUBRICATOR TO 3000#. RIH WI 20' X 2.5" GUN AS ABOVE, CORR. TO ABOVE LOG & PERFED FROM 3940' TO 3960'. 14:30 POH & LD GUN, ALL SHOTS FIRED. 15:00 MU GUN, PT LUB. TO 3000#. RIH WI 20' X 2.5" GUN WI TOP 2' BLANK AS ABOVE, CORR. TO ABOVE LOG & PERFED FROM 3922' TO 3940'. 16:15 POH & LD GUN, ALL SHOTS FIRED. 17:00 . MU GUN, PT LUB. TO 3000#. RIH WI 20' X 2.5" GUN AS ABOVE, CORR. TO ABOVE LOG & PERFED FROM 3872' TO 3892'. 17:45 POH & LD GUN, ALL SHOTS FIRED. 18:15 MU GUN, PT LUB. TO 3000#. RIH WI 20' X 2.5" GUN AS ABOVE WI TOP 4' BLANK, CORR TO ABOVE LOG & PERFED FROM 3856' TO 3872'. 19:00 POH & LD GUN, ALL SHOTS FIRED. 19:40 RIG DOWN. 20:30 RETURNED WELL TO INJ @ 20:15. RELEASED SWS. SERVICE COMPANY - SERVICE CAlL yeaST ACCUMTOTAL $560.00 $660.00 APC $250.00 $4,950.00 LITTLE RED $2,200.00 $4,180.00 SCHLUMBERGER $17,574.25 $45,294.50 TOTAL FIELD ESTIMATE $20,584.25 $55,084.50 ARca Alaska, Inc. ~~ ~~ KUPARUK RIVER UNIT lELL SERVICE REPORT K1 (D-119(W4-6» WELL JOB SCOPE JOB NUMBER 1 D-119 PERFORATE, PERF SUPPORT 0406982349.2 DATE DAIL Y WORK UNIT NUMBER 04/3()/98 PERFORATE - PERF WEST SAK INJ 2128 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 2 o Yes @ No @ Yes 0 No BARTZ JONES FIELD AFC# CC# DAILY COST ACCUM COST Signed ESTIMATE AK9013 18WSTF7SC $14,997 $34,500 Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 700 PSI 650PSI 200 PSI OPSI OPSI OPSI CAlLY SUMMARY SWS (BARTZ & CREW) PERFED WEST SAK IN~ IN 3 RUNS FROM 4032' TO 4048',4008' TO 4022' & 3980' TO 4000'. ALL SHOTS FIRED. RETURNED WELL TO INJECTION FOR THE NIGHT. TIME LOG ENTRY 09:30 SWS (BARTZ & CREW) MIRU, HELD TGSM (SLlPERY SURFACES). SECURED RADIO SILENCE (TOOK LONG TIME, LOTS OF ACTIVITY). MU GUN & PT lUBRICATOR TO 3000#. 11:15 RIH WI 20' GUN WI TOP 4' BLANK, 2.5" HC, DP, 4SPF, 180 DEG PHASE, 90 DEG ORIENT. CORR TO eBL lOG 2-25-98 & PERF FROM 4032' TO 4048'. 12:15 POH & LD GUN, ALL SHOTS FIRED. 13:00 MU GUN & PT LUBRICATOR TO 3000#. 13:45 RIH WI 20' GUN AS ABOVE, PUMP 25 BBlS DIESEL @ .5 BPM, 1100# WHILE RIH. CORR TO ABOVE LOG & PERFED FROM ·3980' TO 4000'. 14:30 POH & LD GUN, ALL SHOTS FIRED. 15:15 MU GUN & PT LUBERICATOR TO 3000#. 15:45 RIH WI 20' GUN WI TOP 6' BLANK AS ABOVE, CORR TO ABOVE LOG & PERFED FROM 4008' TO 4022". 16:20 POH & LD GUN, ALL SHOTS FIRED. 17:15 RETURNED WELL TO INJECTION. SWS RIGGED DOWN. 18:00 RELEASED SWS. . SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $100.00 $100.00 APC $1,200.00 $4,700.00 LITTLE RED $0.00 $1,980.00 SCHLUMBERGER $13,697.25 $27,720.25 TOTAL FIELD ESTIMATE $14,997.25 $34,500.25 >ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 ---¡:;--=~ ~~ ~~ April 28, 1998 ..::..;¡ ~o--a, "3 (;: ~d t t [c~ Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 ¡ --\ ; '¡. C ; ... A\8.,'\;',). Dn f', R~~~~~~a Commì"S\Q1í Subject: 1D-119 (Permit No. 97-222) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on West Sak ID-119. If there are any questions, please call 265-6890. Sincerely, ~w. ¡1~- T. W. Mc Kay Senior Drilling Engineer Kuparuk Development TWM/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ;¡--. ;'.0:.;-: ",~ - 1 Status of Well Classification of Service Well (; 1 to.. r; f~ ~, OIL 0 GAS 0 SUSPENDED 0 ABANDONEIU SERVICE [] Injector 7 Permit Number ¡.\iHS1(fl (1ïì ?7~ C}ClS Cons; tJOlT nl1~;sIur;.: 2 Name of Operator ARCO Alaska, Inc 3 Address ,0.; 1S10 !'i;¡UJ 97-222 8 API Number P.O. Box 100360, Anchorage, AK 99510-0360 4 Location of well at surface 50-029-22836 9 Unit or Lease Name 151' FNL, 598' FEL, Sec. 23, T11N, R10E, UM At Top Producing Interval 78'FSL, 1528'FEL,Sec. 14,T11N, R10E, UM At Total Depth : J-//(¡/1$, ~ 'Æi., . '¡ 6 Leàse Designation and Serial No. -~1Ì6 ~~ ~:- ¡\, H!.....,;;;;¡o" r l Kuparuk River Unit 10 Well Number ,. West Sak 10-119 11 Field and Pool 138' FSL, 1738' FEL, Sec. 14, T11 N, R10E, UM 5 Elevation in feet (indicate KB, OF, etc.) -' KUPARUK RIVER West Sak Oil Pool RKB 41', Pad 71' 12 Date Spudded 12-Dec-97 17 Total Depth (MD+ TVD) 4515' MD & 4261' TVD 13 Date T.D. Reached 13-Dec-97 18 Plug Back Depth (MD+TVD) 4438' MD & 4188' TVD ADL 25650 ALK 468 14 Date Compo ,Susp. or Aband. 08-Apr-98 19 Directional Survey YES ~ NO D 15 Water Depth, if offshore .116 No. of Completions NA feet MSL 1 20 Depth where SSSV set 21 Thickness of permafrost NA feet MD 1634' APPROX 22 Type Electric or Other Logs Run GR/Res 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD I TOP 8TM HOLE SIZE CEMENT RECORD CASING SIZE WT 16' 62.58# 5.5' 15.5# 3.5' 9.3# GRADE H-40 L-80 L-80 SURF. SURF. 3777' 121' 3777' 4501' 24' 8.5' 8.5' 9 cu yds High Early 325 sx AS III LW, 445 sx Class G, & 60 sx AS I 24 Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 25 SIZE TUBING RECORD 3.5' DEPTH SET (MD) 3777' PACKER SET (MD) 4048'-4068' MD 3819'-3838' TVD 4087'-4097' MD 3856'-3865' TVD 4107'-4145' MD 3875'-3911' TVD 4170'-4180' MD 3934'-3944' TVD 4 spf 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Date of Test Hours Tested PRODUCTION TEST IMethod of Operation (Flowing, gas lift, etc.) Injector PRODUCTION FO OIL-BBL GAS-MCF TEST PERIOI: r\nI0!t\f f\ I 1,,) f\ I lJ ! I \j Ii L 27 Date First Production WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing Press. Casing Pressure CALCULATED 24-HOUR RATE: OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (corr) 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A Form 10-407 Rev. 7-1-80 Submit in duplicate CONTINUED ON REVERSE SIDE ---" 29. 30. GEOLOGIC MARKERS FORMATION TESTS MEAS DEPTH TRUE VERT. DEPTH Include inteNal tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. NAME Top West Sak Sand Base West Sak Sand 3852' 4313' 3635' 4069' Annulus left open - freeze protected with diesel. /".ç\ ;~_'k ¿ þ':' ~? . . f~,~i;~ C;\\ ?oc (~~~;~~~~~'f,f.~~'iÎS{;' 31. LIST OF ATTACHMENTS Summar of Dail Drillin Re orts, Directional SUNey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. /J , ~~¡V/~/C .~./ I Î /A ~,/ZI?~i/Vt:;;) 'f- 2r-1? Signed / . W· f!/I Title ~&I/J~/¿ DATE Prepared by Name/Number Sharon Allsup-Drake/263-4612 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (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: 2/18/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 -------------------------------------------------------------------------------- -------------------------------------------------------------------------------- WELL:1D-119 WELL_ID: AK9013 TYPE: AFC: AK9013 STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: SPUD:12/12/97 START COMP: RIG:PARKER 245 WI: 0% SECURITY: 0 API NUMBER: 50-029-22836-00 BLOCK: FINAL: -------------------------------------------------------------------------------- -------------------------------------------------------------------------------- 12/11/97 (D1) TD : 12 l' ( 12 1 ) SUPV: DEB 12/12/97 (D2) TD : 2 3 0 l' (2 18 0 ) SUPV: DEB 12/13/97 (D3) TD: 4515' (2214) SUPV: DEB 12/14/97 (D4) TD : 4 5 15' ( 0 ) SUPV: DEB 12/15/97 (D5) TD : 4 515' ( 0 ) SUPV:MMC 12/16/97 (D6) TD : 4 515' ( 0 ) SUPV:MC MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 DRILLING AT 250' Move rig 15' from 1D-120 to 1D-119. Accept rig @ 2400 hrs. 12/11/97 MW: 9.1 VISC: 280 PV/YP: 26/56 APIWL: 6.8 DRILLING @ 3500' NU diverter system. Function test diverter system. Spud at 121' and drill to 2301'. MW: 9.1 VISC: 270 PV/YP: 28/50 APIWL: 6.4 C&C MUD, ON BOTTOM W/HOLE OPEN Drill from 2301' to 4515' MD. Circulate hole clean and condition mud. Swabbing from 3600' to 2700', tight and swabbing from 2700' to 2020'. Wash and ream out from 2020' to 1735'. Wash out from 1735' to HWDP at 1250'. MW: 9.3 VISC: 92 PV/YP: 25/36 APIWL: 7.0 WASH CEMENT OUT OF RISER Ream tight hole from 1959' to 2054', 2567' to 2622' & 2940' to 3190'. Hold pre-job safety meeting. Run 3.5" x 5.5" casing string. MW: 8.6 VISC: 38 PV/YP: 5/15 PREP TO RUN 3.5" TUBING Pump 1st stage cement and 2nd stage cement. cement, plug and stage tool at 1840'. Drill & ream to 1901'. APIWL: 20.0 Drill out stringers, wash MW: 8.8 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED Run 3.5" completion. ND BOP, NU tree and test to 5000 psi for 10 minutes, OK. Release rig @ 2400 hrs. 12/16/97. End of WellSummary for Well:AK9013 WELL 10-119 DATE 04/07/98 DAY ARCO Alaska, Inc. ...~ ~~ JOB SCOPE PERFORATE, PERF SUPPORT DAILY WORK PERFORATE NEW WEST SAK INJ OPERATION COMPLETE SUCCESSFUL NO NO KUPARUK RIVER UNIT WELL SERVICE REPORT K1 1 D-119 W 4-6 JOB NUMBER 0406982349.2 UNIT NUMBER Initial Tbg Press o PSI Initial Inner Ann OPSI KEY PERSON BARTZ Final Inner Ann o PSI SUPERVISOR JONES Initial Outer Ann Final Outer Ann o PSI 0 PSI 1 DAILY SUMMARY SWS CRANE BROKE FAN BELT, OVERHEATED & SPILLED 1/2 GAL ANTIFREEZE (CLEAN UP). PERFED W/4 DP SPF FROM 4170' TO 4180'. SPILLED 2 GAL DIESEL FROM LUBRICATOR CLEANED UP. RIG DOWN FOR NIGHT. TIME LOG ENTRY 10:30 SWS (BARTZ & CREW) SPOT EQUIPMENT. INSTALL SCAFFOLD. 11:30 SWS STINGER CRANE FAN BELT BROKE, OVERHEATED & SPILLED 1/2 GAL ANTI-FREEZE. REPORTED & CLEANED SPILL. REPLACED BROKEN FAN BELT. 13:00 RIG UP, HELD TGSM. ASSURED RADIO SILENCE, ARMED PERF GUN. 15:30 INSTALL & TEST LUBRICATOR @ 3000#. (HAD LEAK FIRST TIME, CUT O-RING) 16:30 RIH WI 10' - 2 1/8" DP 4 SPF, 180 DEG PHASED, 90 DEG ORIENTED PERF GUN. CORRELATED & PERFED FROM 4170' TO 4180'. 18:15 POH WI PERF GUN. WHEN REMOVING LUBRICATOR, 2 GALS DIESEL SPILLED FROM LUB. (REPORTED & CLEANED UP SPILL). 20:00 RIG DOWN LUBRICATOR & SECURED EQUIPMENT (CREW NEEDS REST) ARca Alaska, Inc. ~~ ~~ JOB SCOPE PERFORATE, PERF SUPPORT DAILY WORK PERFORATE OPERATION COMPLETE NO Initial Tbg Press 300 PS I WELL 1 D-119 DATE 04/08/98 DAY 1 ~--~.,/ KUPARUK RIVER UNIT WELL SERVICE REPORT K1 1D-119 W4-6 JOB NUMBER 0406982349.2 UNIT NUMBER SUCCESSFUL NO Initial Inner Ann o PSI KEY PERSON BARTZ Final Inner Ann o PSI SUPERVISOR JONES Initial Outer Ann Final Outer Ann o PSI 0 PSI CAlLY SUMMARY SWS PERFORATED WI 2.5" DP 4 SPF FROM 4107' - 4145',4087' - 4097' & 4048' - 4068' WLM. DONE IN 4 RUNS, ONE RUN DID NOT FIRE, HAD TO CUT OFF 50' OF E-LlNE & RETIE ROPE SOCKET. TIME LOG ENTRY 07:30 SWS (BARTZ & CREW) RU, HELD TGSM (COMMUNICATION) & SECURED RADIO SILENCE. MADE UP PERF GUN. 09:30 PT LUBRICATOR TO 3000#. RIH WI 20' 2.5" DP GUN W/4 SPF, 180 DEG PHASE, 90 DEG ORIENT. CORR TO SWS CBL LOG & PERFED FROM 4125' TO 4145'. 10:30 POH & LD PERF GUN, ALL SHOTS FIRED. 11 :30 MU GUN, PT LUBRICATOR TO 3000#. RIH WI 18' 2.5" 4 SPF DP GUN AS ABOVE, CORR & PERFED FROM 4107' TO 4125'. 13:15 POH & LD PERF GUN, ALL SHOTS FIRED. 14:15 MU GUN, PT LUBRICATOR TO 3000#. RIH WI 20' 2.5" 4 SPF DP GUN AS ABOVE. CCL STOPPED WORKING. POH & DISARMED PERF GUN. 16:00 FOUND E-LlNE SHORTED, CUT OFF 50' OF LINE & RETIED ROPE SOCKET. MU GUN, PT LUBRICATOR. 18:30 RIH WI 20' 2.5" 4 SPF DP GUN AS ABOVE, CORR TO LOG & PERFED FROM 4048' TO 4068'. POH & LD GUN, ALL SHOTS FIRED. 20:15 MU GUN, PT LUBRICATOR TO 3000#. RIH WI 10' 2.5" 4 SPF DP GUN AS ABOVE, CORR TO LOG & PERFED FROM 4087' TO 4097'. POH & LD GUN, ALL SHOTS FIRED. 23:00 RIGGED DOWN LUBRICATOR & MADE WELL SAFE FOR THE NIGHT. C¡7~ c??~ SPERRY-SUN DRILLING SERVICES PAGE 1 ANCHORAGE ALASKA ARCO ALASKA, INC. DATE OF SURVEY: 121397 WEST SAK / lD-119 MWD SURVEY 500292283600 JOB NUMBER: AKMM80046 NORTH SLOPE BOROUGH KELLY BUSHING ELEV. = 111.50 FT. COMPUTATION DATE: 1/ 8/98 OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/l00 NORTH/SOUTH EAST/WEST SECT. .00 .00 -111.50 0 0 N .00 E .00 .OON .OOE .00 121.00 121.00 9.50 0 0 N .'00 E .00 .OON .OOE .00 183.00 183.00 71.50 0 30 N 60.00 E .81 .14N .23E -.19 379.49 379.46 267.96 1 9 N 69.18 E .34 1.27N 2.84E -2.42 561.93 561.87 450.37 0 56 N 6.22 E .61 3.41N 4.72E -3.70 743.23 743.08 631.58 2 24 N 58.61 W 1.20 6.87N 1.64E .16 924.95 924.62 813.12 2 39 S 82.47 W .94 8.30N 5.78W 7.71 1106.63 1106.12 994.62 2 32 S 79.00 W .11 6.98N 13.93W 15.25 1289.90 1289.25 1177.75 1 49 N 59.49 W .92 7.68N 20.45W 21.74 1483.19 1482.41 1370.91 2 19 N 58.01 W .26 11.32N 26.43W 28.44 1579.10 1578.13 1466.63 4 46 N 77.69 W 2.83 13.20N 31.98W 34.29 1674.82 1673.30 1561.80 7 26 N 76.53 W 2.78 15.50N 41.91W 44.47 1765.61 1762.95 1651.45 10 38 N 76.42 W 3.54 18.84N 55.78W 58.74 1862.20 1857.39 1745.89 13 30 N 76.97 W 2.96 23.48N 75.45W 78.95 1959.97 1951.89 1840.39 16 11 N 75.66 W 2.76 29.43N 99.79W 104.00 2055.39 2042.58 1931.08 19 58 N 75.68 W 3.97 36 . 7 6N 128.48W 133.61 2150.96 2131.40 2019.90 23 17 N 75.96 W 3.48 45.39N 162.65W 168.85 2245.75 2217.47 2105.97 26 13 N 75.68 W 3.08 55.12N 201.14W 208.54 2340.61 2301.69 2190.19 28 32 N 73.11 W 2.75 66.89N 243.14W 252.15 2434.60 2384.03 2272.53 29 6 N 72.49 W .68 80.29N 286.43W 297.44 2529.18 2466.07 2354.57 30 33 N 74.38 W 1.83 93.69N 331.53W 344.46 2624.89 2548.61 2437.11 30 16 N 74.74 W .36 106.59N 378.23W 392.91 2717.78 2628.93 2517.43 30 1 N 75..72 W .59 118.48N 423.34W 439.55 2906.80 2792.97 2681.47 29 33 N 77.09 W .43 140.56N 514.61W 533.44 3098.06 2959.40 2847.90 29 29 N 78.12 W .27 160.79N 606.66W 627.61 3286.11 3123.75 3012.25 28 39 N 78.95 W .49 178.96N 696.21W 718.84 3474.57 3289.60 3178.10 28 2 N 80.21 W .46 195.16N 784.22W 808.07 3569.53 3374.07 3262.57 26 18 N 76.85 W 2.43 203.74N 826.71W 851.34 3662.90 3458.67 3347.17 23 44 N 75.23 W 2.85 213.24N 865.04W 890.82 3756.92 3545.68 3434.18 20 45 N 75.58 W 3.17 222.22N 899.48W 926.42 3851.10 3634.00 3522.50 19 51 N 71.77 W 1.70 231.38N 930.84W 959.08 3948.78 3725.88 3614.38 19 49 N 72.49 W .25 241.55N 962.40W 992.18 4041.83 3813.44 3701.94 19 43 N 72.92 W .18 250.91N 992.45W 1023.63 4136.52 3902.64 3791.14 19 28 N 73.60 W .36 260.06N 1022.88W 1055.38 4232.07 3992.77 3881.27 19 18 N 74.34 W .31 268.83N 1053.37W 1087.10 ~=t' f:.~(-; EJ t:; L) ~j AN '\ 4\~:,~f;; ORIGINAL ~-}H&, f>·~i:? ~lX1r:,~'t(H ~-~q8 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 ARCO ALASKA, INC. WEST SAK / 1D-119 500292283600 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/ 8/98 DATE OF SURVEY: 121397 MWD SURVEY JOB NUMBER: AKMM80046 KELLY BUSHING ELEV. = 111.50 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 4326.10 4081.63 3970.13 18 52 N 75.47 W .61 276.84N 1083.06W 1117.85 4456.88 4205.61 4094.11 18 14 N 76.58 W .55 286.89N 1123.44W 1159.46 4515.00 4260.81 4149.31 18 14 N 76.58 W .00 291.12N 1141.14W 1177.65 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT 1177.69 FEET AT NORTH 75 DEG. 41 MIN. WEST AT MD 4515 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 284.75 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD PROJECTED SURVEY AT 4,515.00' MD - - ~-' ~---- -./ SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 ARCO ALASKA, INC. WEST SAK / 1D-119 500292283600 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/ 8/98 DATE OF SURVEY: 121397 JOB NUMBER: AKMM80046 KELLY BUSHING ELEV. = 111.50 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION .00 .00 -111.50 .00 N .00 E .00 1000.00 999.59 888.09 7.84 N 9.24 W .41 .41 2000.00 1990.17 1878.67 32.33 N 111.12 W 9.83 9.42 3000.00 2874.04 2762.54 150.83 N 559.42 W 125.96 116.13 4000.00 3774.07 3662.57 246; 76 N 978.96 W 225.93 99.97 4515.00 4260.81 4149.31 291.12 N 1141.14 W 254.19 28.26 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA ARCO ALASKA, INC. WEST SAK / ID-119 500292283600 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/ 8/98 PAGE 4 DATE OF SURVEY: 121397 JOB NUMBER: AKMM80046 KELLY BUSHING ELEV. = 111.50 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH .00 111.50 211.50 311.51 411.53 511.55 611.56 711.62 811.71 911.81 1011.92 1112.02 1212.11 1312.16 1412.22 1512.31 1612.61 1713.41 1815.14 1918.04 2022.46 2129.37 2239.11 2351.78 2466.04 2581.92 2697.64 2813.11 2928.10 3043.03 3157.92 3272.15 3386.08 3499.38 .00 111.50 211.50 311.50 411.50 511.50 611.50 711.50 811.50 911.50 1011.50 1111.50 1211.50 1311.50 1411.50 1511.50 1611.50 1711.50 1811.50 1911.50 2011.50 2111.50 2211.50 2311.50 2411.50 2511.50 2611.50 2711.50 2811.50 2911.50 3011.50 3111.50 3211.50 3311.50 -111.50 .00 100.00 200.00 300.00 400.00 500.00 600.00 700.00 800.00 900.00 1000.00 1100.00 1200.00 1300.00 1400.00 1500.00 1600.00 1700.00 1800.00 1900.00 2000.00 2100.00 2200.00 2300.00 2400.00 2500.00 2600.00 2700.00 2800.00 2900.00 3000.00 3100.00 3200.00 TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION .00 N .00 N .26 N .78 N 1.50 N 2.59 N 4.22 N 6.18 N 8.36 N 8.38 N 7.76 N 6.93 N 6.42 N 8.05 N 9.80 N 11.93 N 13.88 N 16.78 N 21.11 N 26.68 N 34.07 N 43.35 N 54.39 N 68.44 N 84.89 N 100.89 N 116.00 N 130.18 N 142.91 N 155.22 N 166.86 N 177.68 N 188.08 N 197.14 N .00 E .00 E .45 E 1.55 E 3.44 E 4.63 E 4.81 E 2.77 E .80 W 5.18 W 9.78 W 14.17 W 18.31 W 21.07 W 23.99 W 27.66 W 34.99 W 47.23 W 65.31 W 88.85 W 117.94 W 154.52 W 198.31 W 248.24 W 301.02 W 357.34 W 413.58 W 469.54 W 524.85 W 580.15 W 635.49 W 689.64 W 743.23 W 795.71 W .00 .00 .00 .01 .03 .05 .06 .12 .21 .31 .42 .52 .61 .66 .72 .81 1.11 1.91 3.64 6.54 10.96 17.87 27.61 40.28 54.54 70.42 86.14 101.61 116.60 131.53 146.42 160.65 174.58 187.88 .00 .00 .01 ·.02 .02 .01 .06 .09 .10 .11 .10 .09 .05 .06 .09 .30 .80 1.73 2.90 4.43 6.91 9.74 12.67 14.26 15.88 15.72 15.47 14.98 14.94 14.88 14.24 13.93 13.30 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA ARCO ALASKA, INC. WEST SAK / 10-119 500292283600 NORTH SLOPE BOROUGH COMPUTATION DATE: 1/ 8/98 .PAGE 5 DATE OF SURVEY: 121397 JOB NUMBER: AKMM80046 KELLY BUSHING ELEV. = 111.50 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH 3611.07 3411.50 3720.23 3511.50 3827.18 3611.50 3933.49 3711.50 4039.77 3811.50 4145.91 4251.92 4357.67 4463.08 4515.00 3911.50 4011.50 4111.50 4211.50 4260.81 TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 3300.00 3400.00 3500.00 3600.00 3700.00 3800.00 3900.00 4000.00 4100.00 4149.31 207.95 N 218.87 N 228.84 N 239.99 N 250.71 N 260.95 N 270.60 N 279.40 N 287.34 N 291.11 N 844.23 W 886.55 W 923.13 W 957.45 W 991.79 W 1025.88 W 1059.69 W 1092.95 W 1125.33 W 1141.14 W 199.57 208.73 215.68 221.99 228.27 234.41 240.42 246.17 251.58 254.19 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS 11.69 9.15 6.95 6.32 6.27 6.15 6.00 5.75 5.42 2.61 3/27/98 [~--=-~ - NO. 11965 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm AUn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: West Sak (Reservoir Analysis Logs) Well Job # Log Description Date BL RF Sepia Floppy Disk 7- J. ). ,. ;l.:J z. WS 10-119 CBL SLlM-CMT 980225 1 1 J WS 1 0-120 CBL SLlM-CMT 980225 1 1 SIGNED: J ~V~ --~~~--------------------------------- DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. 5pe~rV-5un· CRILLING SERVices ---~--- -_._~------- WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 January 14, 1998 RE: MWD Formation Evaluation Logs .--.., /""\ {'\ -~ r-1 .¡ 0- g ¡ j ,- :/ j).?- \ 1 .~q ID-119, AK-:rvß1-80046 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of Jim GalVÍ1\ S peny-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-22836-00 ð~-C· .~ ~ 4'f't~¡ ~,,~ il j. "".;~.,~ ~~ Š v a.ø:."'" f¡\rl 1 ¿l '99H ~ ;~,~.. .} Gri.') (....cos. C{)mm¡~,~!~ c \ '~''fK "':;;(;£ 5631 Silverado Way, Suite G . Anchorage, .AJaska 99518 . (907) 563-3256 . Fax (907) 563-7252 A Dresser Industries. Inc. Company sper-'r-'v-sun CRILLING SeRVIc:eS WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 January 14, 1998 Q-rr- cvn---;ì- \ RE: MWD Formation Evaluation Logs 1D-119, AK-MM-80046 The teclmical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 5631Silverado Way, #G, Anchorage, AK 99518 ID-119: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-22836-00 1 Blueline 1 Folded Sepia 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22836-00 1 Blueline 1 Folded Sepia cÝ~7i:;~ ·c;: «è; 1=:: ·~',J/;c ".~ } ;.~"; ~.ç.. ~~..:;."'.ti Z ...~r ~- _.~ .-.:J.!'- ~ ,,~~NI 4 ~i.1~;~~ "~i~ ...", "" ~ \,;::.--i-"';-~·:< ': -;f ~5: '_J::-:-; ~~CJ~~~. i ..,--~:-~;~~I . ~_:1~~;:~-~(~1t¡8 5631 Silverado Way, Suite G . Anchorage, AJaska 99518 . (907) 563-3256 . Fax (907) 563-7252 5pe~~Y-5un- CRILLING SERVICES 13-Jan-98 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Ql-?--?-'?- Re: Distribution of Survey Data for Well 10-119 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: 0.00' MD Window / Kickoff Survey: n/a' MD (if applicable) Projected Survey: 4,515.00' MD Please call me at 563-3256 if you have any questions or concerns. Regards, /l ~.L--. Attachment(s) & ~~ \,,~ç~~ ~;(.:.¿{ ~~.~:_-=: ~~ '~/ :'o,,--ç-~-~:> ,,-''--; William T. Allen Survey Manager ~~ t !" ~ ~.. i). d ,~\ r~ )". 5631 Silverado Way, Suite G . Anchorage, ,AJaska 99518 . (907) 563-3256 . Fax (907) 563-7252 A Dresser Industries, Inc. Company TONY KNOWLE$, GOVEF~NOFt ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 December 5, 1997 Michael Zanghi Drilling Superintendent ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit West Sak 1D-119(F4) ARCO Alaska. Inc. Permit No: 97-222 Sur. Loc.: 151'FNL, 598'FEL, Sec. 23, TllN, R10E, UM Btmhole Loc: 152'FSL, 1751'FEL, Sec. 14, TllN, R10E. 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. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and 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 tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Chairman ~ BY ORDER OF THE COMMISSION dlf/enclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmentalt Conservation w/o encl. STATE OF ALASKA .... ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 ^^G 25.005 la. Type of Work Drill X Redrill J lb Type of Well Exploratory ~'l StratigraphicTest Re-Entry DeepenJ Service X Development Gas FI SingleZone X Multiple Zone FI 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 71' feet Kuparuk River Field 3. Address 6. Property Designation West Sak Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25650, ALK 468 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 151' FNL, 598' FEL, Sec. 23, T11 N, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET) 8. Well number Number 109' FSL, 1587' FEL, Sec. 14, T11N, R10E, UM West Sak 1D-119 (F4) #U-630610 At total depth 9. Approximate spud date Amount 152' FSL, 1751' FEL, Sec. 14, T11 N, R10E, UM 12/11/97 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1D-04 4516' MD 1751' @ TD feet 27.2' @ 740' feet 2560 4243' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 1400' feet Maximum hole angle 31.43° Maximum surface 1419 psig At total depth 1865 psig (TVD) 18. Casing program Setting Depth size Specifications Top Bottom Quantit7 of cement Hole Casing Weight Grade Ooupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 77' 41' 41' 118' 118' +_200 CF 8.5" 5.5" 15.5# L-80 BTC MOl:: 3728' 41' 41' 3769' 3542' 471 Sx Arcticset III & 8.5" 3.5" 9.3# L-80 8rd 747' 3769' 3545' 4516' 4243' 426 Sx Class G & 60 sx AS I ./. 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet0 RIGINAL Effective depth: measured feet Junk (measured) '-' true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural RECEIVED Intermediate Produotion Liner ~OV ~ ~J Perforation depth: measured true vertical A]ask~ 0il & Gas Cons. Anchorage 20. Attachments Filing fee X Property plat [] BOP Sketch [] Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed"~' ~~' ~'~/"~/~//~/~ ~--~/?¢¢~/ Title Drilling Superintendent Date Commission Use Only Permit Number I AP, number j App)o~,~ d..a~.. J see cover,etter for ~.~ ¢ 2_.- ~._.~.. 50- c::3 ~. ¢--' ~ ~ ~ ~' "¢'"~' other requirements Conditions of approval Samples required J--: Yes j~ No Mud log required J~ Yes ,J~ No Hydrogen sulfide measures r~ Yes [~,No Directional survey required I~ Yes FI No Required workingpressureforBOPE Fj2M ~ 3M BI 5M r-J 1OM r~J 15M Other: Origlriai [Jlgii~u Oavid W. Johnston by order of Date Approved by Commissioner the commission Form 10-401 Rev. 7-24-89 Submit in triplicate Drill, Case and Completion Plan for West Sak 1D-119 (F4) Monobore Injector General Procedure: . Excavate cellar, install cellar box, set and cement 16" conductor to +/- 110' RKB. Weld landing ring on conductor. 2. Move in / rig up drilling rig. Install diverter & function test same. , Spud and directionally drill 8-1/2" hole to desired target through West Sak interval. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. NOTE: A 9-7/8" hole may be drilled depending on the hole conditions encountered. 4. Condition hole for casing, trip out. , Run and cement 3-1/2" 9.3# L80 8RD x 5-1/2" 15.5# L80 BTC tapered casing string to surface, displace cement with mud. Perform stage job and top job as required. NOTE: Stage (DV) tool to be installed +/- 200 ft TVD below the base of permafrost interval. , Nipple down diverter and install wellhead. Nipple up BOP stack and pressure test same to 3000 psi. . Pick up 4-3/4" mill tooth bit, 3-1/2" drill collars, and 2-7/8" drill pipe. Trip in and drill out stage collar. Clean out to top of 3-1/2" casing. o Pressure casing to 3,000 psi for 30 minutes per AOGCC regulations. Record results. . Swap well over to non-freezing completion brine. Circulate well clean. Trip out. 10. Rig up and run 3-1/2" tubing tieback to surface for monobore injector. Sting into seal bore and pressure test tubing and annulus to 3,000 psi. Set tubing hanger. Install back pressure valve. 11. Nipple down BOP stack. Install production tree and pressure test same. 12. Secure well, release rig. Page 1 13. 14. 15. 16. 17. Rig up Coiled Tubing Unit (CTU) and clean out 3-1/2" monobore tubing to PBTD. Circulate well to clean brine. Secure well and release CTU. Rig up E-line unit and RIH with CBL/CET, and run cement bond Icg across West Sak interval. Report results to office for remedial action if necessary. Rig up E-line unit and RIH with through-tubing perforating guns. Perforate well overbalanced. POOH with perf guns. Repeat runs as required to perforate all desired West Sak intervals. Rig down E-line unit. Install back pressure valve, shut in and secure well. TAB, 11/20/97, Rev. 1 RECEIVED ~!ask~ Oi~ & O~s Cons. Co~missio~ Anchorage Page 2 DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS & DRILLING AREA RISKS West Sak 1 D-119 (F4) Drilling Fluid Type Extended Bentonite Slurry Drillinq Fluid Properties: Property Density Plastic Viscosity Yield Point Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to TD Initial 8.5-9.0 ppg 8-15 35-70 10-25 10-30 8-15 8.0-10.0 4-6 % Drill Out to TD Final 10.0 ppg 15-35 35-70 10-25 10-35 5-7 8.0-9.5 8-12% Drilling Fluid System: Tandem Brandt Scalping Shale Shakers Triple Derrick Flow Line Cleaners Solids Processing System to Minimize Drilling Waste Desander, Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Mud Hoppers with Mixing Pumps *Spud mud should be adjusted to a FV between 200 - 250 sec/qt to drill gravel beds. Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Only one hole section will be drilled in this well. This single hole section will be drilled using a diverter system only for well control. A tapered 5-1/2" x 3-1/2" surface / production casing string will be run at total depth (TD). This combination surface / production casing will be cemented to surface using a stage (DV) collar. The stage collar will be placed approximately 200 feet TVD below the base of the permafrost interval. MASP (Maximum Anticipated Surface Pressure): Based on actual well test data from the nearby WSl-01 well, expected reservoir pressures in the West Sak sands in the 1D pad area vary from 0.43 to 0.46 psi/ft, or 8.2 to 8.8 ppg EMW (equivalent mud weight), depending on the TVD of the sand layer being evaluated. Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.6 ppg can be predicted as a maximum mud weight required to safely drill this formation, assuming a TVD of 3,635' MD/TVD. Experience in the area has proven that these zones can be safely drilled using a diverter system only for well control purposes. The rig diverter system will be filled with water or mud and function tested prior to spudding the well. Since the combination surface / production casing will not be drilled out, leakoff test and MASP calculations are not necessary for drilling ahead. However, MASP calculations for cased hole operations are in order. Calculating MASP based on the highest recorded reservoir pressure from the WSl-01 well, and assuming a gas gradient of 0.11 psi/ft from the West Sak base in the West Sak 1D-119 (F4) well to surface, the following MASP can be computed: MASP (4055 ft)(0.46 - 0.11 psi/fi) 1419 psi Based on this calculation for MASP, it will only be necessary to test the BOP equipment to a maximum of 3,000 psi. Following the cementing of the $-1/2" x 3-1/2" combination surface / production casing in this well, the BOP stack will be installed and tested to 3,000 psi. The stage collar will then be drilled out and the well cleaned out to PBTD. At that time, the casing will be pressure tested for 30 minutes at a surface pressure of 3,000 psi as well. The 5-1/2" 15.5# L80 BTC casing to be used has a burst rating of 7,000 psi; 70 % of this burst rating is 4,900 psi. After testing, a 3-1/2" tubing tieback string will be installed in the well to be used as the injection string. Drillin_q Area Risks: Drilling risks in the West Sak 1D-119 (F4) area are limited to lost circulation and potential borehole instability in and below the permafrost formation. Lost circulation will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. Based on previous Drill Site 1D drilling results, 10.0 ppg mud should be more than adequate to control both the Ugnu and West Sak formation pressures without resulting in lost circulation. ARCO has drilled through the West Sak formation many times in nearby Kuparuk wells. For this reason, AAI requests that the requirements listed in 20 AAC 25.033 (e) and 20 AAC 25.061 (a) (pertaining to predicted overpressured strata and seismic refraction / reflection analysis, respectively) be waived for the drilling of West Sak 1D-119 (F4). Well Proximity Risks: The nearest existing well to West Sak 1D-119 (F4) is KRU 1D-04. As designed, the minimum distance between the two wells would be 27' at 740' MD. Annular Pumping Activities: Incidental fluids generated from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface / production casing annulus of an existing well on DS-1D. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. In addition, the West Sak 1D-119 (F4) surface casing / production tubing annulus will be filled with diesel and/or non-freezing brine after setting the 3-1/2" tubing tieback string and prior to the drilling rig moving off of the well. TAB, 11/20/97 C~eoted ~ ~inch For: T McKAY Octe plotted : 6-Oct-g7 Plot Reference ~B WS lO-Ilg/F4 Ver~,~. Coord[notes are ;n feet reference slot ~119. T~e Ve~col Depths ore ref~ence 250 500 75O 1ooo 1250 1500 1750 2000 2250 2500 2750 5000 3250 3500 3750 4000 4250 Structure: Pod 1D I1: Field : Kuparuk River Unit Location : North Slope, AlaskaI TD LOCATION: 152' FSL, 1751' FEL SEC. 14, T11N, RIOE <-- West (feet) 12oo 1~oo lOOO goo 800 70° 600 500 400 3°0 2°0 lOO 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 ~ ~ ~ TARG~ o~ ~D=3778 ~ TMD=4021 K0P TVI)=1400 TMI)=1400 DEP=0 3.00 6.00 B/ PERMAFROST TVD=1652 TMD=1633 DEP=14 9.00 12.00 15.00 DLS: 5.00 deg per 100 ft 18.00 21.00 24.00 27.00 30.00 EOC TVD=2396 TMD=2448 OEP=280 NORTH 260 WEST 989 (bo~' SURFACE LOCATION: 151' FNL, 598' FEL SEC. 23, T11N, R10E 284.75 AZIMUTH 1023' (TO TARGET) MAXIMUM ANGLE 31.43 DEG T/ UGNU SNDS TVD=2957 TMO=3105 DEP=623 BEGIN ANGLE DROP TVD=3121 TMD=3297 DEP=723 50.00 28.00 26.00 24.00 22.00 DLS: 2.00 deg per 100 ft T/ W SAK SNDS(EOD) TVD=3635 TMD=3869 DEP=971 'ARGET - A3 TVD=3778 TMD=4021 BEP=1023 B/ W SAK SNDS TVD=4055 TMD=4316 DEP=1124 ~%~> TD - CSG PT TVD=4243 TMD=4516 DEP=l192 i i ]i I i it I I i i 0 250 500 750 1000 1250 Vertical Section (feet) -:> TARGET ANGLE 20 DEG 0 1 oo ~ ~ ~ 5oo 4OO 300 200 100 o 100 Azimuth 284.75 with reference 0.00 N, 0.00 E from slot #119 C,eoted W finch For: T McKAY Dote plotted : 2?--Oct--§? Plot Reference [s W~ 1D-119/F4 Vets./~5. I I Coordinot ..... in feet roi ....... lot ~119.I iAkCO ALA _ KA, Structure : Pad 1D Well : F4 Field : Kuporuk River Unit Location : North Slope, Alaska 320 280 240 <- West (feet) 640 600 560 520 480 440 400 360 520 280 240 200 160 120 80 40 0 40 //~0 ]00 76O 720 68O I I I I I I I I I .1 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---J-./____ I[",.q .... ,,;. 520 '- 280 '-- 240 ~ .......... 3200 2600 2500 2400 2300 ""'"'-,~,.,.,,., '"~ 200 200 - __ 2200 21 O0 2000 21 O0 ' - ........ 3100 1900 1800 17(~3"-.. 1600 1500 3000 "" 160 160- ' ............ 2900 ~~-~L~_~.:~. 2000 ............ ... 2BO0 '"""-..,,....,... A I 120 .............. .2.700 I 1900 120 .............. 2.600 '"-.. , ",-'~ t' ~ """(~I 1800f / Z -*- ............ ... 2500 ® ................ .2.?.0 . !;o6'~'' ._.,'- .......... .2..a? o ~'6oc~ [- ... 2200 ~;-,Z/~O~ I c' 40 ........... 2100 .,_ ./rq uu 40 T ........ __2.o00 -~' o '";"~'°--°-..~15oo Z o 120 160 200 o e ........... e 14oo 2000/" / 2100/' / 2200 / .~-~-!4~0~ / / 2300.," 140.0. ......... 7': ............ ' ~5o9. ......... ,,' 1600 ......... / 2400 120 160 800 760 720 OS[) 640 600 560 520 480 440 400 360 32(] 280 240 200 160 120 B0 40 0 40 B0 <- West (feet) 320 I ~ 280 -I-- 240 O 200 Z Cr¢otcd by finch For: T McKAY Dote plotted : 27-0ct-97 Plot Refcrencm is WS ID-119/F4 Vers.~3. Coordinotes ~:re in fee[ reference slot ~11g. Structure : Pod 1D Well : F4 [ Field : Kuporuk River Unit Locotion : North Slope, Aloskot West (feet) 1400 1360 1320 1280 1240 1200 1160 1120 1080 1040 1000 960 920 880 840 800 760 720 680 640 600 560 520 520 f I I I I I I I I I ~ I I I I I I I I J I I I ~ t I I I I t I I t I I I I I I I I I .. ~ .520 480 '-,.. -.. --, 1600 480 440 """"""'"' 440 -, -, -, -,, "-,.. 15( 400 '~, 400 360 360 320 ~- 4200 3400 ~ ......... 4100 ...... ....4.000 ~ ....... ..._~900 280 ~ ......... 3800 3200~ ......... 3700 ........... ~ ~ 00~'~"'~ ...... .,...3500 240 ~ .......... .3.400 3~ ......... _~poo ~ ........... .~200 2600 2500 .~ <~ 200 2900 2800 2700 ............... .31 O0 1 $o ................ 3.000 ............. 2900 160 120 190 80 80 4O 40 0 0 ........ 1 ...... I ....... l ......... l ......... 1 ....... 1 ...... 1 ....... 1 ........ T----"T--'--r-----'-T ........ T ..... ! ....... [ ...... l ....... ~ -F---- ¥--~~------1 ..... i ...... 1 ...... I r-----i'---F ---' ] l .... l- 1' l----1 ...... ] ..... T'-'-'7 .... [ .... l .... T .......... I ......... T ........ ! ....... ! ....... 1400 1,360 1320 1'2B0 1240 1200 1160 1120 IOEJO 1040 lOOO 960 920 880 840 800 760 720 680 640 600 .560 520 <- West (feet) z ARCO ALASKA, Inc. Pad 1D F4 slot #119 Kuparuk River Unit North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE REPORT by Baker Hughes INTEQ Your ref : WS 1D-119/F4 Vets.#3 Our ref : prop2207 License : Date printed : 27-0ct-97 Date created : 17-Apr-97 Last revised : 6-0ct-97 Field is centred on nT0 16 18.576,w150 5 56.536 Structure is centred on n70 18 1.316,w149 30 18.908 Slot location is nT0 17 59.831,w149 30 36.341 Slot Grid coordinates are N 5959513.689, E 560490.188 Slot local coordinates are 151.00 S 598.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath PGMS <0-8365'>,,1,Pad 1D TOTCO Survey,,WS-8,Pad 1D PGMS <0-8930'>,,5,Pad 1D PGMS <0-7502'>,,4,Pad 1D PGMS <0-8070'>,,3,Pad 1D PGMS <0-9783'>,,2,Pad 1D PGMS <0-8610'>,,6,Pad 1D MSS <3311-8200'>,,7,Pad 1D WS 1D-120/F6 Vets. #3,,F6,Pad 1D WS 1D-105/C7 Version #4,,CT,Pad 1D WS 1D-106/D6 Vers.#3,,D6,Pad 1D WS 1D-109/D4 Vets. #2,,D4,Pad 1D WS 1D-115/E3 Version #4,,E3,Pad 1D WS 1D-117/E7 Version #4,,ET,Pad 1D WS 1D-118/E5 Version #4,,E5,Pad 1D WS 1D-124/G3 Version #3,,G3,Pad 1D WS 1D-129/J3 Version #3,,J3,Pad 1D WS 1D-130/H4 Version #4,,H4,Pad 1D WS 1D-133/J5 Version #4,,J5,Pad 1D WS 1D-135/G7 Version #4,,G7,Pad 1D WS 1D-121/G5 Version #3,,GS,Pad 1D Closest approach with 3-D Minimum Distance method Last revised Distance 4-Aug-92 387.5 16-0ct-96 4 -Aug- 92 4 -Aug- 92 4 -Aug- 92 4 -Aug- 92 25-0ct-97 25-0ct-97 6-0ct-97 22 -Oct- 97 8-0ct-97 8-0ct-97 22-0ct-97 22-0ct-97 22-Oct-97 22-0ct-97 22-0ct-97 27-Oct-97 22-0ct-97 22-0ct-97 23-0ct-97 446 1 89 4 27 2 148 0 267 8 212 0 332 0 14 9 285.0 255.0 210.0 90.0 60.0 45.0 120.0 240.0 255.0 300.0 375.0 30.0 M.D. Diverging from M.D. 1000.0 1000.0 1300.0 1300.0 1040.0 1040.0 740.0 740.0 20.0 2620.0 420.0 420.0 20.0 680.0 460.0 460.0 1080.0 1080.0 380.0 380.0 1000.0 1000.0 380.0 380.0 280.0 4515.8 380.0 380.0 1240.0 1240.0 900.0 900.0 300.0 300.0 600.0 600.0 280.0 280.0 780.0 780.0 1400.0 1400.0 West Sak-- r)-119 (F4) Monobore . ,jector Well Proposed Completion Diagram Tapered Monobore Injector Isolate Injection Thief Zones Using Patches 3-1/2" Tubing 9.3# L-80 8RD EUE (tied back to surface from Seal Bore/PBR) 16" Conductor Casing @ 80' Weatherford Gemoco 754HO 5-1/2" DV Stage Collar Stnd. Grade BTC Threads (set +/J~(~ ~flv ~r~frost) ~,~ov 2 ~ i99~' Alaska 011 & ,3as Cons, Commission Anchorage 5-1/2" Combination Surface/Production Casing 15.5# L-80 BTC (Cemented to Surface) Baker Seal Bore Extension - 12' Size 80-40 with 80-40 bottom sub to 3-1/2" tbg and 80-40 top sub, 5-1/2" to 3-1/2" (ASN 461-3435) (positioned +/- 100' above perfs) XO From 5-1/2" Casing to 3-1/2" Casing D Sands B Sands A Sands 3-1/2" Tapered Casing/Tubing 9.3# L-80 8RD EUE (Cemented to Surface) ARCO Alaska, Inc. TAB, 11/20/97, Rev.1 KUPARUK Ri-?ER UNIT - WEST SA~ OPERATIONS 20" DIVERTER SCHEMATIC 3 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. MAINTENANCE & OPERATI(~N 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. TWM, 9/15,/97 8 7 6 13 5/8" 5000 PS1 BOP STACK West Sak Operations - Injector Wells ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2_ ASSURE THAT 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 LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. 1. 5 BOP STACK TEST 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. 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 LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TESTAS 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 BO3-FOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSt AND 3000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 3 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES 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 TO3000 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 DOPE DAILY. VBRS WILL ACCOMODATE 3-1/2" TO 6" OR 4-1/2" TO 7" PIPE ODS AS APPROPRIATE. 1. 16" - STARTING HEAD 2_ 7-1/16" - 5000 PSI TUBING HEAD 3. 7-1/16" - 5000 PSI X 13-5/8" - 5000 PSI DOUBLE STUDDED ADAPTER/SPACER SPOOL 4. 13-5/8" 5000 PSI X 13-5/8" 5000 PSI SPACER SPOOL 5. 13-5/8" - 5000 PSI PIPE RAMS 6. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 7. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 8. 1 3-5/8" - 5000 PSI ANNULAR TWM, 9/18/97 , : ~ ,~,-~ ~- ,~-- I ~ ~ 14.1~ O~ ~ , ,,~ ~ ~CINITY MAP ~ e 117 , ; ~ SCALE: 1" = I MILE 119 i 120 121 i ~ 1~4 i ~ ~ 8 i LEGEND s[E SHE~ , 2 fOR NOTES ~D LO~TION INFOR~TION o gx/sn~ co~oucro~s ~ LOUNSBURY · NEW CONOUCrO~ LOC~ nON ~EA' lO ~ULE XX UNIT' Ol ~ DRILL SI~ 1-g ARCO Alaska, Inc. ~r ~ST SAK PHASE I - ~CONDUCTORS AS-BUILT LK610410 9/02/97 CEA-D1DX-610~IO 1 ~ 2 2 1. COORDINATES SHOWN ARE A.S.P. ZONE 4, N.A.D. 2Z ~LEVA TIONS SHOWN ARE BRITISH PETROLEUM MEAN ZEA LEVEL. ALL DISTANCES SHOWN ARE TRUE. 2. BASIS OF LOCATIONS AND ELEVATIONS ARE D.S. I-D 4,10NUMENTS PER LHD AND ASSOCIATES. .7. CONDUCTORS ARE LOCA TED WITHIN PROTRACTED SECTTONS ~,¢ & 2J, TOWNSHIP 11 NORTH, RANGE 10 EAST, U.M. 4. DA TE OF SURVEYS: 8/25, 29 & 30/97, FIELD BK L97-24, pp. 32 - 45, 68 - 73. 5. DRILL SITE I-0 GRID NORTH IS ROTA TED 00' 01' 05" i~EST FROM A.S.P. ZONE 4 GRID NORTH. 6. SEE DRA WING NSK-.7. 5-1 FOR A S- BUlL T L OCA TIONS OF CONDUCTORS /1tl THROUGH ~8. 9ESCRIPTION AS-BUILT PER KSBI Kg7082ACS D.S.1B WEST SAK- 1 77-115 SURVEY VIC/N/TY MAP SCALE: 1" = I MILE We// A. S.P. s LA TI TUDE LONGITUDE SEC., ,,,,- , ,,,~-SEC' PAD O.G. No. 'Y' 'x' ~7~ ~ ELEV.ELEV. S,;c. 14, T. 11 N., R. IO E. F.S.L.F.E.L. 105 5,959,798.99 560,490.57 70' 18' 02.6.57' 149' ,,ID' `56.26`5' I`54' 595' 70.5' 62.0': 106 5,959,768.9`5 560,490.67 70' 18' 02. J41" 149' .50' .56.268" 104' 595' 70,4' 62.$" 109 5,959,72,7.89 560,490.60 70' 18' 01.898' 149' `50' 36.280" 59' 596' 70,4' 62.7'! S,=.c. 23, T. 11 N., R. I O E. F.N.L. F.E.L. 115 5,959,60`5.9.5 560,490,68 70' 18' .00.718' 149' .50' 36.306' 61' 597' 70.4' 63.4'I 117 5,959,575.95 560,490.65 70' 18' 00.423' I49' .50' .56.314' 91' 597' 70,4' 624° 118 5,959,558.95 560,490.68 70' 18' 00.276' 149' .50' 36.$16" 106' 597' 70.4' 6,~4' 119 5,959,513.86 560,490.72 70' 17' 59.8`52' 149' .50' 36.$26' 15I' 598' 70.6' 66.0' 120 5,959,499.0I 560,490.77 70' 17' 59.686" 149' 30' 36.`527' 166' 598' 70.6' 66.0' 121 5,959,483.89 560,490.67 70' 17' 59,5`58' I49' `50' .56.335' 18I' 598' 70.5' 66.0 124 5,959,395.96 560,490.70 70' 17' 58.65`5' I49' `50' 36.355' 271' 599' 70.3' 65.0' 129 5,959,273.92 560,490.79 70' 17' 57.472' 149' `50' `56.380' `591' 600' 70.$' 68.2' 150 5,959,259.09 560,490.81 70' 17' 57.`526' 149' .50' 36.385' 406' 600' 70,5' 68.2' 1`5`5 5,959,21`5.89 560,490.68 70' I7' 56.882' 149' .50' 36..597' 451' 600' 70.4' 69.0' 135 5,959,1.59.02 560,490.80 70' 17' 56.146' 149' .50' 36.412' 526' 601' 70.5' 69,4' SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT i AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLA T REPRESENTS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF AUGUST 30, 1997. ARCO Alaska, inc. LK610410 9,/02,/07 LOUNSBURY & ASSOCIATES, INC. E,~NEERS PLANNERS SURVEYORS AREA' lO MODULE' XX DRILL SITE 1-D WEST SAK PHASE ! - WEM_ CONDUCTORS AS-BUILT CEA-D1DX-6104D10 ISHEET:2 O{ 2 IRE:v: UNIT' D1 ARCO Alaska, Inc. Kuparuk Drillsite Development Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 265-6206 Michael Zanghi Supervisor November 20, 1997 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill West Sak 1D-119 (F4) West Sak Phase lA Development Well, Kuparuk River Unit Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore development well to the West Sak interval from 1D pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and develop the production potential of the West Sak sands in the vicinity of 1D pad. The well is designed as a monobore injection well using a 5-1/2" x 3-1/2" tapered casing string, with 3-1/2" tubing used as a tieback string. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottomhole locations proposed for the well per 20 AAC 25.005 (c) (2). Note the 40 acre spacing requirements governed by the West Sak pool rules. 4) Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. 5) Diagrams and descriptions of the BOP and diverter equipment to be used as required by 20 AAC 25.035 (a) (1) and (b). Note that due to the pressures expected in the West Sak sands, ARCO proposes to test the 5000 psi BOP equipment to a maximum of 3000 psi, pending AOGCC approval per this letter and APD. Please note that due to the large number of KRU wells which have penetrated the West Sak sands in this area, ARCO has a clear understanding of the formation pressures to be encountered. As a result, no overpressured strata is expected in this area. There are also no shallow hazards expected at WS 1D- 119 (F4), such as shallow gas. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany There have been eight (8) Kuparuk wells and several West Sak wells drilled from KRU 1D pad and no occurrences of shallow gas or other hazards have been observed. There is a gas sand at approximately 2,100' TVD which is present, but has not caused any past problems in the existing wells which penetrated this sand using a diverter system only. An excePtion to the requirements set out by 20 AAC 25.033 (e) and 25.061 (a) are hereby requested for this APD because of this regional experience. A prediction of the maximum downhole and surface pressures which may be encountered however are included in this APD per 20 AAC 25.035 (d) (2). 6) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well and completion design. 7) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. 8) A copy of the proposed drilling program, including a request for approval of annular pumping operations is attached. 9) Also note that ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S monitoring equipment functioning on the rigs as is the standard operating procedure in the Kuparuk River Unit drilling operation. 10) Please note that because of the large volume of regional information available in this area, ARCO considers this well to be a development well, and as such, no mudlogging operations such as type log generation and sample catching are planned. An exception to the requirements detailed in 20 AAC 25.005 (c) (8) is thus requested. Please note that the anticipated spud date for this well is December 11, 1997. If you have any questions or require further information, please contact Tom Brockway at (907) 263-4135 or Tom McKay at (907) 265-6890. ,///- ' /,/ Si ncef. e:lV, ,/:/ Thomas ^. Brockwag Operations Drillin~ Attachments CC: West Sak 1D-119 (F4) Well File Tom McKay ATO-1202 Keith Lynch ATO-1228 Ike Bellaci ATO-1260 Cliff Crabtree NSK-6 RECEIVED 40V 21 Gas C0ns~ C0mmissi0~. Anchorage · FIELD & POOL WELL PERMIT CHECKLIST COMPANY ADMINISTRATION .~ DATE 'ENGINEERING APPR DAT~ ,, GEOLOGY WELL NAME ,/~,'k~,/' /,~ -/,,2 ¢ GEOL AREA 1. Permit fee attached ....................... N 2. Lease number appropriate ................... N 3. Unique well name and number .................. N 4. Well located in a defined pool .................. N 5. Well located proper distance from drilling unit boundary .... N 6. Well located proper distance from other wells .......... N 7. Sufficient acreage available in drilling unit ............ N 8. If deviated, is wellbore plat included ............... N 9. Operator only affected party ................... N 10. Operator has appropriate bond in force ............. N 11. Permit can be issued without conservation order ........ N 12. Permit can be issued without administrative approval ...... N 13. Can permit be approved before 15-day wait ........... N Conductor string provided ................... ~N Surface casing protects all known USDWs ........... N CMT vol adequate to circulate on conductor & surf csg ..... ~ ~ N CMT vol adequate to tie-in long string to surf csg ........ CMT will cover all known productive horizons. ~ N Casing designs adequate for C, T, B & permafrost ....... Adequate tankage or reserve pit ................. If a re-drill, has a 10-403 for abandonment been approved.. Adequate wellbore separation proposed ............. (.,,.'~ N If diverter required, does it meet regulations .......... ~iN Drilling fluid program schematic & equip list adequate ..... N BOPEs, do they meet regulation ................ N BOPE press rating appropriate; test to "~~ psig. Choke manifold complies w/APl RP-53 (~a~ 84) ........ Work will occur without operation shutdown ........... (~,N~ Is presence of H2S gas probable ................. Y~ 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. PROGRAM: exp [] dev [] redrll [] serv"~wellbore seg E; ann. disposal para req [] UNIT# _//'/~"~"~ ON/OFF SHORE 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones ............. 33. Seabed condition survey (if off-shore) ............. /Y N 34. Contact name/phone for we,ekly,prog, ress repo, rts ..... .~ Y N lexp~ora~ory omyj REMARKS GEOLOGY: ENGINEERING: COMMISSION: CO (.5) Comments/instructions: HOW/Ijt- A:\FORMS\cheklist rev 09~97 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. ,/Q7 -¿¡~ Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe 1 Use: ConocoPhillips Alaska, Inc. July 28,2005 8010 1 3.5" 9.3Ib. L-80 Tubing & Liner Well: 1D-119 Field: Kuparuk State: Alaska API No.: 50-029-22836-00 Top Log IntvI1.: 150' Bot. Log IntvI1.: 3,870 Ft. (MD) Inspection Type : Co"osive & Mechanical Damage Inspection COMMENTS: This caliper data is tied into the W-1 Nipple @ 3,736' (Driller's Depth). This log was run to assess the condition of the 3.5" tubing and liner with respect to corrosive and mechanical damages. The condition of the 3.5" tubing and liner ranges from good to poor with respect to corrosive damage, with a maximum wall penetration of 49% in joint 101 (3,164'), excluding the perforations. The deeper penetrations are recorded in the interval between joints 55 and 121 (1,700' - 3,870'). Wall penetrations ranging from 20% to 49% are recorded in 69 of the 120 joints logged. The damage appears in the forms of isolated pitting and lines of pits. No significant areas of cross-sectional wall loss or ID restrictions are recorded throughout the tubing and liner logged. Cross-sectional drawings of the most significant events recorded are included in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. The numbering of the joints is approximated, based on average joint length. During the logging operations the tool closed early resulting in no available data for the top 150' of the 3.5" tubing. MAXIMUM RECORDED WAll PENETRATIONS: Line of Pits Line of Pits Line of Pits Line of Pits Line of Pits ( 49%) ( 48%) ( 48%) ( 46%) ( 46%) Jt. Jt. Jt. Jt. Jt. 101 @ 118 @ 120 @ 77 @ 78 @ 3,164 Ft. (MD) 3,707 Ft. (MD) 3,808 Ft. (MD) 2,417 Ft. (MD) 2,449 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL lOSS: No significant areas of cross-sectional wall loss (> 6%) are recorded. MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded. SCJ~~JNE[) 14UG ~i 1 2005 I Field Engineer: N.Kesseru Analyst: M. Tahtouh Witness: C. Fitzpatrick I ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Pllone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudtloe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 ck3s, Well: Field: Company: Country: 10·119 Kaparuk ConocoPhillips (Alaska), Inc. USA I Tubing: Weight 9.3 ppf Grade & TIuead L-80 Nom.OD 3.5 ins Penetration and Metal Loss (% wall) _ penetration body 150 filii! metal loss body 100 ILL 50 0 o to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% Number of joints analysed (total = 120) pene. 0 5 46 58 11 loss 5 115 0 0 0 o o Damage Configuration ( body) 80 60 40 20 o isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole Number of joints damaged (total = 107) 37 8 62 0 0 PDS Report Overview Body Region Analysis Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: Nom.ID 2.992 ins July 28, 2005 MFC 24 No. 00387 1.69 24 M. Tahtouh Upper len. 1.2 ins Lower len. 1.2 ins Nom. Upset 3.5 ins Damage Profile (% wall) _ penetration body o 6. == ,E=" ª ~ 'iiæ" æ- 56~{ II ~ metal loss body 50 100 I t .:...- .;. r- I, I.: L 106 _ GlM 1 ~ L .I... Bottom of Survey = 121 Analysis Overview page 2 ~. PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 Well: 10-119 Body Wall: 0.254 in Field: Kaparu k Upset Wall: 0.254 in Company: ConocoPhillips (Alaska), Inc. Nominal 1.0.: 2.992 in Country: USA Survey Date: July 28,2005 Joint Jt. Depth I:>('n. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body 0/0 Loss 1.0. Comments (% wall) (Ins.) (Ins.) (j';) (Ins.) 0 50 100 6 168 0 0.04 17 2 2.92 Shallow corrosion. 7 200 0 0.05 18 2 2.89 Shallow corrosion. 8 231 0 0.03 13 ~) 2.93 Shallow pitting. 9 263 n 0.03 13 1 2.93 Shallow pitting. Lt. Deposits. 10 294 0 0.03 13 2 2.91 Shallow pitting. 11 326 0 0.04 15 .1 2.92 Shallow pitting. Lt. Deposits. 12 357 0 0.03 13 .1 2.92 Shallow pitting. 13 388 0 0.03 10 2 2.90 14 420 0 0.03 10 2 2.93 15 451 0 0.03 11 2 2.92 16 482 0 0.03 13 2 2.93 Shallow corrosion. 17 513 0 0.05 19 3 2.91 Shallow corrosion. Lt. Deposits. 18 543 n 0.03 13 2 2.92 Shallow pitting. 19 574 0 0.04 14 .1 2.90 Shallow pitting. 20 605 0 0.03 12 2 2.91 21 637 0 0.05 19 :3 2.90 Shallow pitting. 22 668 () 0.03 10 2 2.90 23 700 0 0.04 14 2 2.93 Shallow pitting. 24 731 0 0.03 11 1 2.91 25 763 0 0.03 11 1 2.91 26 794 0 0.03 13 :3 2.92 Shallow pitting. 27 826 () 0.04 15 4 2.92 Shallow pitting. 28 857 0 0.03 11 2 2.93 29 889 0 0.04 18 2 2.92 Shallow pitting. 30 920 0 0.03 13 2 2.89 Shallow pitting. 31 950 0 0.03 11 2 2.93 32 982 0 0.02 9 3 2.92 33 1013 0 0.04 14 :3 2.92 Shallow pitting. 34 1045 0 0.05 20 2 2.90 Shallow pitting. 35 1076 0 0.04 14 2 2.92 Shallow pitting. 36 1108 0 0.04 14 1 2.91 Shallow corrosion. 37 1139 0 0.04 15 1 2.91 Shallow pitting. 38 1169 0 0.03 13 2 2.91 Shallow pitting. 39 1200 0 0.03 11 6 2.92 40 1232 0 0.03 11 2 2.91 41 1263 0 0.04 14 :3 2.91 Shallow pitting. Lt. Deposits. 42 1294 0 0.04 16 3 2.92 Shallow corrosion. 43 1324 0 0.03 13 :3 2.90 Shallow pitting. 44 1355 0 0.03 13 2 2.91 Shallow pitting. 45 1386 0 0.04 16 2 2.91 Shallow pitting. 46 1418 () 0.04 14 2 2.93 Shallow pitting. 47 1449 () 0.04 16 2 2.89 Shallow pitting. 48 1481 0 0.04 16 2 2.91 Shal.low pitting. 49 1512 0 0.03 13 2 2.89 Shallow corrosion. Lt. Deposits. 50 1543 0 0.04 15 :3 2.89 Shallow pitting. 51 1575 0 0.05 18 2 2.90 Shallow pitting. 52 1607 0 0.05 20 4 2.92 Isolated pitting. 53 1638 0 0.06 23 3 2.91 Isolated pitting. 54 1670 0 0.04 17 2 2.92 Shallow corrosion. 55 1701 0 0.09 35 6 2.91 Isolated pitting. I Penetration Body Metal Loss Body Page 1 ( ;;t PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 Well: 10-119 Body Wall: 0.254 in Field: Kaparu k Upset Wall: 0.254 in Company: ConocoPhillips (Alaska), Inc. Nominal 1.0.: 2.992 in Country: USA Survey Date: July 28, 2005 Joint Jt. Depth [>en. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins. ) (Ins.) <Yo (Ins.) 0 50 100 56 1732 0 0.08 32 4 2.92 Isolated pitting. 57 1763 0 0.08 33 4 2.92 Isolated pitting. 58 1795 0 0.07 29 4 2.93 Isolated pitting. 59 1826 0 0.08 33 6 2.92 Isolated pitting. 60 1858 0 0.09 35 3 2.91 Isolated pitting. 61 1889 () 0.08 30 2 2.91 Line of pits. 62 1921 0 0.10 39 2 2.90 Line of pits. 63 1952 0 0.10 39 :3 2.92 Line of pits. 64 1982 0 0.10 39 2 2.92 Line of pits. Lt. Deposits. 65 2014 0 0.08 30 5 2.92 Line of pits. 66 2045 0 0.07 28 4 2.93 Line of pits. 67 2077 0 0.09 35 3 2.91 Line of pits. Lt. Deposits. 68 2108 0 0.06 24 :3 2.93 Line of pits. 69 2140 0 0.08 30 3 2.92 Line of pits. Lt. Deposits. 70 2172 0 0.08 32 2 2.93 Line of pits. 71 2203 0 0.09 35 4 2.91 Line of pits. Lt. Deposits. 72 2233 0 0.08 31 :3 2.93 Line of pits. 73 2264 0 0.10 39 5 2.92 Line of pits. 74 2295 0 0.09 34 3 2.92 Line of pits. 75 2327 0 0.09 35 :3 2.93 Line of pits. 76 2358 0 0.08 33 6 2.91 Line of pits. Lt. Deposits. 77 2388 0 0.12 46 2 2.90 Line of pits. 78 2418 0 0.12 46 3 2.93 Line of pits. 79 2450 0 0.11 43 3 2.92 Line of pits. 80 2481 0 0.10 41 . 2 2.93 Line of pits. 81 2513 0 0.09 35 4 2.90 Line of pits. 82 2544 0 0.07 30 2 2.91 Line of pits. 83 2574 0 0.08 31 2 2.90 Line of pits. 84 2606 0 0.09 37 4 2.92 Line of pits. 85 2637 0 0.10 39 2 2.92 Line of pits. 86 2669 0 0.08 31 :3 2.92 Line of pits. 87 2700 0 0.08 31 3 2.92 Line of pits. 88 2732 0 0.08 31 3 2.94 Line of pits. Lt. Deposits. 89 2763 0 0.08 30 J 2.93 Line of pits. Lt. Deposits. 90 2793 0 0.08 32 4 2.91 Line of pits. 91 2825 0 0.09 34 4 2.91 Line of pits.. 92 2856 0 0.11 42 :3 2.92 Line of pits. 93 2887 0 0.09 35 4 2.92 Line of pits. 94 2919 0 0.10 38 :3 2.93 Line of pits. 95 2950 0 0.10 39 4 2.91 Line of pits. Lt. Deposits. 96 2982 () 0.08 31 :3 2.90 Line of pits. Lt. Deposits. 97 3013 0 0.10 39 :3 2.91 Line of pits. 98 3045 0 0.09 37 3 2.92 Line of pits. Lt. Deposits. 99 3076 0 0.11 42 4 2.92 Line of pits. Lt. Deposits. 100 3108 0 0.08 30 2 2.92 Line of pits. Lt. Deposits. 101 3139 0 0.12 49 4 2.92 Line of pits. 102 3170 0 0.09 35 3 2.93 Line of pits. 103 3202 0 0.10 40 :3 2.89 Line of pits. 104 3233 0 0.10 38 3 2.92 Line of pits. Lt. Deposits. 105 3265 0 0.09 35 :3 2.92 Line of pits. I Penetration Body Metal Loss Body Page 2 I" ~ PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf l-80 Well: 10-119 Body Wall: 0.254 in Field: Kaparu k Upset Wall: 0.254 in Company: ConocoPhillips (Alaska), Inc. Nominal 1.0.: 2.992 in Country: USA Survey Date: July 28, 2005 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body 0/0 Loss 1.0. Comments (% wall) (Ins.) (Ins.) ()' (Ins.) 0 50 100 10 106 3296 0 0.06 23 ') 2.91 Line of pits. .) 107 3326 () 0.08 33 :3 2.91 Line of pits. 108 3357 () 0.08 30 2 2.93 Line of pits. 109 3389 () 0.09 35 .1 2.90 line of pits. It. Deposits. 110 3420 0 0.09 36 :3 2.92 Line of pits. 111 3452 () 0.08 30 2 2.92 Line of pits. 112 3483 0 0.07 29 :-\ 2.91 Line of pits. It. Deposits. 113 3515 0 0.07 29 :3 2.92 Line of pits. 114 3546 () 0.07 28 2 2.91 Line of pits. 115 3576 0 0.08 33 :3 2.91 Line of pits. 116 3607 0 0.07 29 3 2.92 Line of pits It. Deposits. 117 3639 0 0.09 36 4 2.92 Line of pits. 117.1 3670 0 0.05 20 :3 2.92 PUP Line of pits. 117.2 3685 0 0 0 0 N/A GlM (latch @ 3:00) 117.3 3693 0 0.05 19 2 2.92 PUP Line of shallow pits. 118 3706 0 0.12 48 3 2.91 Line of pits. 118.1 3736 0 0 0 0 2.81 W-1 Nipple 119 3738 0 0.11 42 4 2.94 Line of pits. 119.1 3770 0 0.03 10 1 2.94 PUP 119.2 3776 () 0 0 0 N/A Seal Assembly 119.3 3788 0 0 0 0 N/A HANGER Ll DepOSi~ 119.4 3798 0 0.06 25 1 2.91 PUP Line of pits. 120 3808 0 0.12 48 3 2.93 Line of pits 121 3838 0 0.19 74 5 2.92 Perforation Interval, Isolated pitting. IPenetration Body ,)I\Jd Metal Loss Body Page 3 · ---~LS ~ ø· PDS Report Cross Sections Well: Field: Company: Country: Tubing: 1 0-11 9 Kaparuk ConocoPhillips (Alaska), Inc. USA 3.5 ins 9.3 ppf L-80 Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst July 28, 2005 MFC 24 No. 00387 1.69 24 M. Tahtouh Cross Section for Joint 101 at depth 3163.61 ft Tool speed = 52 Nominal 10 = 2.992 Nominal 00 = 3.500 Remaining wall area = 96 % Tool deviation = 31 0 Finger 2 Penetration = 0.124 ins Line of Pits 0.12 ins = 49% Wall Penetration HIGH SIDE = UP Cross Sections page 1 ~s~ PDS Report Cross Sections Well: Field: Company: Coun try: Tubing: 1 0-11 9 Kaparu k ConocoPhillips (Alaska), Inc. USA 3.5 ins 9.3 ppf L-80 Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: July 28,2005 MFC 24 No. 00387 1.69 24 M. Tahtouh Cross Section for Joint 118 at depth 3707.01 ft Tool speed = 50 Nominal 10 = 2.992 Nominal 00 = 3.500 Remaining wall area = 98 % Tool deviation = 22 0 Finger 24 Penetration = 0.122 ins Line of Pits 0.12 ins = 48% Wall Penetration HIGH SIDE = UP Cross Sections page 2 TUBING (CÞ3m, 00:3.500, 10:2.438) =>ROOUCTlON (0-3777, 00:5.500, Wt15.50) NIP (3736-3737, 00:3.500) SEAL (3776-3778, 00:4.000) Perf (3856-3892) LINER (3777-4500, 00:3.500, Wt9.30) Perf (3922-3960) Perf (397CÞ3980) Perf (3980-4000) Perf (4008-4022) Perf (4032-4048) Perf (4048-4068) Perf (4087-4097) Perf (4107-4145) Perf (4170-4180) \ ConocoPhillips Alaska, Inc. 10-119 KRU Well Type: INJ Orig Completion: 12/1611997 Last W/O: Ref Log Date: TD: 4515 ftKB Max Hole Angle: 31 deg @ 2529 API: 500292283600 SSSV Type: NONE Annular Fluid: clsl/3% KCI Reference Log: Last Tag: 3842' Tar Last Tag Date: 411012005 Casina String - ALL STRINGS Description Size CONDUCTOR 16.000 PRODUCTION 5.500 UNER 3.500 Tubing String - TUBING Size I Top 3.500 0 Perforations Summary Interval TVD ~6-~ ~9-æ73 1 D-119 Angle (à) TS: deg (iiJ Angle @ TO: 18 deg (à) 4515 Rev Reason: Tagged Tar Last Update: 4115/2005 Top Bottom TVD Wt Grade Thread 0 121 121 62.58 H-40 Welded 0 3Tl7 3565 15.50 L-80 MBTC 3777 4500 4247 9.30 L-80 EUE TVD Wt Grade Thread 3565 9.30 L-80 ABM-EUE Bottom 3Tl7 Zone WSD 3922 - 3960 3701 - 3737 WSB 3970 - 3980 3746 - 3755 WSM 3980 - 4000 3755 - 3Tl4 WSM 4008 - 4022 3782 - 3795 WSA3 4032 - 4048 3804 - 3819 WSA3 4048 - 4068 3819 - 3838 WSA3 4087 - 4097 ~6 - 3866 WSA2 4107 - 4145 3875 - 3911 WSA2 4170 - 4180 3934 - 3944 WSA2 === Gas Lift MandrelsNalves ___ St MD TVD Man Mfr Man Type VMfr 1 3684 3478 BST ATX - Other (plugs, equip., etc.) - JEWELRY ---- Depth TVD Type 3736 3526 NIP 3Tl6 3564 SEAL 4500 4247 Shoe Status Ft SPF æ 4 38 4 10 4 20 4 14 4 16 4 20 4 10 4 38 4 10 4 Date 5/1/1998 5/1/1998 5/1/1998 4130/1998 IPERF 4130/1998 IPERF 4130/1998 IPERF 41811998 IPERF 4/811998 IPERF 4/811998 IPERF 417/1998 IPERF Type Comment IPERF 2.5" HC, DP, 180 deg phasing, 90 deg orient IPERF 2.5" He, DP, 180 deg phasing, 90 deg orient IPERF 2.5" HC, DP, 180 deg phasing, 90 deg orient 2.5" HC, DP, 180 deg phasing, 90 deg orient 2.5" HC, DP, 180 deg phasing, 90 deg orient 2.5" He, DP, 180 deg phasing, 90 deg orient 2.5" HC, DP, 180 deg phasing, 90 deg orient 2.5" HC, DP, 180 deg phasing, 90 deg orient 2.5" HC, DP, 180 deg phasing, 90 deg orient 2.5" HC, DP, 180 deg phasing, 90 deg orient V Type VOD latch Port TRO DMY 1.0 T-1 0.000 0 Description Cameo 'W-1' Selective Nipple Baker GBH-22 Locator Seal Assy Gemoco Date Run 12/16/1997 Vlv Cmnt ID 2.813 3.000 0.000 Sperry-Sun Drilling Services LIS Scan Utility Mon Jan 12 09:33:01 1998 Reel Header Service name ............. LISTPE Date ..................... 98/01/12 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Tape Header Service name ............. LISTPE Date ..................... 98/01/12 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: MWD RUN 1 AK-MM-80046 S. BURKHARDT D. BREEDEN ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 1D-119 500292283600 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 12-JAN-98 23 liN 10E 151 598 .00 111.60 70.60 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 4515.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 3. DEPTH SHIFT/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN M WENER OF ARCO ALASKA, INC. AND M MUNYAK OF SPERRY-SUN DRILLING SERVICES ON 01/07/98. 4. THIS WELL REACHED A TOTAL DEPTH (TD) OF 4515'MD, 4261'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/01/12 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FI LE SUMMARY PBU TOOL CODE START DEPTH FET 121.0 RPD 121.0 RPM 121.0 RPS 121.0 RPX 121.0 GR 121.0 ROP 121.0 $ STOP DEPTH 4478.5 4478.5 4478.5 4478.5 4478.5 4486.0 4515.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH ...... BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 121.0 4515.0 $ REMARKS: MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD AAPI 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max Mean Nsam DEPT 121 4515.5 2318.25 8790 ROP 21.5562 9574.8 273.578 8790 GR 7.1038 121.984 60.0949 8731 RPX 0.0932 2000 61.1629 8716 RPS 0.1205 2000 63.9723 8716 RPM 0.2813 2000 76.4632 8716 RPD 0.1672 2000 79.1304 8716 FET 0.0685 3.1719 0.293216 8716 First Reading 121 121 121 121 121 121 121 121 Last Reading 4515.5 4515.5 4486 4478.5 4478.5 4478.5 4478.5 4478.5 First Reading For 'Entire File .......... 121 Last Reading For Entire File ........... 4515.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/01/12 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/01/12 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 121.0 4478.5 RPD 121.0 4478.5 RPM 121.0 4478.5 RPS 121.0 4478.5 R?X 121.0 4478.5 GR 121.0 4486.0 ROP 121.0 4515.5 $ ~ LOG HEADER DATA DATE LOGGED: 13-DEC-97 SOFTWARE SURFACE SOFTWARE VERSION: ISC 5.06 DOWNHOLE SOFTWARE VERSION: CIM 5.46 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 4515.0 TOP LOG INTERVAL (FT): 121.0 BOTTOM LOG INTERVAL (FT): 4515.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMI/M~GLE: .5 MAXIMUM ANGLE: 30.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL 'CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY P0891CRG6 EWR4 ELECTROMAG. RESIS. 4 P0891CRG6 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 8.5 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMS4)AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ............... 2.Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 SPUD MUD 175.00 280.0 8.5 55O .0 4.500 3.400 3.000 5.000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 1 AAPI 4 1 68 4 2 RPX MWD 1 OH~4 4 1 68 8 3 RPS MWD 1 OH~M 4 1 68 12 4 RPM MWD 1 OHMM 4 1 68 16 5 RPD MWD 1 OHMM 4 1 68 20 6 ROP MWD 1 FT/H 4 1 68 24 7 FET MWD 1 HOUR 4 1 68 28 8 34.5 First Name Min Max Mean Nsam Reading DEPT 121 4515.5 2318.25 8790 121 GR 7.1038 121.984 60.0949 8731 121 RPX 0.0932 2000 6121629 8716 121 RPS 0.1205 2000 63.9723 8716 121 RPM 0.2813 2000 76.4632 8716 121 RPD 0.1672 2000 79.1304 8716 121 ROP 21.5562 9574.8 273.578 8790 121 FET 0.0685 3.1719 0.293216 8716 121 Last Reading 4515.5 4486 4478.5 4478.5 4478.5 4478.5 4515.5 4478.5 First Reading For Entire File .......... 121 Last Reading For Entire File ........... 4515.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/01/12 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/01/12 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 98/01/12 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File