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Home My WebLink About197-151C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\H2LGR515\2023-11-15_22136_KRU_1E-33_GR_GGL_Log_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22136 KRU 1E-33 50-029-22797-00 GR / CCL Log 15-Nov-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 197-151 T38135 11/21/2023 Kayla Junke Digitally signed by Kayla Junke Date: 2023.11.21 10:42:41 -09'00' C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\H2LGR515\2023-09-28_15948_KRU_1E-33_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 15948 KRU 1E-33 50-029-22797-00 Caliper Survey w/ Log Data 28-Sep-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 197-151 T38026 10/3/2023 Kayla Junke Digitally signed by Kayla Junke Date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y Samantha Carlisle at 1:37 pm, Aug 05, 2021 Stefan Weingarth Digitally signed by Stefan Weingarth Date: 2021.08.05 10:39:13 -08'00' RBDMS HEW 8/9/2021 DSR-8/6/21VTL 8/9/21 ! " #$ %& % % ' ( ! ') & *+ ,, -.. ! % ! "#$!& % & " % '( ') &&*+ / % ) &&*+ ,, +.. &"0* &!*+ / ) &"*1* 2 &"*0* ) &%*+ ) &!*+ 3 -- # + 3' % // " &+ + & 0 + 0 ) / ! ! / 3%3%% 45678 9::45; <=>?5487<@A Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: 10,884.0 9/14/1997 1E-33 WV5.3 Conversion Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Drift For E-Line 2/24/2021 1E-33 raineg Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 42.0 Set Depth (ftKB) 121.0 Set Depth (TVD) … 121.0 Wt/Len (l… 62.58 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.83 Top (ftKB) 41.1 Set Depth (ftKB) 5,480.9 Set Depth (TVD) … 3,998.9 Wt/Len (l… 40.00 Grade L-80 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 38.4 Set Depth (ftKB) 8,997.2 Set Depth (TVD) … 6,106.6 Wt/Len (l… 26.00 Grade L-80 Top Thread ABM-BTC Casing Description LINER OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 8,836.0 Set Depth (ftKB) 10,951.0 Set Depth (TVD) … Wt/Len (l… 12.60 Grade L-80 Top Thread NSCT Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 8,836.0 6,018.2 55.28 SLEEVE BAKER 5.5" C2 LINER SETTING SLEEVE ID 4.997" w/BAKER 80-47 SEAL OD 5.875"/ID 4.75" SEAL BORE EXTENSION 4.750 8,846.3 6,024.1 55.28 HANGER BAKER CMC MECHANICAL LINER HANGER 4.276 8,888.4 6,048.0 55.60 NIPPLE CAMCO DB LANDING NIPPLE w/ NO GO PROFILE 3.750 Tubing Strings Tubing Description TUBING - WO 2015 String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 36.6 Set Depth (ft… 8,806.0 Set Depth (TVD) (… 6,001.1 Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 36.6 36.6 0.00 HANGER FMC HANGER 4.500 7,158.9 5,022.6 53.18 LOCATOR LOCATOR SUB 3.950 7,159.8 5,023.1 53.18 SEAL ASSY BAKER 80-47 SEAL ASSEMBLY 3.870 7,166.8 5,027.3 53.20 PBR BAKER PBR 80-47 4.750 7,187.9 5,040.0 53.27 PACKER BAKER PREMIER PACKER 3.930 8,777.1 5,984.7 55.27 NIPPLE BAKER DB NIPPLE W/ (PULLED - RHC PLUG - on 10/7/2015) 3.813 8,792.2 5,993.3 55.27 LOCATOR LOCATOR SUB 3.870 8,794.0 5,994.3 55.27 SEAL ASSY BAKER 80-47 SEAL ASSEMBLY 3.870 Tubing Description TUBING - ORIGINAL String Ma… 5 1/2 ID (in) 3.88 Top (ftKB) 8,792.3 Set Depth (ft… 8,822.7 Set Depth (TVD) (… 6,010.7 Wt (lb/ft) Grade Top Connection Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 8,792.3 5,993.4 55.27 PBR BAKER PBR 3.875 8,805.8 6,001.0 55.28 SEAL ASSY BAKER GBH-22 ANCHOR SEAL ASSEMBLY 3.875 8,806.6 6,001.5 55.28 PACKER BAKER FAB-1 PACKER 3.958 8,809.8 6,003.3 55.28 BLAST JT BLAST JOINT 3.958 8,819.5 6,008.8 55.28 SEAL ASSY BAKER GBH-22 LOCATOR SEAL ASSEMBLY 3.875 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 9,270.0 9,330.0 6,203.8 6,216.5 C-4, 1E-33 9/14/2000 6.0 APERF TCP 3 3/8" HSD w/HJ2 charges; 60 deg ph 9,799.0 10,248.0 6,231.3 6,242.3 C-4, 1E-33 11/2/1997 4.0 IPERF TCP 2 7/8" HSD 10,299.0 10,650.0 6,243.2 6,258.4 C-4, 1E-33 11/2/1997 4.0 IPERF TCP 2 7/8" HSD 10,699.0 10,883.0 6,261.5 6,272.9 C-4, 1E-33 11/2/1997 4.0 IPERF TCP 2 7/8" HSD Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,644.6 2,278.9 53.11 CAMCO KBG2- 1R 1 GAS LIFT GLV BK 0.188 1,264.0 5/22/2020 2 4,475.5 3,389.1 52.55 CAMCO KBG2- 1R 1 GAS LIFT OV BK 0.250 0.0 5/22/2020 3 5,710.5 4,140.8 51.47 CAMCO KBG2- 1R 1 GAS LIFT DMY BEK-5 0.000 0.0 10/6/2015 DCK- 2 4 6,708.0 4,748.2 51.94 CAMCO KBG2- 1R 1 GAS LIFT DMY BK-5 0.000 0.0 9/27/2015 5 7,096.0 4,984.8 52.98 CAMCO KBG2- 1R 1 GAS LIFT DMY BK-5 0.000 0.0 9/27/2015 Notes: General & Safety End Date Annotation 9/8/2010 NOTE: View Schematic w/ Alaska Schematic9.0 1E-33, 8/4/2021 7:52:14 AM Vertical schematic (actual) LINER; 8,836.0-10,951.0 IPERF; 10,699.0-10,883.0 IPERF; 10,299.0-10,650.0 IPERF; 9,799.0-10,248.0 APERF; 9,270.0-9,330.0 PRODUCTION; 38.4-8,997.2 PACKER; 8,806.6 NIPPLE; 8,777.1 PACKER; 7,187.9 GAS LIFT; 7,096.0 GAS LIFT; 6,708.0 GAS LIFT; 5,710.5 SURFACE; 41.1-5,480.9 GAS LIFT; 4,475.5 GAS LIFT; 2,644.6 CONDUCTOR; 42.0-121.0 HANGER; 36.6 KUP PROD KB-Grd (ft) 44.81 Rig Release Date 9/15/1997 1E-33 ... TD Act Btm (ftKB) 10,951.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292279700 Wellbore Status PROD Max Angle & MD Incl (°) 91.51 MD (ftKB) 9,558.79 WELLNAME WELLBORE1E-33 Annotation Last WO: End Date 9/18/2015 H2S (ppm) 150 Date 12/16/2013 Comment SSSV: NONE 2Co420 WELL LOG TRANSMITTAL#902774021 DATA LOGGED %%/3/2015 M.K.BENDER To: Alaska Oil and Gas Conservation Comm. October 30, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED NOV 032015 RE: RCT and String Shot Record: 1E-33 AOGCC Run Date: 9/23/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1E-33 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-22797-00 SCANNED PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed. STATE OF ALASKA ` AAA OIL AND GAS CONSERVATION CO SION • REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing FoT Operations Shutdown r Performed: Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well Re-enter Susp Well r' Other: Stacked Packer I� 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development pr Exploratory r 197-151 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic " Service 50-029-22797-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25651,25650 KRU 1 E-33 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 10951 feet Plugs(measured) 8888' true vertical 6279 feet Junk(measured) none Effective Depth measured 10884 feet Packer(measured) 7188, 8807 true vertical 6272 feet (true vertical) 5040,6002 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 121 121 SURFACE 5440 9.625 5481 3999' PRODUCTION 8959 7 8997, 6207' LINER 2115 4.5 1098 NE f 6279 " W r ? i,)!.. 1 23 d, is"_i C Perforation depth: Measured depth: 9270-9330, 9799-10248, 10299-10650, 10699-10883 : . -; True Vertical Depth: 6204-6217,6231-6242, 6243-6258,6262-6273 Tubing(size,grade,MD,and TVD) 4.5, L-80, 8806 MD, 6001 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER PREMIER PACKER @ 7188 MD and 5040 TVD PACKER-BAKER FAB-1 PACKER @ 8807 MD and 6002 TVD NO SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this operation Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Fro Exploratory r Development Kr. Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-551 Contact Janelle Nesvold 263-4641 Email Janelle.R.Nesvold(a�conocophillips.com Printed Name Janelle Nesvold Title Senior Wells Engineer Signature -440-(-1-6_,_ ' 21-(- 1/A1' Phone:263-4641 Date ( D/2 (/` /5 V71- !o/2 /`f 6 z RBDMS 001'9-3 ?fl,5 3L Form 10-404 Revised 5/2015 Z/" Submit Original Only KUP PROD 1E-33 ConocoPhillips i Well Attributes Max Angle&MD TD Alaska,Ill Wellbore APIIUWI Field Name Wellbore Status Incl(°) MD(ftKB) Act Btm(ftKB) ,,,,...mo-„o„,„ ,? 500292279700 KUPARUK RIVER UNIT PROD 91.51 9,558.79 10,951.0 ••• - Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1E-33,10/2/201511'.33:56 AM SSSV:NONE 150 12/16/2013 Last WO: 9/18/2015 44.81 9/15/1997 Vertical schen-late(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Data HANGER;36.6 >•"-��yy�� Last Tag'. 10,884.0 9/14/1997 Rev Reason:WORKOVER smsmith 10/2/2015 , 7 Casing Strings Casing Description 00(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 42.0 121.0 121.0 62.58 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread r ( SURFACE 9 5/8 8.835 41.1 5,480.9 3,998.9 40.00 L-80 BTC U • I` Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread 1 PRODUCTION 7 6.276 38.4 8,997.2 6,106.6 26.00 L-80 ABM-BTC ' a w.Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread LINER 41/2 3.958 8,836.0 10,951.0 12.60 L-80 NSCT -.WCotioucroa 4s.o-lzl.o Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 8,836.0 6,018.2 55.28 SLEEVE BAKER 5.5"C2 LINER SETTING SLEEVE ID 4.997" 4.750 w/BAKER 80-47 SEAL OD 5.875"/ID 4.75"SEAL BORE EXTENSION 8,846.3 6,024.1 55.28 HANGER BAKER CMC MECHANICAL LINER HANGER 4.276 8,888.4 6,048.0 55.60 NIPPLE CAMCO DB LANDING NIPPLE w/NO GO PROFILE 3.750 GAS LIFT;2,644.6 -. Tubing Strings -- Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Iblfl) Grade Top Connection TUBING-WO 2015 I 4 1/21 3.9581 36.61 8 806.01 6,001.11 12.601 L-B0 1(BTM GAS LIFT;4,475.5 Completion Details i. Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Mel(°) Item Des Corn (in) 36.6 36.6 0.00 HANGER FMC HANGER 4.500 7,158.9 5,022.6 53.18 LOCATOR LOCATOR SUB 3.950 SURFACE;41.1-5,4E10.9 .- 7,159.8 5,023.1 53.18 SEAL ASSY BAKER 80-47 SEAL ASSEMBLY 3.870 7,166.8 5,027.3 53.20 PER BAKER PER 80-47 4.750 7,187.9 5,040.0 53.27 PACKER BAKER PREMIER PACKER 3.930 GAS LIFT;5,710.5-II 4 8,777.1 5,984.7 55.27 NIPPLE BAKER DB NIPPLE W/RHC PLUG 3.813 I 8,792.2 5,993.3 55.27 LOCATOR LOCATOR SUB 3.870 - 8,794.0 5,994.3 55.27 SEAL ASSY BAKER 80-47 SEAL ASSEMBLY 3.870 GAS LIFT;6,708.0 C L Tubing Description TUBING-ORIGINAL 'String Ma.1/2..'ID(in)3.878(Top(ftKB)8,792.3 8Set Depth(ft..1Sot Depth(TOO)6,010.7(...'Wt(lb/ft) (Grade 'Top Connection Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 8,792.3 5,993.4 55.27 PER BAKER PBR 3.875 8,805.8 6,001.0 55.28 SEAL ASSY BAKER GBH-22 ANCHOR SEAL ASSEMBLY 3.875 GAS LIFT;7,096.6 8,806.6 6,001.5 55.28 PACKER BAKER FAB-1 PACKER 3.958 8,809.8 6,003.3 55.28 BLAST JT BLAST JOINT 3.958 8,819.5 6,008.8 55.28 SEAL ASSY BAKER GBH-22 LOCATOR SEAL ASSEMBLY 3.875 • LOCATOR;7,158.9 PM Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) SEAL ASSY;7,159.8 Top(TVD) Top Incl PER;7,166.8 Top(ftKB) (ftKB) 7) Des Com Run Date ID(in) 1111 8,840.0 6,020.5 55.28 CATCHER 3.78"CATCHER(OAL=38") 9/16/2015 PACKER;7,187.9 8,888.4 6,048.0 55.60 PLUG 3.75"DBP PLUG W/PRONG •7/27/2015 I Perforations&Slots Shot Dens NIPPLE;8,777.1 Top(1V0) Btm(TVD) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Corn • LOCATOR;8,792.2 9,270.0 9,330.0 6,203.8 6,216.5 C-4,1 E-33 9/14/2000 6.0 APERF TCP 3 3/8"HSD w/HJ2 PER;8,792.3 ( charges;60 deg ph SEAL ROSY,0,704.0 9,799.0 10,248.0 6,231.3 6,242.3 C-4,1E-33 11/2/1997 4.0 IPERF TCP 2 7/8"HSD SEAL Asst;e,e05.9 10,299.0 10,650.0 6,243.2 6,258.4 C-4,1 E-33 11/2/1997 4.0 IPERF TCP 2 7/8"HSD PACKER;8,806.6 `- '; 10,699.0 10,883.0 6,261.5 6,272.9 C-4,1E-33 11/2/1997 4.0 IPERF TCP 2 7/8"HSO Mandrel Inserts SEAL ASSY;8,819.5 , St ati N Top(TVD) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Seen Type Type (in) (psi) Run Date Com • 1 2,644.6 2,278.9 CAMCO KBG2- 1 GAS LIFT DMY BK-5 0.000 0.0 9/27/2015 CATCHER;8,840.0 '\t I/11R it 2 4,475.5 3,389.1 CAMCO KBG2- 1 GAS LIFT DMY BK-5 0.000 0.0 9/27/2015 1R 3 5,710.5 4,140.5 CAMCO KBG2- 1 GAS LIFT SOV BEK-5 0.000 0.0 9/27/2015 DCK-2 1R PLUG;51,888.4j. 4 6,708.0 4,748.2 CAMCO KBG2- 1 GAS LIFT DMY BK-5 0.000 0.0 9/27/2015 1R 5 7,096.0 4,984.8 CAMCO KBG2- 1 GAS LIFT DMY BK-5 0.000 0.0 9/27/2015 1R Notes:General&Safety PRODUCTION;38.4-8,997.2- isEnd Dale Annotation _ 9/8/2010 NOTE:View Schematic w/Alaska Schematic9.0 APERF;9,270.0-9,330.0NOTE: (PERF;9,799.0-10,248.0 ti IPERF;10,299.0-10,650.0 (PERF;10,699.0-10,883.0 LINER;8,836.0-10,951.0 A • Durati Start End Sub Date From To on Depth Depth Phase Code Code Time Activity 9/18/2015 0:00 8:00 0:00 16 MIRE MOVE MOB P Move and stage Downey camp,pits and shop at DS-1E.Move and stage the sub base at the IC/KIC"v', 9/19/2015 0:00 0:00 12:00 12 MIRU MOVE MOB P Move and stage Rig at KCC.Lay mats on lE access road 9/19/2015 0:00 12:00 0:00 12 MIRU MOVE MOB P Continue laving mats on IE access road. 9/20/2015 0:00 0:00 17:00 17 MIRU MOVE MOB P Lay mats on 10 access road and move Rig over 1E-33. 9/20/2015 0:00 17:00 22:00 5 MIRU MOVE RURD P Rill antl ready Rig Co kill well.Taking on 9.9 ppg brine water at 22:00 hrs.Rig Accepted 77 nn hrs 4/70/15 9/20/2015 0:00 22:00 0:00 2 MIRE WELCT RURD P Continue R/U while take on brine in the pits. L ', AES rigging up Flow lines,choke house and kill'.. tank. 9/21/2015 0:00 0:00 2:30 2.5 MIRE WELCT RURD P Continue to R/U to kill well.Install flow lines to'. ----. L choke house and Kill tank. 9/21/2015 0:00 2:30 4:30 2 MIRU WELCT MPSP P P/U,install and test lubricator to 1800 psi.Pull L BPV.IA=750 osi.TBG=750 osi. 9/21/2015 0:00 4:30 5:00 0.5 MIRU WELCT SEQP P Pressure test lines going to the choke house -- - -- L and kill tank to 3000 osi. 9/21/2015 0:00 5:00 6:00 1 MIRE WELCT KLWL P S eed pressure off of the IA and TBG to the L choke and loll tank.IA=750 psi,TBG 750 psi. ---- raped nresoinp from 700 no to 0 9/21/2015 0:00 6:00 9:15 3.25 MIRU WELCT KLWL P.. Pump 420 bbls of 9.9 ppg brine down the L tubing out the IA to the kill tank,2.5 bpm,82- 250 psi.Pump 25 bbls at 2 bpm at 200 psi. 9/21/2015 0:00 9:15 9:30 0.25 MIRU WELCT OWFF p Monitor well for 15 minutes.Well still flowing L out the IA. 9/21/2015 0:00 9:30 12:30 3 MIRU WELCT KLWL P Pump 165 bbls of 9.9 ppg brine down th TOG L and out the IA..2 hom.150 psi, 9/21/2015 0:00 12:30 13:00 0.5 MIRE WELCT OWFF P Monitor well for 30 minutes.(well dead) I. 9/21/2015 0:00. 13:00 14:00 1 MIRU WHDB MPSP P.... Set the BPV and perform a rolling test to 1000'.. .... OP '.osi for 10 minutes. 9/21/2015 0:00 14:00 18:30 4.5 '. MIRU WHDB OWFF T Monitor the IA flow,tinting flow back every 2.5 OP '.gals.Gals=Minutes 2.5=5:20 2.5=6:45 '.. 2.5=10:30 2.5=16:30 2.5=29:00 2.5= 35+Well Flow decrease to a minimal amount. Verified with town and received approval to _. ..... ... nim 9/21/2015 0:00 18:30 21:00 2.5 MIRU WI-IDE NUND P N/D Tree:The tubing hanger has moved up OP about a half inch with the lock down screws '.. still tight.The hanger body seal has been crushed allowing the hanger to rise.Consulted with CPAI Superintendent and FMC.FMC said the body seal is crushed but could hold pressure for a BOP test.It was decided to N/U the GOP's and perform a body test to see if the hanger body seal will hold pressure. 9/21/2015 0:00 21:00 0:00 3 MIRE WHDB NUND P N/U BOPE,ready test equipment and cellar for', OP body test. 9/22/2015 0:00 0:00 0:30 0.5 MIRU WHDB RURD P RU testing equipment '.. OP 9/22/2015 0:00 0:30 1:30 1 MIRE WOOS ROPE T Attempted to get ROPE shell test to250/3000 OP psi,Made mutable attempts with test pump to 3000 psi.pressure would fall off and IA flow would increase with pressure on it.Tubing hanger seals appear to be leaking.States right to witness ROPE was waived by Bob Noble nrydrr 9/22/2015 0:00 1:30 11:30 10 MIRU WHDB WAIT T discussed with town on plan forward and state OP '.approval:Sim OP continue to test Choke manifold and TD 250/3000 psi.Load and drift - './tally new completion string 9/22/2015 0:00 11:30 12:00 0.5 MIRE WHDB MPSP P Pull blanking plug and BPV. ... __. _.. OP 9/22/2015 0:00 12:00 13:30 1.5 COMPZ RPCOM RURD P RU weatherford equipment and landing it '.. _. ,........ N 1 P ..... 9/22/2015 0:00 13:30 15:00 1.5 COMPZ RPCOM PULL P Attempted to pul seals Free from PBR working '.. N P string up to 240K and then to 270 K straight nul h 9/22/20150:00 15:00 0:00 9 COMPZ RPCOM WAIT T Walt onEloe crew due to time out resin[ions' '., N P Sim-OP:load drill pipe and tally. 9/23/2015 0:00 0:00 3:30 3.5 COMPZ RPCOM WAIT T Continue to wait on 0-line crew. N P 9/23/2015 0:00 3:30 6:30 3 COMPZ RPCOM ELNE P Spot HES E-line.Rehead line. ...... ...... .__:.. N P 9/23/2015 0:00 6:30 7:00 0.5 COMPZ RPCOM SFTn P P2SM.Discuss the rig up and working with '.. N P explosives. 9/23/2015 0:00 7:00 9:30 2.5 COMPZ RPCOM ELNE P Bring E Line equipment to the ng floor and rig'.. '., N P up same.Rig up Lubricator.Make-up Tool String.Pressure test lubricator at 1,000 psi. '.. 9/23/2015 0:00 9:30 12:00 2.5 COMPZ.RPCOM EWE P Run canna hole with CCL/Stnng Shot(240 gram/ft N P x 5-ft L.).Log a tie-in pass to the completion jewelry on the Tubing Detail dated 09/14/1997.Make a(+)6-f[correction. Repeat tie in pass.Log the String Shot into place and straddle the planned tubing cut at '.. Ou 9/23/2015 0:00 12:00 13:30 1.5 COMPZ RPCOM ELNE P Pullll out w[h Tooll String.Lay down String N P Shot...elk charges detonated.Makeup the '.. Radial C at nn Tnurh Cr tier 9/23/2015 0:00 13:30 15:30 2 COMPZ RPCOM ELNE P Run in hole with The Radial Cutting Torch N P Cutter.Log[ie-In pass.Make a(+)16-ft '., correction.Log the RCT Cutter into place with the cut to be made at 8,768-ft.Set Anchors. ',. Attempt to fire Cutter.No indication on surface'.. or on the Logging Unit control panel.Release '.. ..... Pu.hn... 9/23/2015 0:00 35:30 16:30 1 COMPZ RPCOM ELNE P Pull out to inspect tool string.RCT Cutter '.. N P appears to be a normal expected recovered cutter after"£rine" 9/23/2015 0:00 16:30 17:30 1 COMPZ RPCOM ELNE P Set back E-LIne equipment so we can pull on N P the tubn0 string. 9/23/2015 0:00 17:30 18:00 0.5 COMPZ.RPCOM PULL P Pulled Hanger to surface.Tbg came free at N P 225K.Inspected hanger.outer body is off center 1/8 gap on one side 3/8"on the other. _....... Seal Innk nk 9/23/2015 0:00 18:00 19:30 1.5 COMPZ RPCOM CIRC P Circulated 465 BBL's of 9.9 0 brine St 5 BPM '.. N P 81 450 05 9/23/2015 0:00 19:30 20:00 0.5 COMPZ RPCOM OWFF P Flow check 30 min's '.. _.. N P 9/23/2015 0:00 20:00 20:30 0.5 COMPZ RPCOM RURD P --- RU Weatherford and Camco handling ....._. N P eauioment 9/23/2015 0:00 20:30 0:00 3.5 8768 5200.COMPZ RPCOM PULL P POOH with current completion N P 9/24/2015 0:00 0:00 2:30 2.5 5200 2400 COMPZ'.RPCOM PULL P Continue to POOH with current completion N P • 0 ex 9/24/2015 0:00 2:30 3:30 1 2400 2400 COMPZ RPCOM RURD P swap over handling equipment to DP '.. N P 9/24/2015 0:00 3:30 4:30 1 2400 2500 COMPZ WHDB MPSP T Pick up storm packer and set tat 100 ft. N OP. 9/24/2015 0:00 4:30 5:00 0.5 2500 2500 COMPZ WHDB PRTS T Test storm packer to 1100 psi for 10 min's. I N OP a empty stack 9/24/2015 0:00 5:00 8:00 3 2500 2500 COMPZ WHDB RUED P Install test plug.RU Test equipment Perform N OP shell,test 9/24/2015 0:00 8:00 12:30 4.5 2500 2500 COMPZ WHOP. POPE P Perform the remainder of the Initial ROPE test N OP as per ConocoPhillips/AOGCC requirements at '.. 250/3,000 psi with 4 1/2"and 3 1/2'Test Joints.Record test pressures on the chart. '.. '.. Test Gas alarms.Perform the Koomey draw down test.The State's right to witness the test'. was waived by B.Noble. 9/24/2015 0:00 12:30 13:30 1 2500 2500 COMPZ WHDB RURD P Pull Test PLug.Blow down lines.Rig down test -- N OP equipmene 9/24/2015 0:00 13:30 14:15 0.75 2500 2500 COMPZ WHDB MPSP T PJSM.Pick-up Packer Petrlevmg Tool.Latch N OP and release Baker Storm Packer.Monitor Well. Pull out of the hole and lay down same. '.. 9/24/2015 0:00 14:15 19:30 5.25 2500 0 COMPZ RPCOM PULL P Continue to single down the remaining 4 1/2" N P Completion.Recover 13.54 ft of cut jt.Finish tally and clear pipe shed.Note:heavy paraffin from jt 231 thru 246 TOF @ 8773.44 ft.ORKB'.. 9/24/2015 0:00 19:30 20:30 1 0 0 COMPZ WELLP BHAH P Load,tally and prep BHA#1:5 3/4 overshot '.. N R with 4.5 grapple.string mills and jarring assemhly 9/24/2015 0:00 20:30 21:45 1.25 0 312 COMPZ WELLP BHAH P Pick up 13HA#1 N R 9/24/2015 0:00 _ 21:45 0:00 2.25 312 2320 COMPZ WELLP POLO P Pick up drill pipe and RIH with BHA#1 -._. N R 9/25/2015 0:00 0:00 8:00 8 2320 8735 COMPZ.RPCOM PULD P Continue to pick up drill pipe R14 with BHA# .-. N P 1. 9/25/2015 0:00 8:00 9:00 1 8735 8762 COMPZ RPCOM FISH P Up weight=170K.Down weight=95K.Make N P up Top Drive.Bring Pump on line at 2.0 '.. bpm/315 psi.Tagged the top of the 4 1/2" Tubing Stump at 8,762-ft dpmd.Pull up to '.. 200K to plant overshot and bleed Jars.Fish free.Pull Seals free from the PBR. 9/25/2015 0:00 9:00 11:00 2 8762 8762 COMPZ RPCOM CIRC P Park Seal Assembly Mule Shoe on top of the N P PBR.Bong Pump on line at 7.0 bpm/2,090 psi.'.. Pump bottoms up(230 bbls).Pump a Hi-Vis '.. Sweep(42 bbls).Chase sweep back to • surface at 7.1 bpm/2,136 psi.Recovered- 1/2 cu/yd of Frac Sand and some bits of rubber.End Pump.Monitor Well.Blow down Adjust L:n 9/25/2015 0:00 11:00 11:30 0.5 8762'- 6762 COMPZ RPCOM SURD P AdjustLmk[Ilt Control on Top Drive..SIMDPS N P clear and clean floor. 9/25/2015 0:00 11:30 15:45 4.25 8762 312 COMPZ,RPCOM TRIP P Trip out with the recovered 41/2"Tubing N P Stub,Baker Seal Assembly,and BHA #1...standing back the 3 1/2"Drill Pipe in the k 9/25/2015 0:00 15:45 17:00 1.25 312 0 COMPZ RPCOM BHAH BOA aP BHA at surface.Single down Drill Collars.Lay N P down the remainder of BHA#1.No Fish rcrnva 2 Insnem Granula Broken 9/25/2015 0:00 17:00 19:30 2.5 0 COMPZ RPCOM WAIT T Wait on fish ng tool from Baker ...... .... N P 9/25/2015 0:00 19:30 20:30 1 0 211 COMPZ',RPCOM BHAH T Make up BHA#2.5 3/4 Bowen over shot with'. N P 4.5"oranle 9/25/2015 0:00 20:30 0:00 3.5 211 8757 COMPZ',RPCOM TRIP T RIH with BHA#2 ...- N P 9/26/2015 0:00 0:00 2:00 2 8757 8768 COMPZ RPCOM FISH T Engaged fish @ 8768 ft.Set grapple.Up Wt.= N p ', I65K Dw.Wt.=95K.Began working jars @ 40 K over.Attempted to rotate seals to brake '.. free.with out success.Continue to work jars • up to 75 K over.Hit 13 times pulled free.@ '.. 220K.pull seals out of PBR with 400 psi pressure on it dropped to 175.Tail @ 8788 R '.. Cu. 9/26/2015 0:00 2:00 3:45 1.75 8788 8768 COMPZ RPCOM CIRC T Circulate well clean with 40 BBL/52 Vis sweep'.. N P @ 8 BPM @ 2100 psi.Recovered sand. Continue to circulate @ 5 BPM @ 1150 psi. while building 50 BBL 60 Vis pill to spot across'.. hole In casing.@ 7580 ft+/- 9/26/2015 0:00 3:45 4:15 0.5 8788. 8788 COMPZ RPCOM OWFF T Monitor well for flow/BDTD _.. N P 9/26/2015 0:00 4:15 8:15 4 8788 211 COMPZ RPCOM TRIP T POOH with BHA#2. .... .. N P 9/26/2015 0:00 8:15 10:30 2.25 211 0 COMPZ RPCOM BHAH T BHA#2 at surface.Set back Drill Collars.Lay N P down the remainder of BHA#2.Lay down the remainder of the recovered 4 1/2" Completion...4 1/2"cut-off Tubing Stump,4 '.. ',. 1/2"Pup Joint(16.40-ft),and the 4 3/4"OD Baker Anchor/Seal Assembly.Break Fish out of'.. the Overshot.Run the two stands of Drill Collars back in the hole.Single down same. '.. ',. Clear and clean floor. 9/26/2015 0:00 10:30 10:45 0.25 0 10 COMPZ WELLP SHAH P Make-up the Baker Retnevamatic Test Packer. N R 9/26/2015 0:00 10:45 14:30 3.75 10 7530 COMPZ WELLP TRIP P Trip Test Packer in on 3 1/2"Drill Pipe from N R the Derr ck. 9/26/2015 0:00 14:30 14:45 0.25 7530 7530 COMPZ WELLP MPSP P Up weight=135K.Down weight=90K.Set N R Baker Retrievamatic Test Packer with the '..center element at 7,530-ft.(30K slack-off). 9/26/2015 0:00 14:45 16:30 1.75 7530 7198 COMPZ WELLP PRTS P Attempt to get a pressure on the Casing at N R 2,500 psi.Pressure"fall-offt-900 psi x 4 minutes.Repeat with same results.Release Packer and move up hole to 7,510-ft.Set Packer with 35K slack-off.Pressure up with '.. same fall-off results.Observe Wellhead and flow from the Drill Pipe side for seeps drips...none.Move Packer up to 7,488 ft. Reverse circulate 10 bbls around Packer at 2.0 bpm/305 psi.Re-set Packer at 7,488-ft with • 35K slack-off.Pressure up to 2,500 psi and • observe a fall-off down to 1,300 psi in 3 minutes.Notify Anchorage Engineer.Pull three'. stands of Drill Pipe and set the Packer with the''. ''l ! center element 7,198-ft dpmd.Pressure up to 2,500 psi x 30 minutes.Solid test.Discuss i options with Anchorage Engineer. 9/26/2015 0:00 16:30 19:00 2.5 7198 7198 COMPZ WELLP WAIT T Wait on final orders and a new Completion N R running brooram. 9/26/2015 0:00 19:00 0:00 5 7198 3300 COMPZ',WELLP PULD P POOH laing down drill pipe nod test packer N I R • • 410. 9/27/2015 0:00 0:00 2:45 2.75 3300 0 COMPZ WELLP PULD P Contiune to lay down doll pipe and test packer'.. N R 9/27/2015 0:00 2:45 3:15 0.5 0 0 COMPZ RPCOM,WWWH P Pull Wear ring and wash stack. N P 9/27/2015 0:00 3:15 4:00 0.75 0 COMPZ RPCOM OTHR P Clear floor and pipe shed of tools N P 9/27/2015 0:00 4:00 4:30 0.5 0 0 COMPZ RPCOM RURD P RU Weatherford tbg handling equipment .... N P 9/27/2015 0:00 4:30 16:45 12.25 0 8795 COMPZ RPCOM PUTB P PJSM:RIH with completion as per tally/ '., I.. N P '. procedure.Up weight=11OK.Down weight= 83K.No-Go out on the lower PBR at 8,783-ft dpmd...Mule Shoe depth at 8,795-ft dpmd. '.. 9/27/2015 0:00 16:45 17:15 0.5 8795. 8778 COMPZ RPCOM RURD P Rig up to circulate.SIMOPS:stage Corrosion N P Inibitor and Returns trucks.Pull Seal Assembly'.. '.. out of the lower PBR and park Mule Shoe at --- 8 778-ft 9/27/2015 0:00 17:15 19:00 1.75 8778 8778 COMPZ RPCOM CRIH P Circulate Corrosion Inhibited Bnne(Condor N P 3O3A as per MI proceedure).290 BBLs 5i 4 RPM(al 450 PSI. 9/27/2018 0:00 19:00 19:45 0.75 8778 COMPZ RPCOM PACK P Engaged lower seal assembly and set Baker N P Premier sacker As Der Baker. 9/27/2015 0:00 19:45 20:00 0.25 COMPZ RPCOM PRTS P Shear out seals 51 122 K.PT packer to 500 psi N P for 5 Min's. 9/27/2015 0:00 20:00 22:00 2 COMPZ RPCOM HOOO P Space out tbg.and land.RILDS N P 9/27/2015 0:00 22:00 23:30 1.5 - COMPZ RPCOM PRTS P Pressure test Tubing to 3000 psi for 15 min's. N P Bled pressure down to 1500.PT IA to 2500 psi for 30 min's.Sheared SOS and circulated thru both direction at3 BPM Si 2200 psi. 9/27/2015 0:00 23:30 0:00 0.5 COMPZ RPCOM OWFF P.... Monitor well for flow.15 min's -._.. _..... N P 9/28/2015 0:00 0:00 0:30 0.5 COMPZ WHDB MPSP P Installed TWC and tested indirection of flow to ._ _... N OP 1000 PSI fors Min's 9/28/2015 0:00 0:30 4:30 4 COMPZ WHDB:NUND P ND ROPE _.. N OP 9/28/2015 0:00 4:30 8:00 3.5 COMPZ WHDB NUND P NU tree and adaptor.Have Drill Slte Operator'.. N OP and"POP"Forman verify correct alignment due to non-routine Wing Valve/Lateral Line alirmrtmr, 9/28/2015 0:00 8:00 10:00 2 COMPZ WHDB POTS P Pressure testst Hanger void at 250/5,000 x 10 N OP minutes.Good.Pressure test Production Tree '.. at 250/5,000 psi.Good.(SIMOPS Clea pits). 9/28/2015 0:00 10:00 10:30 0.5 COMPZ WHDB MPSP P :Pull TWCV. N OP 9/28/2015 0:00 10:30 13:30 3 COMPZ WHDB FRZP P PJSM with Lil'Red.Pressure test line Freeze N OP protect well with 75 bbls diesel pumped down -' the IA.Release LII'Red.Allow diesel to U-tube. 9/28/2015 0:00 13:30 14:00 0.5 DEMOB MOVE ROOD P Blow down lines.RIg down and secure Cellar. Final pressures...Tbg=0 psi,IA="0"psi,OA'.. =60 psi.Release Rig at 14:00 hrs. • • P722 [97- - / SJ Loepp, Victoria T (DOA) From: Nesvold, Janelle R <Janelle.R.Nesvold@conocophillips.com> Sent: Tuesday, September 22, 2015 4:13 PM To: Loepp, Victoria T (DOA) Subject: RE: KRU 1E-33 Rolling BOP test/Full BOP test PTD(197-151) Follow Up Flag: Follow up Flag Status: Flagged Victoria, As I mentioned on the phone, we were unable to pull the tubing free from the seals on 1E-33. In order to proceed forward we will need to rig up e-line and make a cut in the tubing.This will postpone the BOP test a little more. Please let me know if you approve the request to proceed with rigging up e-line for the cutting operation on 1E-33. Thanks, Janelle Original Message From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Tuesday,September 22, 2015 11:23 AM To: Nesvold,Janelle R Cc: Regg,James B(DOA) Subject: [EXTERNAL]FW: KRU 1E-33 Rolling BOP test/Full BOP test PTD(197-151) Original Message From: Loepp, Victoria T(DOA) Sent:Tuesday, September 22, 2015 11:22 AM To: Loepp,Victoria T(DOA) Subject: RE: KRU 1E-33 Rolling BOP test/Full BOP test PTD(197-151) Janelle, Approval is granted to conduct a full BOP test after the tubing is pulled. A combined BOP test report including the results of the rolling BOP test and the full BOP test should be submitted when complete. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil &Gas Conservation Commission 333 W. 7th Ave Anchorage,AK 99501 Work: (907)793-1247 1 Victoria.LoeppCc@alaska.gov • • CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it,and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793- 1247 or Victoria.Loepp@alaska.gov Original Message From: Loepp,Victoria T(DOA) Sent:Tuesday,September 22,2015 10:30 AM To: 'Nesvold,Janelle R' Cc: Regg,James B(DOA) Subject: KRU 1E-33 Rolling BOP test PTD(197-151) Janelle, Please send the charts for the rolling BOP test and a description of the process(what were you pumping/rate). What are the criteria for a passing rolling test?We will review. Is this BOP stack a part of the BWM(between wells maintenance) program? If the results of the rolling BOP test are acceptable, a full BOP test will be needed after the tubing is pulled and a storm packer set as you described below. A combined BOP test report including the results of the rolling BOP test and the full BOP test should be submitted. Thanx, Victoria Original Message From: Nesvold,Janelle R [mailto:Janelle.R.Nesvold@conocophillips.comj Sent:Tuesday,September 22,2015 10:19 AM To: Loepp,Victoria T(DOA) Subject: Re: 1E-33 Approval Victoria, We have successfully performed a rolling test on the BPV on 1E-33. We also currently have 9.9 ppg NaCI brine KWF in the well. Thank you, Janelle Nesvold Sent from my iPhone On Sep 22,2015, at 8:10 AM, "Nesvold,Janelle R" <Janelle.R.Nesvold@conocophillips.com<mailto:Janelle.R.Nesvold@conocophillips.com»wrote: Victoria, 2 S During the operations on 1E-33 yesterday we nippled down the tree noticed the tubing hanger move up about(1/2)" due to compressional forces on the tubing.The lock down screws were still in place.This caused the hanger body seal to be crushed.We attempted to perform a pressure test against the body seal to see if it would hold but were unsuccessful. As a result we are unable to perform our BOP test as planned. I am writing you to ask for a variance to allow us to pull the 4-1/2"tubing and install a storm packer in the well to use to pressure against for the BOP test. Please let me know as soon as possible if the state approves the variance to go ahead and pull the 4-1/2"tubing in order to set the storm packer. If you have any questions please don't hesitate to call me. Thank you, Janelle Nesvold Senior Wells Engineer ConocoPhillips Alaska Inc. 700 G Street(ATO-1586) Anchorage,AK 99501 Work: (907)263-4641 Cell: (281)352-2927 3 • ZG25Co WELL LOG TRANSMITTAL DATA LOGGED /'1212N01D5 K.BEER R' r. � To: Alaska Oil and Gas Conservation Comm. August 31, 2015 Attn.: Makana Bender i_' 22 201.; 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 ACP, RE: Leak Detect Log with TMD3D: 1E-33 Run Date: 8/2/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS ANC@halliburton.corn 1E-33 Digital Data in LAS format, Digital Log file 1 CD Rom 50-029-22797-00 Leak Detect Log with TMD3D (Field print) 1 Color Log 50-029-22797-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. ,ANNE ), ':u Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: M4-42474k-4) 6_80,..cat • OF Tram Alaska and Gas• S ti � THE STATEw� s •‘� TA Conservation Commission ��= - 333 West Seventh Avenue u : _ Anchorage, Alaska 99501-3572 GOVERNOR BILL WALKER g Main: 907.279.1433 ALA& Fax: 907.276.7542 www.aogcc.alaska.gov Janelle Nesvold 504,MECt DEC 1 12015. Senior Wells Engineer s, ConocoPhillips Alaska, Inc. I`/ - 1 P.O. Box 100360 Anchorage,AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1E-33 Sundry Number: 315-551 Dear Ms.Nesvold: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, its, / Cathy P oerster Chair DATED this /D day of September, 2015 a 2015 RBDMS SEP 2 Encl. STATE OF ALASKA • AKA OIL AND GAS CONSERVATION COM ION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon r Plug Perforations r Fracture Stimulate r Pull Tubing p"" • Operations Shutdown r Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Rogram r Plug for Redrill r Perforate New Pool r Repair Well �, ; Re-enter Susp Well r Other:5rneikeripae-, 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc.• Exploratory r Development J - 197-151 3.Address: Stratigraphic r Service 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-029-22797-00 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No F7 / "KRU 1E-33 9.Property Designation(Lease Number): 7 10.Field/Pool(s): ADL 25651l 454c0 Kuparuk River Field/Kuparuk River Oil Pool . 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft)4743 Plugs(measured): Junk(measured): 10951 6279 /0 9S1 t (O,Z?Q t 8888' none Casing Length / Size MD TVD Burst Collapse CONDUCTOR 79 16 121' 121' SURFACE 5440 9.625 5481' 3999' RECEIVED PRODUCTION 8959 7 8997' 6207' LINER 2115 4.5 10951' 6279' SEP Q3- 2015 AOGCC Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9270-9330,9799-10248,10299-10650,10699-10883 6204-6217,6231-6242,6243-6258,6262-6273 4.5 L-80 8823 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER FAB-1 PACKER MD=8807 TVD=6002 NIPPLE-CAMCO BP6i HYDRAULIC LANDING PROFILE NO GO NIF MD=1474 TVD=1435 12.Attachments: Description Summary of Proposal (;E 13. Well'Class after proposed work: Detailed Operations Program r BOP Sketch Exploratory (• Stratigraphic r Development Service 14.Estimated Date for Commencing Operations: 9/7 //y 15. Well Status after proposed work: 10/1 2015 VII,' OIL . WINJ r WDSPL r Suspended r 16.Verbal Approval: Da GAS r WAG r GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdown r Abandoned r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Janelle Nesvold @ 263-4641 Email: Janelle.R.Nesvold@conocophillips.com Printed Name Janelle N-svold Title: Senior Wells Engineer Signature - ' / Phone:263-4641 Date MU-7/s -- %.' Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 3k 5 - 5 s i Plug Integrity r BOP Test 1'4/Mechanical Integrity Test r Location Clearance r Other: l3pp 1-z-5 f- QUOr5i (AriP5>P )S 243Flp5t J ,4--Pi j-1vlct-r l'jl---t✓ly,*r.+' /'f5t f`o 2 500 p5' Spacing Exception Required? Yes ❑ No [/ Subsequent Form Required: /G — 4 D 4 � • - APPROVED BY Approved by:( j'1L(�✓</J�(/\ COMMISSIONER THE COMMISSION Date: 9-/S "f a V7-L 9/! /✓ — Approved application is va Id or 12 months troo Q/the date of ap royal. submit Form and ORIGINForm 10-403 Revised 5/2015 rI `7 SEP 2,Ota a .nts in Duplicate S • ConocoPhillips RECEIVED Alaska SEP 0 3 2015 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 AOGCC Aug.28,2015 Commissioner State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska,Inc.hereby submits an Application for Sundry Approval to workover Kuparuk Producer 1E- 33(PTD# 197-151). 1E-33 was originally drilled and completed in 2000 as a"C"sand producer in Kuparuk.In 2015 a hole fmder identified a tubing leak at 3,170'RKB and the well failed an MIT-T.A CMIT was attempted in July 2015.An LDL was run in July 2016 and identified another tubing leak between 7,555' and 7,560 SLM.In August a temperature anomaly was seen at 7,572'SLM.An impulse test identified a casing leak in between 7500' and 7600' SLM. The purpose of this workover is to pull the existing 4-1/2"upper completion and replace it with a new 4-1/2" stacked packer completion above the production casing leak. If you have any questions or require any further information,please contact me at 263-4641. Sincerely, /Janelle Nesvold Wells Engineer CPAI Drilling and Wells • 1E-33 Rig Workover, P&R Tbg w/ a Stacked Packer (PTD #: 197-151) Current Status: The well is currently shut in. It has a leak in the tubing and production casing. Scope of Work: Pull the existing upper completion and replace with a new 4 ''/2"stacked packer completion above the production casing leak. General Well info: MPSP: 2,438 psi(using 0.1 psi/ft gas gradient) Reservoir pressure/TVD: Kuparuk C-Sands—3,058 psi/6,204'TVD(9.5 ppg EMW)measured 10/9/2014. Wellhead type/pressure rating: FMC Gen V,7 1/16"5M Top x 11"3M Bottom Nabors 7ES BOP Config: Annular/Variable Pipe Rams/Blind Rams/Mud Cross/Variable Pipe Ram MIT results: MITxIA—Failed 07/20/2015,MIT-T—Failed 07/20/15 Well Type: Producer Estimated Start Date: October, 10,2015 Production Engineers: David Lagerlef/Dana Glessner Workover Engineer: Janelle Nesvold(263-4641 /Janelle.R.Nesvold@conocophillips.com) Proposed Pre-Rig Work: 1. RU E-line.Ensure SSSV has been locked out. 2. Set catcher sub on top of DB plug at 8,888.4'MD. 3. Set DV's in GLM#2 and#3.Ensure GLM#1,4 and 5 are dummied off and leave GLM#6 open. 4. RIH and cut tubing at mid joint of the first full joint above the PBR. 5. RDMO E-line. 6. Set BPV w/i 24 hrs of rig arrival. Proposed Procedure: 1. MIRU. 2. Pull BPV. Reverse circulate KWF. Obtain SITP&SICP,if still seeing pressure at surface, calculate new KWF and repeat circulation as necessary. Verify well is dead. 3. Set BPV&blanking plug,PT from below,ND tree,NU BOPE&test to 3,000 psi. V 4. Pull blanking plug&BPV,screw in landing jt,BOLDS's,unland tubing hanger. 5. POOH laying down 4-1/2"tubing. a. If tubing will not pull free, RU E-line: Fire a string shot and cut the tubing in the middle of the second full joint above the Seal Assembly. 6. MU overshot assembly to pull Seal Assembly free from Baker FAB-1 permanent packer and TOOH in stands to lay down same. 7. MU Tandem String Mill Assembly and test packer and cleanout to the top of the FAB-1. 8. While POOH stop at 7,500'MD and test upper casing.If casing does not hold contact engineer for path forward. 9. TOOH laying down DP and Cleanout assembly. 1E-33 Rig Workover, P&R Tbg w/ a Stacked Packer (PTD #: 197-151) 10. MU&TIH w/4-1/2" stacked packer completion. 11. Space out. Drop ball/rod and pressure up to set retrievable packer. Shear upper PBR. 12. Space out w/pups. Stab seal assembly into PBR and land tubing hanger. 13. PT the tubing to 3,000 psi,bleed tubing to 2,000 psi, PT the IA to 2,500 psi for 30 min and record. Bleed the IA to zero,then the tubing. Ramp up the IA pressure quickly to shear the SOV. 14. Pull the landing joint,install TWC. PT TWC from below. 15. ND BOPE. 16. NU tree. Pull TWC&install tree test plug. Test tree. Pull test plug. 17. Freeze protect well w/diesel. 18. Set BPV. 19. RDMO. Post-Rig Work request: 1. Reset well house(s)and flowlines of adjacent wells 2. Pull BPV 3. RU Slickline: a. Pull ball and rod b. Pull SOV and run GLD c. Pull RHC plug body d. Pull catcher and DB plug e. Ensure well is freeze protected and RDMO 4. Turn well over to Ops. . • Kuparuk Producer 1E-33 Pro•osed Well Schematic ot F-1 9/2/2015 Janelle Nesvold Ca+«oF9'4 Nt, 16"62.5 ppf H-40 welded conductor from 42'-121'MD . 9 4.1/2"12.6 ppf 180 NSTC production tubing 9-5/8"40 ppf L-80 BTC surface casing from 41.1'-5480.9'MD 1 44:4 I sw l'. :::: I E IN 4it BAKER Premier packer @"7,500'MD 04 OA *11 N4 lk, *4 til it 3.813"CAMCO'DB'nipple BAKER seal assembly AV''' %li,t'i r BAKER FAB-1 packer @"'8,807'MD la 13.1 04,,„ ,,,,„ t' ,,,,, - , Locator Seal Assembly "C"sand perfs 7"26 ppf L-80 ABM-BTC production casing ,414 4., from 38.4'-6,106.6'MD • 0 Loepp, Victoria T (DOA) From: Nesvold,Janelle R <Janelle.R.Nesvold@conocophillips.com> Sent: Wednesday, September 16, 2015 2:57 PM To: Loepp,Victoria T (DOA) Subject: 1E-33 Sundry Follow Up Flag: Follow up Flag Status: Flagged Victoria, We would like to move 1E-33 up on the rig schedule by a few weeks to help avoid long costly rig moves across the field. We are expecting to start this well around 9/23/15. Can you please rush the Sundry review on this well? Thanks for your help. Janelle Nesvold Senior Wells Engineer ConocoPhillips Alaska Inc. 700 G Street(ATO-1586) Anchorage,AK 99501 Work: (907)263-4641 Cell: (281)352-2927 1 • • Bettis, Patricia K (DOA) From: Nesvold, Janelle R <Janelle.R.Nesvold@conocophillips.com> Sent: Tuesday, September 08, 2015 7:00 AM To: Bettis, Patricia K (DOA) Subject: RE: KRU 1E-33: Sundry Application (PTD 197-151) Patricia, The current effective depth of 1E-33 is 10,951'MD (6,279'TVD). Thanks, Janelle From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Friday, September 04, 2015 10:22 AM To: Nesvold, Janelle R Subject: [EXTERNAL]KRU 1E-33: Sundry Application (PTD 197-151) Jan, What is the current effective depth of KRU 1E-33, both MD and TVD? Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907) 793-1238 or patricia.bettis@alaska.gov. 1 1"', ,.-. Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning, They are available in the original file. may be scanned during the rescan activity or are viewable by direct inspection of the file, 197- 151 Well History File Identifier Organization (done) 0 Two-Sided 1111111111111111111 0 Rescan Needed 1111111111111111111 RESCAN DIGITAL DATA OVERSIZED (Scannable) 0 Color items: 0 Grayscale items: 0 Poor Quality Originals: 0 Other: 0 Diskettes, No, 0 Maps: 0 Other, NofType 0 Other items scannable by large scanner OVERSIZED (Non-Scannable) 0 Logs of various kinds 0 Other TOTAL PAGES: I)" 7 -- NOTES: ORGANIZED BV: BEVERLV BREN VINCENT SHERVL MARIA LOWELL DATE: 151 Project Proofing 1111111111111111111 1111111111111111111 D Staff Proof By: Date: PROOFED BV: BEVERLV BREN VINCENT SHERVL MARIA LOWELL DATE: 151 Scanned (done) IIIII1IIIII1IIII1II PAGES: (at tha time of scanning) SCANNED BV: BEVERLV BREN VINCENT SHERVL MARIA LOWELL DATE: -3 ~ IS/'lL ReScanned (done) 1111111111111111111 RESCANNED BV: BEVERLV BREN VINCENT SHERVL MARIA LOWELL DATE: Isl General Notes or Comments about this fo'~: Quality Checked (done) 1111111111111111 ~I PAGES: Re,'NOT$oaMod,wp<! ~,.~ ConocoPh i l l i ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Sept 14, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 10 Anchorage, AK 99501 ~~'~~~~ ~~'~ ~' d `3a~$ Dear Mr. Maunder: '~ ~ - Iq~ 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 if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pum~ed August 20th -Sept 11th, 2008. The corrosion inhibitor/sealant was pumped Sept 12 - 13t ,2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date • Kuparuk Field 9/14/2008 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1 C-178 203-041 8' 1.50 8" 9/11 /2008 4.68 9/12/2008 2F-17 196-204 12' 10" 2.25 8" 9/11/2008 7.65 9/12/2008 3R-20 192-022 9' 4" 1.50 16" 9/11/2008 1Y-27 193-088 11' 9" 3.00 20" 8/24/2008 2.97 9/12/2008 1 Y-29 188-091 41' 6.00 5' 8/20/2008 10.20 9/1 Z/2008 1 Y-32 188-093 27' 8" 4.40 32" 8/20/2008 6.80 9/12/2008 1 Y-34 193-091 8' 1.10 27'° 8/20/2008 5.95 9/12/2008 E-33 197-151 9' 6" 2.10 20" 8/24/2008 7.23 9/12/2008 1 E-104 204-227 7' 1.40 9" 8/24/2008 1.70 9/12/2008 2X-01 183-084 10" NA 10" NA 3.40 9/13/2008 2X-02 183-103 23" NA 23" NA 3.40 9/13/2008 2X-03 183-109 6" NA 6" NA 1.28 9/13/2008 2X-05 183-107 8" NA 8" NA 5.10 9/13/2008 2X-06 183-110 6" NA 6" NA 1.70 9/13/2008 2X-07 183-113 6" NA 6" NA 1.28 9/13/2008 ZX-08 183-114 6" NA 6" NA 1.28 9/13/2008 2X-17 195-171 6" NA 6" NA 1.70 9/13/2008 ~~ ~~°; ~.s~~' ~` UI±C - ~ '~y $~°~s ';` <~ -,c_''''''""' Schlumbel'ger 'RECEI\/EO NO. 3615 Schlumberger -DCS 2525 Gambe" Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth r.rar. ') 1 2fìn;:: uc.L...., ...i·v·... Com pany: - c-....,.,.,¡'-;':_~í! ~Cit&GdsCOOs. rU\;;L....~....... Anchorage Field: Well Job # Log Description Date BL 1 Y -19 11144040 PIEZO SONA TOOL 11/19/05 1 1 Y -27 11072935 PRODUCTION PROFILE WIDEFT 11/22/05 1 2D-09 11072933 SBHP SURVEY 11/18/05 1 1 R-15 11072932 SBHP SURVEY 11/18/05 1 3F-05 N/A PRODUCTION LOG 11/13/05 1 L-25 11056689 SBHP SURVEY 09/14/05 1 3F-12 11057064 INJECTION PROFILE 11/06/05 1 3 H -0 1 11056685 PRODUCTION PROFILE W/DEFT 09/10/05 1 10-16 11141232 PRODUCTION PROFILE W/DEFT 12/01/05 1 1 E-33 I ðJ7- 'l51 N/A GLS & BHP 12/04/05 1 3N-13 11141234 INJECTION PROFILE 12/03/05 1 2N-329 11141236 SLIM CHFR 12/08/05 1 1 C-07 11141231 PRODUCTION PROFILE W/DEFT 11/30/05 1 10-09 11141233 INJECTION PROFILE 12/02/05 1 3B-16 N/A INJECTION PROFILE 12/08/05 1 10-06 N/A PRODUCTION PROFILE W/DEFT 12/10/05 1 2A-21 11141237 INJECTION PROFILE 12/12/05 1 2A-24 11144049 PROD PROFILE W/DEFT 12/15/05 1 1 Q-1 01 11144044 MDT 11/24/05 12/20105 \ q1-/51 Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Kuparuk Color CD 1 SIGNED: SCANNED' Jl\N ~, 0 2005 DATE:&~) Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 0 375* 375 0 100 0 785 5 6/26/2004 6/30/2004 1 E-112 100 0 14267 36 7/1/2004 9/30/2004 1E-112,1E-114 100 0 7139 27 10/1/2004 10/27/2004 1 E-114 0 0 0 0 ..-I 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: 4a. Well Class: Stratigraphic 0 Service 0 Development 0 Exploratory 0 4b. Well Status: Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 0 5a. Sundry number: 5b. Sundry approval date: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal 0 or Continuation 0 or Final 0 10. (h}(1) drilling mud, drilling (h}(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added 304-178 (h)(3) Other Commission approved substances (include descriptions in block 12) 5/13/2004 Volume (bbls): Number of days disposal occurred Previous totals (bbls): o 2004 / 2nd 685 2004 / 3rd 14167 2004 / 4th 7039 2005/1st o Total Ending Volume (bbls): 21891 300 375 22566 11. Attach: Disposal Performance Data: Other (Explain) 0 12. Remarks and Approved Substances Description(s): Pressure vs. Time 0 Step Rate Test 0 ::;:. C'A N· N· E-~ n Ii 11 Cj t) ï n n 5 V~ ~ . ~ tc..-.',,) l" I.. (,¿ 1.1 -¥.. * Freeze protect volumes and LOT I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: < l <"'--L~ --~~ Printed Name: Randy Thomas Title: Date: Kuparuk Drilling Team Leader Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE 6. Permit to Drill Number: 7. Well Name: 8. API Number: 197-151 1 E-33 50-029-22797 -00 9. Field: Kuparuk River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: "-' 68 Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. 7J ( ('ê.. { c> r Phone Number: (907) 265-6830 Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 4a. Well Class: Stratigraphic D Service D Development 0 Exploratory D 4b. Well Status: Oil 0 Gas D WAG D GINJ D WINJ D WDSPL D 5a. Sundry number: 5b. Sundry approval date: 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal D or Continuation 0 or Final D 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added 6. Permit to Drill Number: 7. Well Name: 8. API Number: 197-151 1 E-33 50-029-22797 -00 9. Field: 304-178 (h)(3) Other Commission approved substances (include descriptions in block 12) 5/13/2004 Volume (bbls): Number of days disposal occurred Kuparuk River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: Previous 0 0 totals (bbls): 2004 I 2nd 685 100 2004 1 3rd 14167 100 2004 14th 7039 100 20051 1st 0 0 Total Ending Volume 21891 300 (bbls): 11. Attach: Disposal Performance Data: Pressure vs. Time D Other (Explain) D 12. Remarks and Approved Substances Description(s): Signature: Printed Name: Randy Thomas Form 10-423 Rev. 2/2004 375* 375 0 785 0 14267 0 7139 0 0 375 22566 Step Rate Test D SC~~NNFrj ~PR Date: Title: Kuparuk Drilling Team Leader INSTRUCTIONS ON REVERSE SIDE ...-J 0 5 6/26/2004 6/30/2004 1 E-112 36 7/1/2004 9/30/2004 1E-112,1E-114 27 10/1/2004 10/27/2004 1 E-114 0 --' Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarte" July 20 for the second quarte" October 20 for the third quarte" and January 20 for the 1 8 200Etourth quarter. 68 '-I {lG- {c:,3 Phone Number: (907) 265-6830 * Freeze protect volumes and LOT I hereby certify that the foregoing is true and correct to the best of my knowledge. ~\~ Submit in Duplicate Previous totals (bbls): 2004 / 2nd 2004 / 3rd 2004 / 4th 2005/1st Total Ending Volume (bbls): Signature: Printed Name: STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 4a. Well Class: Stratigraphic D Service D Development 0 Exploratory 0 4b. Well Status: Oil 0 Gas 0 WAGD GINJ D WINJ 0 WDSPL D Sa. Sundry number: 5b. Sundry approval date: 304-178 (h)(3) Other Commission approved substances (include descriptions in block 12) 5/13/2004 Volume (bbls): Number of days disposal occurred 1 . Operator: ConocoPhillips Alaska, Inc. 2. Address: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal D or Continuation 0 or Final D 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added 6. Permit to Drill Number: 7. Well Name: 197-151 1 E-33 8. API Number: 50-029-22797 -00 9. Field: Kuparuk River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: '~' 0 0 375* 375 0 685 100 0 785 5 6/26/2004 6/30/2004 1 E-112 14167 100 0 14267 36 7/1/2004 9/30/2004 1 E-112, 1 E-114 7039 100 0 7139 27 1 0/1/2004 10/27/2004 1 E-114 21891 300 375 22566 11. Attach: Disposal Performance Data: Pressure vs. Time 0 Other (Explain) 0 12. Remarks and Approved Substances Description(s): * Freeze protect volumes and LOT I hereby certify that the foregoing is true and correct to the best of my knowledge. . \ .,. _.,~ l ~ - Step Rate Test 0 Date: Randy Thomas Title: Kuparuk Drilling Team Leader Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE \.. '"' 68 Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. SCANNED JAN 14 2005 t(,(oS' Phone Number: (907) 265-6830 Submit in Duplicate ~ Previous totals (bbls): 2004 / 2nd 2004 / 3rd 2004 / 4th 2005/1st ,~ Total Ending Volume (bbls): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 4a. Well Class: Stratigraphic D Service D Development 0 Exploratory D 4b. Well Status: Oil 0 Gas D WAGD GINJ D WINJ D WDSPL D Sa. Sundry number: 5b. Sundry approval date: 304-178 (h)(3) Other Commission approved substances (include descriptions in block 12) 5/13/2004 Volume (bbls): Number of days disposal occurred 6. Permit to Drill Number: 7. Well Name: 197 -151 1 E-33 375 15427 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal D or Continuation 0 or Final D 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added 8. API Number: 50-029-22797 -00 9. Field: Kuparuk River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: 0 0 375* 375* 0 685 100 0 785 5 6/26/2004 6/30/2004 1 E-112 14167 100 0 14267 36 7/1/2004 9/30/2004 1 E-112, 1 E-114 14852 200 11. Attach: Disposal Performance Data: Pressure vs. Time D Other (Explain) D 12. Remarks and Approved Substances Description(s): * Freeze protect volumes and LOT I hereby certify that the foregoinfl is true and correct to the best of my knowledge. Signature: \ ~ \ ~ Date: Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Form 10-423 Rev. 2/2004 Step Rate Test D IN~TRt Jr.TION~ ON RFVFR~F ~lnF 41 Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. SCANNED NO\/ 0 4 2004 to ((f:iI( (04 Phone Number: (907) 265-6830 ~"hmit in nllnli~~tA STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal 0 or Continuation 0 or Final 0 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added Previous totals (bbls): 0 0 2004 / 2nd 685 100 2004 / 3rd 2004 / 4th 2005/1st Total Ending Volume (bbls): 685 100 Disposal Performance Data: Other (Explain) 0 12. Remarks and Approved Substances Description(s): Pressure vs. Time 0 11. Attach: 4a. Well Class: Stratigraphic 0 Service 0 Development 0 Exploratory 0 4b. Well Status: Oil 0 Gas 0 WAGD GINJ 0 WINJ 0 WDSPL 0 Sa. Sundry number: 5b. Sundry approval date: 304-178 (h)(3) Other Commission approved substances (include descriptions in block 12) 5/13/2004 Volume (bbls): Number of days disposal occurred 375* 375* 0 785 375 1160 Step Rate Test 0 * Freeze protect volumes and LOT I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: ~~ ~ -- Printed Name: Randy Thomas Form 1 0-423 Rev - 2/2004 Date: Title: Kuparuk Drilling Team Leader INSTRUCTIONS ON REVERSE SIDE 0 5 5 6. Permit to Drill Number: 7. Well Name: 197 -151 1 E -33 8. API Number: 50-029-22797 -00 9. Field: Kuparuk River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: ~, 6/26/2004 1 E-112 6/30/2004 Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. 7("2 (ò 'f Phone Number: (907) 265-6830 Submit in Duplicate ~ r'\ 197- (5{ NOTE TO FILE 1 E-33...197 -151...304-178 Request for Annular Disposal Approval Summary This well was drilled in late 1997 and a disposal authorization was not requested at that time. ConocoPhillips (CPAI) is planning to drill up to 12 new West Sak wells from 1E pad and desires to use the annulus of this well. They have submitted the required information. This document analyzes the information and recommends approving their request. Offset Well Information Two wells have been identified within y.. mile of 1 E-33. Referenced to the 9-5/8" casing shoe of 1 E-33, 1 E-03 is approximately 685' distant and 1 E-22 is approximately 1100' distant. These wells were drilled in 1980 and 1983 respectively. As presented in the proximity analysis, 1E-03 and 1 E-33 converge as one goes deeper while 1 E-22 remains at about the same relative distance. At depths shallower than the surface casing in 1 E-33 (3999' tvd), 1 E-03 diverges from 1 E-33. The surface casing of the older wells, per the practice at the time, were not set through the West Sak sands. The outer annulus on each well was down-squeezed with cement and arctic pak in mid 1980 and early 1983 respectively. A review of the files did not indicate that any waste fluids were pumped into either annulus. In each case sufficient total volume was pumped to place the cement below the surface casing shoe. It is probable that some of the West Sak sections were covered with cement, although it is not likely that the total intervals in either well were covered. Neither well has been reported as having external casing pressure problems as required by the sustained casing pressure orders. It is likely that the wellbore sections of 1 E-03 and 1 E-22 proximate to 1 E-33 are not cemented. Although not cemented, given the age of the wells it is likely that the mud left in the production hole has dehydrated with time and sealed around the casing. It is unlikely that communication will be developed with the 1 E-03 wellbore due to the limited volume of disposal allowed per the regulations. The intermittent nature of the disposal operations also results in the placement of disposal volumes in multiple "wings" surrounding the well bore. The Campanian Sands are identified as being present in 1 E-33 about 400' md below the surface casing shoe and they may be a potential disposal zone. Access to those sands will be dependant on how any fluids in that open hole section have dehydrated. Well 1 E-33 Information The surface casing was run and successfully cemented to surface in 2 stages. On the 2nd stage, lead cement was circulated before the tail slurry was pumped. The casing was successfully pressure tested prior to drillout. When tested, the formation broke at about 13.3 ppg EMW and the pressure declined to about 12.0 EMW as pumping proceeded. During the 10-minute observation period, the pressure held at about 11.7 EMW. This pressure behavior is at lower EMWs than exhibited on other wells in the area. CPAI has recently performed an injectivity test down the OA. In this most recent test, the formation breaks at about 13.7 EMW and steady pump in occurs at about 13.0 EMW. After shut down, the pressure stabilized at around 11.4 EMW. If half water, half diesel is used as the fluid column; the EMWs are about 1 ppg higher. Pressure signatures such as these indicate that the shoe is still well cemented. The well was drilled to the top of the Kuparuk reservoir and 7" casing string was set and cemented without problems. On drillout, the formation was tested to 16.2 EMW without leakoff. It is indicated that the 7" casing is well cemented and that the Kuparuk sands are isolated. This well has not been reported as required by the sustained casing pressure order. G:\common\tommaunder\Well Information\By Subject\Annular Disposal\O40512 _197-151--KRU _IE-33 - AD.doc ~ r'--- Recommendation Based on the presented information, I recommend that ConocoPhillips' disposal in 1E-33 (197-151) be approved. ~ ~ 5/,~-o,--\ Tom Maunder, PE Sr. Petroleum Engineer request for annular G:\common\tommaunder\Well Information\By Subject\Annular Disposal\O40512 _197-151--KRU _IE-33 - AD.doc 1""'"'. r\ hI I ., tJR::! ~3/)Z ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ANNULAR DISPOSAL APPLICATION 20 AAC 25.080 1. Operator Name: ConocoPhillips Alaska, Inc. 3. Permit to Drill Number: 197-151 4. API Number: 50-029-22797-00 2. Address: P. O. Box 100360, Anchorage, AK 5. Well Name: 6. Field: 1 E-33 Kuparuk Unit 7. Publicly recorded wells a) All wells within one-quarter mile: 1 E-03 and 1 E-22 (see attached summary) ~ ~\~~-~\~ ~~ l%O-OSfo 0\\ b) ~~wells within one mile: 8. Stratigraphic description: a) Interval exposed to open annulus: interbedded claystone, siltstone and shale b) Waste receiving zone: Colville Clay stones yes, but all have casing set above the West Sak Sand c) Confinement: shales below West Sak, Shales above Kuparuk 9. Depth to base of permafrost: 10. Hydrocarbon zones above waste receiving zone: West Sak :t 1608' MD /1558' TVD none 12. Estimated slurry density: 10.0 #/gal. 13. Maximum anticipated pressure at shoe: 11. Previous volume disposed in annulus and date: 1425 psi 14. Estimated volume to be disposed with this request: 15. Fluids to be disposed: 35,000 bbls 16. Estimated start date: Types of waste can be drilling mud, drilling cuttings, cement-contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act of drilling a well, domestic waste water, and any added water needed to facilitate pumping of drilling mud or drilling cuttings. May 20, 2004 17. Attachments: Well Schematic (Include MD and TVD) 0 Cement Bond Log (if required) 0 FIT Records w/LOT Graph 0 Surf. Casing Cementing Data 0 Other 0 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: ~~ ~_cÀ y -rL-.'Þ""""l.:5 SI-vw Sl1\1'"1I \~- ~.......( Title: D-W:"O Oot'r3ultflnt Printed Name: Phone Number: u,.~- b-l3 ~ë) . 2C: 1855 Date: ~/( (ío'7 Commission Use Only ECEIVED MAY I 2 2004 LOT review and approval: 42.trvl57í~-cLf Approval number: 30 c.¡ . /1 c¡¡ V Conditions of approval: Form 10-403AD Rev. 9/2003 _BFL a Oil & Gas Cons. Commissio~OMMISSIONER Anchorage MAY .1 4: 2IDäTRUCTIONS ON REVERSE BY ORDER OF THE COMM5SION Om, r ¥ f 0 RIG! N A I Submit in Duplicate Approved b ~ ~. Conoc~illi ps Post Office Box 100360 Anchorage, Alaska 99510-0360 Steve Shultz Phone (907) 263-4620 Fax: (907) 265-1535 Email: steven.m.Shultz@conocophillips.com May 10 ,2004 Alaska Oil and Gas Conservation Commission 222 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Application for Sundry Approval for Annular Disposal of Drilling Waste on Well1E-33 Dear Sir: ConocoPhillips Alaska, Inc. hereby requests that 1E-33 be permitted for annular pumping of fluids occurring as a result of drilling operation, per regulation 20 ACC 25.080. It is intended to begin annular disposal operation on 1£-123 in approximately two weeks. Please see the attached form 10-403 and other pertinent information as follows: 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. Annular Disposal Transmittal Form Pressure Calculations for Annular Disposal Surface Casing Description Surface Casing Cementing Report and Daily Drilling Reports during cement ops Casing and Formation Integrity Report (LOT at surface casing shoe) Production Casing Description Production Casing Cementing Report and Daily Drilling Report during cement ops Plan View of Existing Adjacent Wells Plan View of Existing and Planned Adjacent Wells Pressure Integrity Test If you have any questions or require further information, please contact Steve Shultz at 263- 4620 in the Conoco/Phillips office. ~y, Stb'e Shultz Drilling Consultant ,-..... 1"', Annular Disposal Transmittal Form- WelllE-33 A. B. Designation of well to receive drilling wastes: The depth to the base of freshwater aquifers and permafrost, if present. A stratigraphic description of the interval exposed to the open annulus and other information sufficient to support a commission finding that the waste will be confined and will not come to the surface or contaminate freshwater. A list of all publicly recorded wells within one- quarter mile and all publicly recorded water wells within one mile of the well to receive drilling waste. c. D. E. Identify the types and maximum volume of waste to be disposed of and the estimated density of the waste slurry. F. An estimate of maximum anticipated pressure at the outer casing shoe during annular disposal operations and calculations showing how this value was determined. Details that show the shoe of the outer casing is set below the base of any freshwater aquifer and permafrost, if present, and cemented with sufficient cement to provide zone isolation: Details that show the inner and outer casing strings have sufficient strength in collapse and burst to withstand anticipated pressure of disposal operations: Any addition data required by the Commission to confirm containment of drilling wastes: G. H. 1. IE-33 No Aquifers/Base of Permafrost=:!: 1 608' MDI1558'TVD From the 9 5/8" shoe to the Cement top all that is open is interbedded claystone, siltstone and shale with occasional minor non- hydrocarbon bearing sands. See attached horizontal plane clearance report and plot indicating that there are two wells within a quarter of a mile in the same horizontal plane as the 9 5/8" surface casing shoe on lE-33. lE-03 and lE-22 both have been drilled within the quarter mile reference. Both of these wells were cement arctic packed (lE-03, 7/5/80, 58 bbls cement/I 15 bbls arctic pack and lE-22, 1/8/83,41 bbls cement/98 bbls arctic pack) Types of waste can be drilling mud, drilling cuttings, cement -contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act of drilling a well, domestic waste water, and any added water needed to facilitate pumping of drilling mud or drilling cuttings. Maximum volume to be pumped is 35,000 bbls. Maximum anticipated differential pressure at casing shoe during disposal operation is 2473 psi. See attached calculation page. See Attached: cementing reports, LOT/FIT reports and casing reports. See attached casing summary sheet and calculation pages. 5'-\%\ ~ MD ~'1Cf\" TVD (Ær~§~ Well: IE-33 Date 5/1 012004 95/8" Surface Csg ~ Estimated TOC 6500' ---------------------- 8997' MD 6013' TVD u ~ 7" Production Csg I"'"" /"'"'\ Assumptions Maximum surface pressure of 1 ,200 psi, 12.0 ppg fluid being injected Column of gas to bottom GLM wi no gas lift pressure Going to 99% of 7" Collapse Values Gas down to lower GLM and no header pressure Maximum Differential Pressure at Surface Shoe Maximum Disposal MW 12 ppg Maximum Pressure @ 9 5/8" Shoe 2089 psi (Max Duf Press=Max DISposal Press +(Max Disposal MW) (.O52)(TVD)-(Fluid WI on Backstde)(.O52)(TVD) LOT on 9 5/8" Shoe 1425 psi 4952 ppg MWE Production Casin2 Size Weight Grade Collapse @ 100% Collapse @ 85% Gas Depth (TVD of bottom GLM) Gas Gradient Max Disposal Pressure with 13.0 ppg Maximum pressure in 7" X 9 5/8" Annulus and below . No Header Pressure . Column of gas to last GLM . No cement outside 7" down to GLM . 12.0 ppg mud in 9 5/8" annulus . Water from 9 5/8" shoe to GLM . 1,200 psi injection pressure CPC=7" Collapse Press.-(Max Mud wI. )1.O52)(TVD of 9 5/8")-8.33( 052)ITVD of GlM- TVD of 9 5/8")+( gas ~radient\ITVD of bottom GLM) TVD(.O52) 7 inch 26 ppf L-80 5410 psi 4599 psi 5900' TVD O.l1ppg 1,200 psi 5357 psi Surface Casin2 Size Weight Grade Burst @100% Burst @ 85% Fluid Weight on Backside Maximum Disposal Pressure Maximum Differential Pressure @ 9 5/8" Shoe . 13.0 ppg Mud Weight . Maximum surface pressure of 1500 psi . MDP=-(Fluid wt. backside)(.O52)(TVD)+MW(.O52)(TVD shoe)+Max Surface Pressure 9518 inch 40# L-80 5481 psi 4659 psi 8.33 ppg 1,200 psi 2089 psi Maximum Mud Weight . To burst 9 5/8"casing with 1,200 psi 19.5 ppg MMW=Pb @ 85% +(Fluid Weight on Backside)('052)(TVD)-Max Disposal Press (.O52)(TVD) / r-. ~ CASING I TUBING I LINER DETAIL 9-5/8" Surface Casing ARca Alaska, Inc. Subsidiary of Atlantic Richfield Company # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN 41 Jts Joint 'B' Above RKB Landing Joint FMC Fluted Mandrel Casing Hanger . 9-5/8", 40#, L-80, BTC, Range 3, Class A Casing 9-5/8", 40#, L-80, BTC, Range 3, Class A Casing - Baker Locked Gemoco 754 PDC Cementing Stage Tool 9-5/8", 40#, L-80, BTC, Range 3, Class A Casing - Baker Locked 9-5/8",40#, L-80, BTC, Range 3, Class A Casing Gemoco Insert Shut-Off Baffle 9-5/8",40#, L-80, BTC, Range 3, Class A Casing Gemoco Float Collar 9-5/8", 40#, L-80, BTC, Range 3, Class A Casing Gemoco Float Shoe Joint 'A' 83 Jts 1 Jt 2 Jts BakerLock thru Float Collar, plus Stage Collar 29 Bow Spring Centralizers: Install a Centralizer on each of the first 27 Joints, Install a Centralizer In the middle of Joints 'A' & 'B'. (Put Centralizers on Stop Rings In middle of Jts #1, 2, 'A', & 'B') Run Stage Cementing Collar ( Jts 'A' & 'B') between Joints #86 & #87. Run Fluted Hanger on top of Joint #127. Leave 13 Joints In the Shed (Jts #128 thru #140). WELL: 1 E-33 KRU DATE: 8/26/97 1 OF 1 PAGES LENGTH DEPTH TOPS -4.74 45.82 4.12 1734.70 43.24 2.77 42.50 3479.25 -4.74 41.08 45.20 1779.90 1823.14 1825.91 1868.41 5347.66 5347.66 5390.80 5392.32 5479.31 5480.89 Remarks: String Weights with Blocks: 270K# Up, 170K# On, 75K# Blocks. Ran 129 joints of casing. Drifted casing with 8.679" plastic rabbit & hanger with 8.525" rabbit. Used National Arctic Grade API Modified No Lead thread compound on all connections (National = BOL 2000). Torqued to the base of the triangle stamp. 43.14 1.52 86.99 1.58 Bottom of Shoe ==» I TD = 5496' MD (15' Rathole) Parker Rig #245 Drilling Supervisor: Don E. Breeden d:/~ ~ r-\ Cementing Details Field: Kuparuk River Unit Date: 8/26/97 KOP & Angle I Shoe Depth Float Depth I % washout 575'-530 5481' 5391' State type used, intervals covered and spacing 29 Gemoco Bow Spring Centralizers: One on each of first 27 joints, 1st two on stop rings in middle of float joints; One on stop ring in middle of joint on each side of Gemoco Stage Cementing Collar. Weight PV(prior cond) PV(after cond) yp(priOr cond) YP(after cond) 9.8 ppg 21 16 20 12 Gels before Gels after Total Volume Circulated 6/8 4/5 Stg 1: 921 Bbls / Stg 2: 232 Bbls Type Volume I Weight Water 50 Bbls / 20 Bbls 8.34 ppg Type I Mix wtr temp No. of sacks I Weight Yield AS III LW :t75° F 210 sx / 307 s~ 10.5 ppg 4.42 cfs Additives: Class G + 3.5% 044 + 0.60% 046 + 30% 053 + 1.5% D79 + 50% D124 + 1.5% S1 Type I Mix water tempi No. of sacks I Weight I Yield Class G & AS I :t75° F 650 sx / 60 sx 15.8 / 15.7 1.15 / 0.93 Additives: Stage 1: Class G + 0.266% D29 + 0.2% D46 + 0.3% D65 + 1% S1 Stage 2: Arctic Set 1 Displacement Rate(before tail at shoe) Rate(tail around shoe) 7.0 BPM / 6.8 BPM 7.0 BPM /6.1 BPM Reciprocation length Reciprocation speed :t12' :t45 FPM Theoretical Displacement Actual Displacement 405.5 Bbls / 138.2 Bbls 405.2 Bbls / 139.6 Bbls Calculated top of cement lOP Bumped plug Floats held Cemented to Surface 2015, 8/26 Yes Yes Remarks: Include whether full returns were obtained, reciprocation throughout operation and any other pertinent information. 1st Stage: 5 Bbls water, test lines 4000 psi, 50 Bbls water, Mix & Pump 165 Bbls Lead, drop bypass plug, Mix & Pump 122.5 Bbls Class G Tail, drop top shut-off plug, pump 10 Bbls Tail on top of plug, pump 20 Bbls wash-up water, rig pump 375.5 Bbls mud & bumped plug to 1700 psi, floats held. Full returns. Reciprocated until 120 Bbls Lead cement had rounded the shoe. 1st Stage CIP @ 1800 hrs, 8/26/97. 2nd Stage: Opened Stage Cementing Tool @ 1823' with 3000 psi, circulate annulus clean, circulated out :t85 Bbls contaminated mud & cement, circulated 232 Bbls. Pump 20 Bbls water, Mix & Pump 10.5 ppg Lead cement until getting good 10.5 ppg cement returns, pumped 242 Bbls Lead, switch to Tail & pump 10 Bbls AS 1, drop top closing plug, pump 20 Bbls wash-up water, rig pump 119.6 Bbls mud & bumped plug, pressured up & closed stage collar @ 1450 psi, pressure up & hold 1800 psi, floats held, full returns. 2nd Stage CIP @ 2015 hrs, 8/26/97. Cement Company I Rig Contractor I Signature L4' /' ./ / Dowell Parker Rig #245 Don E. Breeden ~ ARCO Alaska, Inc. Well#: 1 E-33 Casing Size Hole Diameter 9-5/8" 12-1/4" Centralizers Mud Spacer Lead Cement Tail Cement Str. Wt. Up 270K# Str. Wt. Down 170K# Str. Wt. in mud 186K# / Date: 1/2/98 ~ ~ ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 ================================================================================ WELL: 1E-33 WELL_ID: AK8917 AFC: AK8917 STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:08/23/97 START CaMP: RIG:PARKER 245 0% WI: SECURITY: 0 TYPE: AFC EST/UL:$ 2340M/ 2810M API NUMBER: 50-029-22797-00 BLOCK: FINAL:09/14/97 -------------------------------------------------------------------------------- -------------------------------------------------------------------------------- 08/22/97 (D1) TD: 121' ( 121) SUPV:DEB DAILY: $ 08/23/97 (D2) TD: 1456' (1335) SUPV:DEB DAILY: $ 08/24/97 (D3) TD: 4167' (2711) SUPV:DEB DAILY: $ 08/25/97 (D4) TD: 5496' (1329) SUPV:DEB DAILY: $ 08/26/97 (D5) TD: 5496' ( 0) SUPV:DEB/SR DAILY: $ 08/27/97 (D6) TD: 5496'( 0) SUPV:DEB/SR MW: 0.0 VISC: APIWL: 0.0 0 PV/YP: 0/ 0 PU DP Move rig around the corner to parallel pad, from 1E-31 to 1E-33. Rig accepted @ 2400 hrs. 8/22/97. 39,373 CUM:$ 39,373 ETD:$ 0 EFC:$ 2,379,373 MW: 9.7 VISC: 82 PV/YP: 30/27 DRILLING @ 2576' MD NU diverter system. Function test diverter system. Spud and drill from 121' to 816'. Injection into 1E-32 annulus backing up ball mill. Drill to 1456', drilling ahead. 87,549 CUM:$ 126,922 ETD:$ 199,961 EFC:$ 2,266,961 APIWL: 7.6 MW: 9.7 VISC: 80 PV/YP: 24/32 DRILLING @ 4750' MD Drill from 1456' to 4167'. Circulate lo/hi sweeps around. Saw gas cut to 8.9 ppg at start of circulation, from last stand or two drilled. Monitor well, pump slug. Short trip 32 stands to HWDP. Tight from 4073' to 3230'. Swabbing at 2100', pump and ream out to 1400'. 73,283 CUM:$ 200,205 ETD:$ 437,476 EFC:$ 2,102,729 APIWL: 6.4 MW: 9.8 VISC: 48 PV/YP: 19/14 RUNNING 9-5/8" SURFACE CASING Drill from 4167' to 5496' MD. Circulate lo/hi visc sweeps around. Monitor hole. Pump slug POH for short trip to HWDP. Tight from 5316' to 4260' and 1800' to 1400'. Ream and wash from 1600' to 1400'. RIH. Bridging from 1635' to 1800', work thru tight hole. Circulate lo/hi visc sweeps around and circulate hole clean. Monitor hole. Pump slug. POH. 73,604 CUM:$ APIWL: 5.2 273,809 ETD:$ 553,912 EFC: $ 2,059,897 MW: 9.8 VISC: 45 PV/YP: 16/12 TESTING BOPE Run 9-5/8" surface casing, tight @ 2170', 2417', and 2529'. Pump 1st stage cement and 2nd stage cement. ND diverter. 226,755 CUM:$ 500,564 ETD:$ 553,912 EFC:$ 2,286,652 APIWL: 5.5 MW: 8.4 VISC: 31 PV/YP: 2/ 1 APIWL: 0.0 DRILLING @ +/- 6250' MD Test BOPE. Tag cement stage collar at 1823'. Ream thru Date: 1/2/98 DAILY: $ 08/28/97 (D7) TD: 8814' (3318) SUPV:DEB/SR DAILY: $ 08/29/97 (D8 ) TD: 9012' ( 198) SUPV:DEB/SR DAILY: $ 08/30/97 (D9) TD: 9012' ( 0) SUPV:DEB/SR DAILY: $ 08/31/97 (DI0) TD: 9505' ( 493) SUPV:DEB/SR DAILY: $ 09/01/97 (Dll) TD: 9505' ( 0) SUPV:DEB/SR DAILY: $ (¿ ~ Page: 2 ARCO ALASKA INC. WELL SUMMARY REPORT stage collar. Tag at 1946', ream to 1995', cement scale. Wash down to 5300'. Drill hard cement to plug/baffle at 5347'. Drill out plug and baffle, drill cement to 5348'. Test casing to 2000 psi for 30 minutes, OK. Drill cement to 5390', drill out plug and FC @ 5390', drill cement to shoe at 5479', and drill out shoe at 5481'. 162,488 CUM:$ 663,052 ETD:$ 553,912 EFC:$ 2,449,140 MW: 9.2 VISC: 42 PV/YP: 12/10 POH FOR SHORT TRIP AT CSG PO IN Drill out shoe @ 5481', clean out rathole to 5496'. Drill 20' new hole to 5516'. Perform leak-off test. Formation leaked-off/broke down at 1025 psi, 13.3 EMW. Drill from 5516' to 8814'. 80 , 220 CUM: $ APIWL: 6.2 743,272 ETD: $ 946,964 EFC:$ 2,136,308 MW: 9.3 VISC: 44 PV/YP: 13/10 BUMPED PLUG ON 7" CSG CMT JOB Drill from 8814' to 9012'. Hold pre-job safety meeting. Run 7" intermediate casing string. 73,073 CUM:$ 816,345 ETD:$ APIWL: 5.8 977 ,086 EFC: $ 2,179,259 MW: 12.0 VISC: 46 PV/YP: 10/16 DRILL CEMENT IN 7" CASING Continue to run 7" intermediate casing. Pump cement. Test packoff to 5000 psi, OK. Tag cement @ 8889'. 264,123 CUM:$ 1,080,468 ETD:$ 977,086 EFC:$ 2,443,382 APIWL: 6.6 MW: 12.0 VISC: 48 PV/YP: 20/28 POH FOR LOGS Drill actual, cement, float collar, cement and shoe to 9012' MD. Pipe packed off, worked free. Drill from 9012' to 9022'. Perform FIT @ TMD 9022', EMW~ 16.2 ppg. Drill 6-1/8" pilot hole from 9022' to 9505'. 96,489 CUM:$ 1,176,957 ETD:$ 1,309,320 EFC:$ 2,207,637 APIWL: 4.8 MW: 12.6 VISC: 50 PV/YP: 24/34 MONITOR WELL-PREP TO POH FOR L Pump slug and POH. Hole fill 4 bbls over calculated (4 bbl loss). Monitor well, well boiling, no flow. RIH to 230O'. Well boiling stronger and flowing. Shut-in well. Circulate out 30 bbl gas influx on choke. Gas bubble migrated up while circulating. Resume circulating on choke and circulate out influx and lubricate in 12.3 ppg below bit as gas broke out. Continue circulating until getting 12.5 ppg returns, volumes remained stable. Monitor well, bubbling, no flow. RIH to 8987'. Monitor well and fill pipe every 10 stands, bubbling/boiling, no flow. Circulate out gas cut mud, returns down flowline. Gassy, but no influx. Continue circulating until gas circulated out and getting 12.4 ppg returns. Monitor well, static, very slight bubbling. Ream into open hole. Shale below shoe sticky and trying to pack-off. Reamed to 9141'. 83,645 CUM:$ 1,260,602 ETD:$ 1,309,320 EFC:$ 2,291,282 APIWL: 4.8 Date: 1/2/98 09/02/97 (Dl2) TD: 9505' ( 0) SUPV:DCL DAILY: $ 09/03/97 (D13) TD: 9505' ( 0) SUPV:DCL DAILY: $ 09/04/97 (Dl4) TD: 9505' ( 0) SUPV:DCL DAILY: $ 09/05/97 (D15) TD: 9852' ( 347) SUPV:DCL/MK DAILY: $ 09/06/97 (Dl6) TD: 9889' ( 37) SUPV:DCL/MK DAILY: $ 09/07/97 (Dl7) TD: 10575' ( 686) SUPV:DCL/MK DAILY: $ 09/08/97 (D18) TD:10655' ( 80) SUPV:DCL/MK DAILY: $ ~ r---.. '..",l ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 MW: 12.6 VISC: 51 PV/YP: 26/30 POH FOR LOGS Ream from 9141' to 9505'. Pack off and tight at 9141' and 9171'. RIH to TD. CBU. No fill. No gas. Pump pill. POH. Monitor well at 4345'. Static. RIH w/GR/CNTG/LDT/Diphole sonic. Unable to work tool string below 9180'. RIH w/clean out BHA. Ream from 8997' to 9034'. No problems. 72,979 CUM:$ 1,333,581 ETD:$ 1,309,320 EFC:$ 2,364,261 APIWL: 5.2 MW: 12.6 VISC: 51 PV/YP: 29134 APIWL: 5.0 POH W/DP Ream from 9034' to 9505'. Had small bobble at 9170'. Reamed out OK. POH to shoe. Flow check. OK. RIH to TD. No hole problems. RIH w/GR/CNTG/LDT/Diphole sonic. Had problems working tools below 9200'. Log from 9505' to shoe at 8997'. Work logs through tight hole for repeat. Circ and condition mud for cement plug. 136,820 CUM:$ 1,470,401 ETD:$ 1,309,320 EFC:$ 2,501,081 MW: 12.6 VISC: 64 PV/YP: 34137 APIWL: 6.1 DRILLING Pump cement. Test all BOPE to stringer from 8978' to 8983'. cement at 8993'. 86,755 CUM:$ 1,557,156 ETD:$ 300/5000 psi. Ream out Soft cement in returns. Tag 1,309,320 EFC:$ 2,587,836 MW: 12.2 VISC: 61 PV/YP: 32/31 POH - MWD FAILURE Drill out cement from 8993' to 9009'. Side track well at 9009'. Drilling from 9009' to 9852'. 114,567 CUM:$ 1,671,723 ETD:$ 1,543,164 EFC:$ 2,468,559 APIWL: 3.1 MW: 12.2 VISC: 61 PV/YP: 37/29 APIWL: 2.8 DRILLING Drilling from 9852' to 9889'. hole to shoe. Pump pill. CBU. Change out pulser. RBIH. 71,660 CUM:$ 1,743,383 ETD:$ MWD malfunction. Pump out of No gas. Download Sperry Sun. 1,568,099 EFC:$ 2,515,284 MW: 12.2 VISC: 63 PV/YP: 37133 APIWL: 3.0 WIPERTRIP Drilling from 9889' to 10575'. 80,335 CUM:$ 1,823,718 ETD:$ 2,030,395 EFC:$ 2,133,323 MW: 12.2 VISC: 68 PV/YP: 40/38 CONDITION MUD Drilling from 10575' to 10655'. Pump hi vis sweep. Monitor well at shoe. CBU. No gas. MAD pass from 10655' to 9880'. Attempt to program LWD. No communication between tools. Change MWD. 69,857 CUM:$ 1,893,575 ETD:$ 2,084,307 EFC:$ 2,149,268 APIWL: 2.9 Date: 1/2/98 09109/97 (D19) TD:10951' ( 296) SUPV:DCL/MK DAILY: $ 09/10/97 (D20) TD:10951' ( 0) SUPV:DCL/MK DAILY: $ 09/11/97 (D21) TD:10951' ( 0) SUPV:DCL/MK DAILY: $ 09/12/97 (D22) TD:10951' ( 0) SUPV:DCL/MK DAILY: $ 09/13 /97 (D2 3 ) TD:10951' ( 0) SUPV:DCL/MK DAILY: $ 09/14/97 (D24) TD:10951' ( 0) SUPV:DCL/MK DAILY: $ 09/15/97 (D25) TD:10951'( 0) SUPV:DCL DAILY: $ c r'--- ARCO ALASKA INC. WELL SUMMARY REPORT Page: 4 MW: 12.2 VISC: 69 PV/YP: 40/38 POH F/LINER Drilling from 10655' to 10799'. Small amount of gas to surface. Losing 1 bpm mud to formation. Drilling from 10799' to 10951'. 105,043 CUM:$ 1,998,618 ETD:$ 2,283,783 EFC:$ 2,054,835 APIWL: 2.8 MW: 12.2 VISC: 70 PV/YP: 39/40 RIH W/LINER RIH to TD. No problems. Circ and condition mud. Drop rabbit. Pump pill. Hole taking improper fill. RIH to TD. Circ and condition mud. No gas or oil. Pump pill. Held prejob safety meeting. RIH w/4.5" liner. 70,852 CUM:$ 2,069,470 ETD:$ 2,283,783 EFC:$ 2,125,687 APIWL: 3.0 MW: 12.3 VISC: 63 PV/YP: 34/40 POH W/LINER SETTING TOOL RIH w/4.5" liner to 10951'. Circ and condition mud. Lost 90% returns. Reduce pump rate to 2 bpm. Pump barafiber LCM. Regained full returns at 4 bpm. Circ out heavy mud. Pump cement. 81,478 CUM:$ 2,150,948 ETD:$ 2,283,783 EFC:$ 2,207,165 APIWL: 4.0 MW: 12.3 VISC: 66 PV/YP: 36/40 DISPLACE W/SEA Set and release hanger. Circ and condition mud w/stinger 15' inside hanger. RIH w/seal assembly and FAB-1 pkr on 3.5" DP. 69,668 CUM:$ 2,220,616 ETD:$ 2,283,783 EFC:$ 2,276,833 APIWL: 4.0 MW: 0.0 VISC: APIWL: 0.0 0 PV/YP: 0/0 ND BOPE Test casing and liner to 3500 psi for 30 min., OK. Freeze protect 9-5/8" x 7" annulus. Held prejob safety meeting. RIH w/4.5" completion equipment. 332,173 CUM:$ 2,552,789 ETD:$ 2,283,783 EFC:$ 2,609,006 MW: 0.0 VISC: MOVE RIG TO 1E-34 Continue to run 4.5" completion. ND BOPE. NU tree. Test packoff to 5000 psi. 80,262 CUM:$ 2,633,051 ETD:$ 2,283,783 EFC:$ 2,689,268 0 PV/YP: 0/ 0 APIWL: 0.0 MW: 0.0 VISC: 0 PV/YP: 0/0 RIG RELEASED Released rig @ 0230 hrs 9/15/97. 7,619 CUM:$ 2,640,670 ETD:$ 2,283,783 EFC:$ APIWL: 0.0 2,696,887 End of WellSurnmary for We11:AK8917 .. I""'"' r--... CASING AND LEAK-OFF FRACTURE TESTS Well Name: 1 E-33 KRU Date: 8/27/97 Supervisor: Don E. Breeden Casing Size and Descrip9-5/8", 40#, L-80, BTC Casing Setting Depth: 5481' TMD 3999' TVD Mud Weight: 8.4 ppg EMW = Leak-off Pressure (PL + MW 0.052 x TVD EMW = 1025 psi 1 (0.052 x 3999 ft) + 8.4 p Drilled 8-1/2" hole to 5516' MD, EMW = 13.3 ppg Pumped 2.6 Bbls. 2200 2100 800 .. B'oke Down @ 1025 psi ./. \ ./ '" / . 1) fVinu-e Shut-In /. \ . ..... / - ..............- .y' (/ . 2000 1900 1800 1700 1600 1500 1400 1300 w 1200 ~ =» ~ 1100 w ~ 0.. 1 000 900 700 600 500 -.- LEAK-OFF TEST - -0- CASING TEST 400 200 I- I 1 00 :1í 300 / -.. r\ CASING I TUBING I LINER DETAIL 7" Intermediate Casinq WELL: 1 E-33 KRU DATE: 8/30/97 1 OF 1 PAGES LENGTH DEPTH TOPS ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN 7" Long String RKB to Casing Head/Hanger Lockdowns Parker Rig #245 38.41 FMC Gen 5, 7" Fluted Mandrel Casing Hanger & Packoff (to LOS) .98 38.41 Pup Joint - 7", 29#, NT-80S, NSCC Casing, pin x pin 1.63 39.39 Crossover Pup Joint - 7", 26#, L-80, NSCC Coupling x BTC Pin 2.16 41. 02 166 Jts 7", 26#, L-80, ABM-BTC Casing Jts #51 thru #216 6865.68 43.18 Pup Joint - 7", 26#, L-80, ABM-BTC Casing 21.60 6908.86 48 Jts 7",26#, L-80, ABM-BTC Casing Jts #3 thru #50 1977.05 6930.46 Gemoco Float Collar 1.28 8907.51 2 Jts 7",26#, L-80, ABM-BTC Casing Jt #1 & #2 87.00 8908.79 Gemoco Float Shoe 1.43 8995.79 Bottom of Shoe ==» 8997.22 I TD = 9012' MD (:1:15' Rathole) Baker Locked thru Float Collar Installed 20' Pup Jt on top of Jt #50 13 Bow Spring Centralizers: Ran one on each of first 13 joints. Used stop rings In the middle of the first two Joints. 16 Centering Guides: Slipped on Joints #163, 166, 169, 172, 175, 178, 181, 184, 187, 190, #193, 196, 199, 202, 207, & 212. Installed Hanger on top of Joint #216. (Left 14 Joints in the Shed => Jts #217 thru #230.) Remarks: String Weights with Blocks: 310K# Up, 155K# On, 75K# Blocks. Ran 216 joints of casing Drifted casing & hanger with 6.151" plastic rabbit. Used National Arctic Grade API Modified No Lead thread compound on all connections (National = BOL 2000). Torqued connections to the base of the triangle stamp (6500 ft-Ib Average). Parker Rig #245 Drilling Supervisor: Don E. Breeden ~~ ,,-..... r"\ ARCO Alaska, Inc. Cementing Details Well#: 1 E-33 Field: Kuparuk River Unit Date: 8/30/97 Casing Size 10le Diametewerage Angl Shoe Depth Float Depth I % washout 7" 8-1/2" 53° 8997' 8907' Centralizers State type used, inteNals covered and spacing 13 Bow Spring Centralizers: One on each of first 13 joints, used sto~ middle of first two joints. 16 Centering Guides: every 5th joint to K( 3rd joint to :1:2300' MD. I Weight PV(prior can PV(after conyp(priOr con< YP(after cone 9.2ppg 16 12 13 10 Gels before Gels after Total Volume Circulated 5/8 3/4 758 Bbls Spacer Type Volume I Water & ARCO Spacer 10 Bbls & 50 Bbls Lead Type IMiX wtr tem: No. of sacks Weight Cement n/a Additives Mud Weight 8.34 & 10.5 Yield Tail Type MiX water tel No. of sacks I Weight I Yield Cement Class G :1:75° F I 127 sx 15.8 ppg 1.15 cfs Additives: Class G + 0.20% D46 + 0.15% D65 + 0.26% D800 Displacemer Rate(before tail at shoe) Rate(tail around shoe) Str. wt. Up 6.3 BPM 5.0 BPM 31OK# Reciprocation length Reciprocation speed Str. Wt. Down :I: 15' :1:25 fpm 155K# I Theoretical Displacement Actual Displacement Str. Wt. in mu( 341 Bbls 340 Bbls 201 K# Calculated top of cemen CIP 3umped plug Floats held 8855' 0600, 8/30 Yes I Yes Remarks: Include whether full returns were obtained, reciprocation throughout operation and any other pertinent information. Dowell prime up & flush line with 5 Bbls water. Test lines to 4000 psi. Pump 10 Bb spacer. Pump 50 Bbls ARCO Spacer weighted to 10.5 ppg. Drop bottom plug. 26 Bbls (127 sx) of 15.8 ppg cement 2 to 4 BPM. Drop top plug. Kick out with 1C Switch to rig pump & displace with mud, 6.3 BPM, :1:450 psi. Bumped plug at ca displacement. Bumped up to 3500 psi & held for 5 minutes, lost 25 psi, OK. Bled & checked floats, floats held. Reciprocated pipe throughout. 31OK# up, 155K# 75K# block weight. Full returns. CIP @ 0600 hrs, 8/30/97. Cement Company Dowell I Rig Contractor Parker Rig #245 ISignature Don E. Breeden Bill! SAKIEII ilUGIlES ¡Niter) Location: North Slope,Alaska Field: Kuparuk River Unit Installation: Pad 1E ConocoPhillips Alaska, Inc. Slot: Well: Wellbore: slot #33 33PB1 33 PB1 conocciPhmips C"'~dò" "OOM' D".~U'" Pi"".,.,,",. i", PB' R"..i"o,"i'MWD<'~9505'> Sœlo 1 '"'" > "" "" "'" 38" 38" "" "" ,~J'ost J!tiet),;5; 36" 3700 38" 38" <500 """ «00 <5" <600 I . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .." . . . . . . . . . ~ ~ - ~ ~ - "'"" z l -"""it ~ - ""00 if ø - "2600 i - BOO g ,,-.... r"\ ConoccrPhillips ConocoPhillips Alaska, Inc. MWD <0 - 9505'>, 33 PB1 slot #33, Pad 1 E CLEARANCE LISTING Page 1 Date Printed: 6-May-2004 Kuparuk River Unit, North Slope, Alaska .¡¡. BAKER HUGHES INTEQ Ellipse separations are reported ONLY If BOTH wells have uncertaintv data Onlv Depth and Maqnetic Reference Field error terms are correlated across tie points Proximities beyond ft with expansion rate of ft/1 OOOft are not reported Cutoff IS calculated on CENTRE to CENTRE distance Summary data uses Horizontal Plane clearance calculation for all minima Hole size/Casinos are NOT included Hole size/Casinqs are NOT subtracted from Centre-Centre distance Ellipses scaled to 2,58standard deviations. ClosinG Factor Confidence limit of 99.80% Errors on Ref start at Slot Permanent Datum (0,00) Report uses Revised: (D-C)lE Factor Calculation Wellbore Name 33 PB1 I Created 19-5ep-2003 I Last Revised 5-May-2004 Well .Name 33PB1 I Government ID Last Revised 24-Feb-2004 Installation Name Pad 1E Eastinq 550528 1946 I Northinq 5959591 1090 I Coord Svstem Name North Aliqnment AK-4 on NORTH AMERICAN DATUM 1927 datum True Field Name Kuparuk River Unit I Eastina 487754.6208 Northino 5948985,8206 I Coord Svstem Name I North Alionment AK-4 on NORTH AMERICAN DATUM 1927 datum True Clearance Summary Offset Offset Offset Offset Minimum MD[ft] Divergìng Ellipse Ellipse Clearance Clearance WeUName Wellbore Slot Structure Distance From[ft] Separation MD[ft] Factor MD[ft] 1ft] 1ft] 33 33 slot #33 Pad 1E 000 5481.00 5481 00 3 3 slot #3 Pad 1E 685.65 5481,00 5481.00 22 22 slot #22 Pad 1E 1101.53 5481.00 5481 00 23 23 slot #23 Pad 1E 140996 5481,00 5481.00 Reference Well bore Survey Tool ProQram Survev Name .. MOrftl MWD <0 - 9505'> 9505.00 survev Tool ISCWSA MWD Error Model Basic MWD - ISCWSA - 28 JAN 03 OJH AU data is In Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig (Actual Datum 1 08.Oft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence limit of 9901 (1 D) Prepared by Baker Hughes Incorporated conocJ'Phillips .~ r---, ConocoPhillips Alaska, Inc. MWD <0 - 9505'>, 33 PB1 slot #33, Pad 1 E CLEARANCE LISTING Page 2 Date Printed: 6-May-2004 Kuparuk River Unit, North Slope, Alaska All data is in Feet unless otherwise stated Coordinates are from Slot and TVO's are from Rig (Actual Datum 108,Oft above mean sea level) Reference MD's are from Rig, Offset MO's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (10) Prepared by Baker Hughes Incorporated '&1. BAKER HUGHES INTEQ ,~ /""",, conoc~illips ConocoPhillips Alaska, Inc. MWD <0 - 9505'>, 33 PB1 slot #33, Pad 1 E CLEARANCE LISTING Page 3 Date Printed: 6-May-2004 Kuparuk River Unit, North Slope, Alaska Rií8 BAKER HUGHES INTEQ Clearance Data Reference Reference Reference Reference Offset Well Offset Offset Offset Offset Angle Horizontal Ellipse MD[ft] TVD[ft] North[ft] East[ft] MD[ft] TVD[ft] North[ft] East[ft From Plane Separation Highside Distance [ft] [deql [ftl 5088.31 3998.96 1735.08S 1941.24E -122.2 1409.96 5481.00 3998.96 984.60S 313488E 23 Offset Well bore Survey Tool PrOQrams Well wellbore Survev Name 23 23 GMS <0-8350'> Morftl I Survev Tool 8350.od Level Rotor Gvro I Error Model Standard All data is in Feet unless otherwise stated Coordinates are from Slot and TVO's are from Rig ( Actual Datum 108 Oft above mean sea level) Reference MO's are from Rig, Offset MO's are from Rig Calculation method uses Minimum Curvature method Confidence limit of 9901 (1 D) Prepared by Baker Hughes Incorporated ,,-... /""",, conoc6Phillips ConocoPhillips Alaska, Inc. MWD <0 - 9505'>, 33 PB1 slot #33, Pad 1 E CLEARANCE LISTING Page 4 Date Printed: 6-May-2004 Kuparuk River Unit, North Slope, Alaska '&1. BAKER HUGHES INTEQ Clearance Data Reference Reference Reference Reference Offset Well Offset Offset Offset Offset Angle Horizontal Ellipse MD[ft] TVD[ft] North[ft] East[ftJ MD[ft] TVD[ft] North[ft} East[ft} From Plane Separation Highside Distance [ft] Ideç¡] 1ft] 5765.77 3998,96 2077.62S 2998.23E -1729 1101,53 5481,00 3998.96 98460S 3134,88E 22 Offset Wellbore Survey Tool ProQrams Well tWelibore I Survev Name 22 122 GMS <0-9480'> MOrftl ISurvevTool 9480 od Level Rotor Gvro I Error Model Standard All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig (Actual Datum 108 Oft above mean sea level) Reference MD's are from Rig, Offset MO's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99,01 (1 D) Prepared by Baker Hughes Incorporated ~ ,~ conoc6Phillips ConocoPhillips Alaska, Inc. MWD <0 - 9505'>, 33 PB1 slot #33, Pad 1 E CLEARANCE LISTING Page 5 Date Printed: 6-May-2004 Kuparuk River Unit, North Slope, Alaska -¡. BAKER MUGMO INTEQ Clearance Data Reference Reference Reference Reference Offset Well Offset Offset Offset Offset Angle Horizontal Ellipse MD[ft] TVD[ft] North[ft] East[ft] MD[ft] TVD[ft] North[ft] East[ft] From Plane Separation Highside Distance [ft] [deq] [ft] 5529.49 3998,96 408.58S 2762.97E -32,9 685,65 5481.00 3998.96 984.60S 313488E 3 . Offset Well bore Survey Tool Programs Well Wellbore Survev Name 3 3.. GMS <0-8905'> IMDfftl J8urvev Tool Error Model 8905.0 Photomechanical Maqnetic Standard All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig (Actual Datum 1 08,Oft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of 99.01 (1 D) Prepared by Baker Hughes Incorporated r---, ~ Conocó'Phillips ConocoPhillips Alaska, Inc. MWD <0 ~ 9505'>, 33 PB1 slot #33, Pad 1 E CLEARANCE LISTING Page 6 Date Printed: 6-May~2004 Kuparuk River Unit, North Slope, Alaska .¡. BAKER HUGHES INTEQ Clearance Data Reference Reference Reference Reference Offset Well Offset Offset Offset Offset Angle Horizontal Ellipse MD[ft] TVD[ft] North[ft] East[ft] MD[ft] TVD[ft] North[ft] East[ft] From Plane Separation Highside Distance [ft] Ideç¡] 1ft] 5481.00 399896 984.608 3134,88E -91,3 0.00 5481.00 3998,96 984.60S 3134.89E 33 Offset Wellbore Survey Tool ProQrams Well [WeUbore I Survev Name 33 33 MWD <9051 -10951'> I MDfftl jsurvevTool 10951 ,01 18CWSA MWD I Error Model BasIc MWD - 18CWSA - 28 JAN 03 OJH All data is in Feet unless otherwise stated Coordinates are from Slot and TVD's are from Rig (Actual Datum 108.0ft above mean sea level) Reference MD's are from Rig, Offset MD's are from Rig Calculation method uses Minimum Curvature method Confidence Limit of99.01 (10) Prepared by Baker Hughes Incorporated PRESSURE INTEGRITY T~ CONOCOPHILLIPS A~. Well Name: I 1E-33 Rig: Date: l. 5/8/2004 Volume Input Pump Rate: Drilling Supervisor: I Nick Scales I pump. used: Other ~ UJrnmenf ... ¡ Barrels ¡... I Bbls/Strk I ... I Bbl/min I ... Type of Test: I Annulus Leak Off Test for Disposal Adequacy I " I Pumping down I annulus. I " I Casing Test Pressure Integrity Test Hole Size: I Other - See commen~ ..., Casing Shoe Depth II Hole Depth Pumping Shut-in Pumping Shut-in RKB-CHF: 1Ft 5,516 IFt-MDI 3,9991 Ft-TVD Ft-MD I Ft-TVD Bbls psi Min psi Bbls psi Min psi CasinQ Size and Description: 19-5/8" 40#/Ft L-80 BTC I'" r 0 0.25 700 1 1125 ChanQes for Annular AdeQuacv Test Pressure Inte!:lritvTest 1 0.5 800 2 107:5 )uter casing shoe test results 6.8 in comments Mud Weight: 6.B ppg 2 0.75 950 3 1025 Description references outer 8.8 casing string. Inner casing aD: 7.0 In. 3 1 1200 4 980 ;izeisthatdrilledbelowouter 5,516 casing. 4 1.25 1250 5 960 ;timated TOC for Hole Depth. 5 1.5 1350 6 9,60 Enter inner casing aD at right 7 Desired PIT EMW: 16.0 ppg 6 1.75 1450 7 950 Estimates for Test: 1913 psi #REF! 7 2 1475 8 950 Steel Volume During Casing Test = 0 bbl 1...1 Inner String Displacement = 0 bbl I... 8 2.25 1425 9 940 EMW = Leak-off Pressure + Mud Weight = 1425 + 68 PIT 15 Second 9 2.5, 1350 10 930 0.052 x TVD 0.052 x 3999' Shut-in Pressure, psi 10 2.75 1325 0 EMW at 5516 Ft-MD (3999 Ft-TVD) = 13.7 1075 15 3 1325 0 20 3.25 1300 0 25 3.5 1290 0 30 3.75 1290 0 4 1290 0 4.25 1290 0 4.5 1290 0 4.75 1290 0 5 1290 0 0 0 ) 2000 1500 S~~'f 'l ~ ~ ,..;,"~ 'i..'., '\b~~ ,/' V--.1" ,t 'b ð-~<,c.' ' ... '=""..<; ~ ) UJ ~ ~ 1000 (J) UJ ~ c.. 500 0 0 3 Barrels 4 6 0 S 10 1 S 20 2S 30 Shut-In time, Minutes 0 PIT Point Volume Pumped 0.0 Bbls Volume Bled Back I Bbls Voume Pumped 5.0 Bbls Voume Bled Back ItSbls Comments: ~CASING TEST 9-5/8" x 7" annulus. -LEAK-OFF TEST Hot Oil Pump Unit for La I RIG #: I CPAI - DAILY ANNULAR DISPOSAL RECORD DATE: I Page- 0'- 5/8/20041 0000 HRS TO 0000 HRS (~ DISPOSING INTO ANNULUS OF WELL: I 1 E-33 BARRELS DISPOSED (List under proper fluid type) FOR MUD ONLY: ORIGIN OF FLUIDS START TIME END TIME PUMP RATE (BPM) STATIC PRESSURE (PSI) DISPOSAL PRESSURE (PSI) Operation that generated Waste Mud Mud WATER for Rushing Annulus DIESEL for Freeze Protecting Rig Wash Water OTHER (specify In comments) TOTAL CUMULATIVE VOLUME WEIGHT (PPG) FUNNEL VISCOSITY COMMENTS Completed on 08/22/97 Rig - ,) Diesel used for LOT 05/08/04 300 55 355 20 20 " ) MUD Total for Today Cummu/ative Total from WATER DIESEL WASH WATER OTHER Previous Day New Total for this Annulus 375 GEL a-GEL X-TND BICARB PH6 TOTAL VOLUMES FOR DAY: I ADDITIVES USED: rIGHT DISPOSAL SUPERVISOR: NIGHTS DAYS rAY DISPOSAL SUPERVISOR: rPAI SUPERVISOR: Nick Scales VERSION 1.3 PAl DAILY ANNULAR INJECTION RECORD SCOTT D. REYNOLDS 12-20-01 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other__ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__X RKB 108 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__ Kuparuk Unit 4. Location of well at surface 8. Well number 126' FSL, 227' FEL, Sec. 16, T11 N, R10E, UM (asp's 550299, 5959717) 1 E-33 At top of productive interval 9. Permit number / approval number 1766' FNL, 534' FWL, Sec. 23, T11 N, R10E, UM (asp's 685545, 5941982) 197-151 At effective depth 10. APl number 50-029-22797 At total depth 11. Field / Pool 2303' FNL, 2140' FWL, Sec. 23, T11 N, R10E, UM (asp's 557967, 5957343) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 10951 feet Plugs (measured) Bridge Plug (9/10/00) @ 9740' MD. true vertical 6279 feet Effective depth: measured 9740 feet Junk (measured) true vertical 6230 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 121' 16" 8 cu yds High Early 121' 121' SURF CASING 5373' 9-5/8" 517 Sx AS III LW, 650 5481' 3999' Class G, & 60 AS I PROD CASING 8889' 7" 127 Sx Class G 8997' 6107' LINER 2156' 4-1/2" 375 Sx Class G 10946' 6278' Perforation depth: measured 9270 - 9330'; [Isolated below Bridge Plug: 9799 - 10248'; 10299 - 10650'; 10699 - 10833'] true vertical 6204 - 6216'; [Isolated below Bridge Plug: 6231 - 6242'; 6243 - 6258'; 6261 - 6273'] Tubing (size, grade, and measured depth) 4.5", 12.6#, L-80, Tubing @ 8790' MD. RECEIVED Packers& SSSV (type & measured depth) Baker'FAB-l' Packer @ 8807' MD. FEB l camco 'BP6-1' Landing w/No-Go Profile @ 1474' MD. 13. Stimulation or cement squeeze summary Alaska 0il & Gas Cons. Commission Intervals treated (measured) (see attached) Anchorage Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 11 3856 1047 176 Subsequent to operation 309 851 2163 176 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /~~~ Title: Dat~repar~by~ JoSh ~P~eir/ce 265.6471 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLIcATE~% 1E.33 DEScRIPTiON OF WORK COMPLETED 9/10/00: BRIDGE PLUG INSTALLATION & PERFORATING OPERATIONS RIH w/Baker NPFI Fietrievable Bridge Plug & set the plug at 9740' MD. 9/14/00.9/15/00: MIRU & PT equi m as follows: Pent. FIIH W/CT COnveyed Perforating guns & shot 60' of Perforations in the 'C4' sand Added Perforations: 9270. 9330' MD Used 3-3/8', HSD carriers & shot the Perfs at 6 spf at 60 degree Phasing. POOH w/guns. FID. Returned the well to production W/lift gas & obtained a Valid Well test. RECEIVED FEB i 6 ZOO1 Alaska Oil & Gas Cons. Commission Anchorage THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE JANUARY 03 2001 P L E W M ATE IA L U N D ER TH IS M ARK ER C:LORIVdFILM.DOC AOGCC Geological Materials Inventory TD 113 7~,'~-~ PERMIT 97-151 ARCO Log Data Sent Received 7824 ~ SCHLUM DSI/LDT/CNTG . 9/25/1997 9/29/1997 8144 ~I5 SPERRY MPT/GR/EWR4 PB1 10/15/1997 10/15/1997 CN j8950-9445 9/25/1997 9/29/1997 CN/LDT t~~' 8950-9445 9/25/1997 9/29/1997 Box DGR/EWR4-MD ~ 5498-9505 PB1 10/22/1997 10/22/1997 DGR/EWR4-MD (>~ 5498-10951 10/22/1997 10/22/1997 DGR/EWR4-TVD v~L 4008-6376 PB 1 10/22/1997 10/22/1997 DGR/EWR4-TVD ~E 4008-6278 10/22/1997 10/22/1997 DSSI j 8950-9500 9/25/1997 9/29/1997 MWD SRVY --~ SPERRY 05-9505.- PB1 10/8/1997 10/15/1997 MWD SRVY ~ SPERRY 8956.58-10951. 10/8/1997 10/15/1997 PRODTD' lz ...... 200--8356 ...................................................... 9/3ll 997 915/1997 -: SSTVD ~C 8950-9445 9/25/1997 9/29/1997 ~0-407 Completion Date ]1 /~,/~!') Daily~vellops ~/),~-,/~?? ' Z/~ I Are dry ditch samples required? yes ;;;;~.~o And received? ~_.3~es no Was the well cored? yes ~.~ no Are tests required? yes ~.r no Well is in compliance ~ Initial Comments Analysis description received? Received? Wednesday, October 13, 1999 Page 1 of 1 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 5, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1E-33 (Permit No. 97-151) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 1E-33. If there are any questions, please call 263-4183. Sincerely, D. K. Petrash Drilling Engineer Kuparuk Development DKP/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well OIL F~ GAS [~ SUSPENDED [] ABANDONED] SERVICE [] 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 97-151 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 ' . .. _, 50-029-22797 4 Location of well at surface --: ,. ; ~~ 9 Unit or Lease Name At Top Producing Interval b -~__. 10 Well Number 1766' FNL, 534' FWL, Sec. 23, T11N, R10E, UM : . 1E~33 At Total Depth ; ' ~ · ' ' 11 Field and Pool 2303' FNL, 2140' FWL, Sec. 23, T11N, R10E, UM KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Sedal No. Kuparuk River Oil Pool Rig RKB 41', Pad 67'I ADL 25650 ALK 468 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 115 Water Depth, if offshore 16 No. of Completions 23-Aug-97 09-Sep-97 1~ ///-~-_/,~ '~I UA feet MSL 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 10951' MD & 6279' TVD 10884' MD & 6272' TVD YES M NO U NA feet MD 1465' APPROX 22 Type Electric or Other Logs Run GPJRes LWD + GR/CNTG/LDT/Dipole 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT RECORD 16" 62.5~ H-40 SURF. 121' 24'1 8 cu. Yds. High Early 9.625" 40.0# L-80 SURF. 5481' 12.25" 517 sx ASIII LW, 650 sx Class G, 60 sx ASI 7" 26.0# L-80 SURF. 8997' 8.5" 127 sx Class G 4.5" 12.6# L-80 8836' 10951' 6.125" 375 sx Class G 24 Perforations open to Production (MD+TVD of Top and Bottom and '25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4.5" 8790' 8807' 9799'-10248' MD 6231'-6242' TVD 10299'-10650' MD 6243'~6259' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC t0699'-10883' MD 6261'-6273' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 4 spf Date First Production Method of Operation (Flowing, gas lift, etc.) UI-(I blI IAL 11/22/97 gas lift Date of Test Hours Tested PRODUCTION FOI DIL-BBL GAS-MCF WATER-BBL CHOKE SIZE 12./31/97 17.80 TEST PERIOB 5 5525 0 212 32000 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (cerr) Press. 175 1382 24-HOUR RATE: 6 7437 0 23° 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A 7 tq~ <; Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE __ 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Total pump volumes for this event: Category 1. 0 Category 2. 0 Top Kuparuk C 9251' 6200' Category 3. 0 Bottom Kuparuk C 10951' 6279' Total: 0 Top Kuparuk A 10951' 6279' Bottom Kuparuk A 10951' 6279' Total to Date: 0 Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Drilling Reports, Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. ' -- Prepared by Name/Number Sharon AIIsup-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- lng 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: 1/2/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:lE-33 RIG:PARKER 245 WELL_ID: AK8917 TYPE: AFC: AK8917 AFC EST/UL:$ 2340M/ 2810M STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD:08/23/97 START COMP: WI: 0% SECURITY:0 API NUMBER: 50-029-22797-00 FINAL:09/14/97 08/22/97 (D1) TD: 121' (121) SUPV:DEB DAILY:$ 08/23/97 (D2) TD: 1456'(1335) SUPV:DEB DAILY:$ 08/24/97 (D3) TD: 4167'(2711) SUPV:DEB DAILY:$ 08/25/97 (D4) TD: 5496'(1329) SUPV:DEB DAILY:$ 08/26/97 (D5) TD: 5496'( SUPV:DEB/SR 0) DAILY:$ 08/27/97 (D6) TD: 5496'( SUPV:DEB/SR 0) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 PU DP Move rig around the corner to parallel pad, from 1E-31 to 1E-33. Rig accepted @ 2400 hrs. 8/22/97. 39,373 C UM:$ 39,373 ETD:$ 0 EFC:$ 2,379,373 MW: 9.7 VISC: 82 PV/YP: 30/27 APIWL: 7.6 DRILLING @ 2576' MD NU diverter system. Function test diverter system. Spud and drill from 121' to 816' Injection into 1E-32 annulus backing up ball mill. Drill to 1456', drilling ahead. 87,549 CUM:$ 126,922 ETD:$ 199,961 EFC:$ 2,266,961 MW: 9.7 VISC: 80 PV/YP: 24/32 APIWL: 6.4 DRILLING @ 4750' MD Drill from 1456' to 4167' Circulate lo/hi sweeps around. Saw gas cut to 8.9 ppg at start of circulation, from last stand or two drilled. Monitor well, pump slug. Short trip 32 stands to HWDP. Tight from 4073' to 3230' Swabbing at 2100', pump and ream out to 1400' 73,283 CUM:$ 200,205 ETD:$ 437,476 EFC:$ 2,102,729 MW: 9.8 VISC: 48 PV/YP: 19/14 APIWL: 5.2 RUNNING 9-5/8" SURFACE CASING Drill from 4167' to 5496' MD. Circulate lo/hi visc sweeps around. Monitor hole. Pump slug POH for short trip to HWDP. Tight from 5316' to 4260' and 1800' to 1400' Ream and wash from 1600' to 1400'. RIH. Bridging from 1635' to 1800', work thru tight hole. Circulate lo/hi visc sweeps around and circulate hole clean. Monitor hole. Pump slug. POH. 73,604 CUM:$ 273,809 ETD:$ 553,912 EFC:$ 2,059,897 MW: 9.8 VISC: 45 PV/YP: 16/12 APIWL: 5.5 TESTING BOPE Run 9-5/8" surface casing, tight @ 2170', 2417', and 2529' Pump 1st stage cement and 2nd stage cement. ND diverter. 226,755 CUM:$ 500,564 ETD:$ 553,912 EFC:$ 2,286,652 MW: 8.4 VISC: 31 PV/YP: 2/ 1 APIWL: 0.0 DRILLING @ +/- 6250' MD Test BOPE. Tag cement stage collar at 1823'. Ream thru Date: 1/2/98 DAILY:$ 08/28/97 (D7) TD: 8814' (3318) SUPV:DEB/SR DAILY:$ 08/29/97 (DS) TD: 9012' (198) SUPV:DEB/SR DAILY:$ 08/30/97 (Dg) TD: 9012'( SUPV:DEB/SR 0) DAILY:$ 08/31/97 (D10) TD: 9505'(493) SUPV:DEB/SR DAILY:$ 09/01/97 (Dll) TD: 9505'( 0) SUPV:DEB/SR DAILY:$ ARCO ALASKA INC. Page: 2 WELL SUMMARY REPORT stage collar. Tag at 1946', ream to 1995', cement scale. Wash down to 5300' Drill hard cement to plug/baffle at 5347' Drill out plug and baffle, drill cement to 5348' Test casing to 2000 psi for 30 minutes, OK. Drill cement to 5390', drill out plug and FC @ 5390', drill cement to shoe at 5479', and drill out shoe at 5481' 162,488 CUM:$ 663,052 ETD:$ 553,912 EFC:$ 2,449,140 MW: 9.2 VISC: 42 PV/YP: 12/10 APIWL: 6.2 POH FOR SHORT TRIP AT CSG POIN Drill out shoe @ 5481', clean out rathole to 5496' Drill 20' new hole to 5516' Perform leak-off test. Formation leaked-off/broke down at 1025 psi, 13.3 EMW. Drill from 5516' to 8814' 80,220 CUM:$ 743,272 ETD:$ 946,964 EFC:$ 2,136,308 MW: 9.3 VISC: 44 PV/YP: 13/10 APIWL: 5.8 BUMPED PLUG ON 7" CSG CMT JOB Drill from 8814' to 9012'. Hold pre-job safety meeting. Run 7" intermediate casing string. 73,073 CUM:$ 816,345 ETD:$ 977,086 EFC:$ 2,179,259 MW: 12.0 VISC: 46 PV/YP: 10/16 APIWL: 6.6 DRILL CEMENT IN 7" CASING Continue to run 7" intermediate casing. Pump cement. Test packoff to 5000 psi, OK. Tag cement @ 8889' 264,123 CUM:$ 1,080,468 ETD:$ 977,086 EFC:$ 2,443,382 MW: 12.0 VISC: 48 PV/YP: 20/28 APIWL: 4.8 POH FOR LOGS Drill actual, cement, float collar, cement and shoe to 9012' MD. Pipe packed off, worked free. Drill from 9012' to 9022' Perform FIT @ TMD 9022', EMW = 16.2 ppg. Drill 6-1/8" pilot hole from 9022' to 9505' 96,489 CUM:$ 1,176,957 ETD:$ 1,309,320 EFC:$ 2,207,637 MW: 12.6 VISC: 50 PV/YP: 24/34 APIWL: 4.8 MONITOR WELL-PREP TO POH FOR L Pump slug and POH. Hole fill 4 bbls over calculated (4 bbl loss). Monitor well, well boiling, no flow. RIH to 2300' Well boiling stronger and flowing. Shut-in well. Circulate out 30 bbl gas influx on choke. Gas bubble migrated up while circulating. Resume circulating on choke and circulate out influx and lubricate in 12.3 ppg below bit as gas broke out. Continue circulating until getting 12.5 ppg returns, volumes remained stable. Monitor well, bubbling, no flow. RIH to 8987' Monitor well and fill pipe every 10 stands, bubbling/boiling, no flow. Circulate out gas cut mud, returns down flowline. Gassy, but no influx. Continue circulating until gas circulated out and getting 12.4 ppg returns. Monitor well, static, very slight bubbling. Ream into open hole. Shale below shoe sticky and trying to pack-off. Reamed to 9141' 83,645 CUM:$ 1,260,602 ETD:$ 1,309,320 EFC:$ 2,291,282 Date: 1/2/98 09/02/97 (D12) TD: 9505' ( 0) SUPV:DCL DAILY:$ 09/03/97 (D13) TD: 9505' ( 0) SUPV:DCL DAILY:$ 09/04/97 (D14) TD: 9505'( 0) SUPV:DCL DAILY:$ 09/05/97 (D15) TD: 9852' (347) SUPV:DCL/MK DAILY:$ 09/06/97 (D16) TD: 9889' ( 37) SUPV:DCL/MK DAILY:$ 09/07/97 (D17) TD:10575'(686) SUPV:DCL/MK DAILY:$ 09/08/97 (D18) TD:10655'( 80) SUPV:DCL/MK DAILY:$ ARCO ALASKA INC. WELL SIRVIMARY REPORT Page: 3 MW: 12.6 VISC: 51 PV/YP: 26/30 APIWL: 5.2 POH FOR LOGS Ream from 9141' to 9505' Pack off and tight at 9141' and 9171'. RIH to TD. CBU. No fill. No gas. Pump pill. POH. Monitor well at 4345' Static. RIH w/GR/CNTG/LDT/Diphole sonic. Unable to work tool string below 9180' RIH w/clean out BHA. Ream from 8997' to 9034'. No problems. 72,979 CUM:$ 1,333,581 ETD:$ 1,309,320 EFC:$ 2,364,261 MW: 12.6 VISC: 51 PV/YP: 29/34 APIWL: 5.0 POH W/DP Ream from 9034' to 9505'. Had small bobble at 9170' Reamed out OK. POH to shoe. Flow check. OK. RIH to TD. No hole problems. RIH w/GR/CNTG/LDT/Diphole sonic. Had problems working tools below 9200'. Log from 9505' to shoe at 8997' Work logs through tight hole for repeat. Circ and condition mud for cement plug. 136,820 CUM:$ 1,470,401 ETD:$ 1,309,320 EFC:$ 2,501,081 MW: 12.6 VISC: 64 PV/YP: 34/37 APIWL: 6.1 DRILLING Pump cement. Test all BOPE to 300/5000 psi. Ream out stringer from 8978' to 8983'. Soft cement in returns. Tag cement at 8993' 86,755 CUM:$ 1,557,156 ETD:$ 1,309,320 EFC:$ 2,587,836 MW: 12.2 VISC: 61 PV/YP: 32/31 APIWL: 3.1 POH - MWD FAILURE Drill out cement from 8993' to 9009' Side track well at 9009' Drilling from 9009' to 9852' 114,567 CUM:$ 1,671,723 ETD:$ 1,543,164 EFC:$ 2,468,559 MW: 12.2 VISC: 61 PV/YP: 37/29 APIWL: 2.8 DRILLING Drilling from 9852' to 9889' MWD malfunction. Pump out of hole to shoe. Pump pill. CBU. No gas. Download Sperry Sun. Change out pulser. RBIH. 71,660 CUM:$ 1,743,383 ETD:$ 1,568,099 EFC:$ 2,515,284 MW: 12.2 VISC: 63 PV/YP: 37/33 APIWL: 3.0 WIPERTRIP Drilling from 9889' to 10575' 80,335 CUM:$ 1,823,718 ETD:$ 2,030,395 EFC:$ 2,133,323 MW: 12.2 VISC: 68 PV/YP: 40/38 APIWL: 2.9 CONDITION MUD Drilling from 10575' to 10655'. Pump hi vis sweep. Monitor well at shoe. CBU. No gas. MAD pass from 10655' to 9880' Attempt to program LWD. No communication between tools. Change MWD. 69,857 CUM:$ 1,893,575 ETD:$ 2,084,307 EFC:$ 2,149,268 Date: 1/2/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 4 09/09/97 (D19) TD:10951'(296) SUPV:DCL/MK DAILY:$ MW: 12.2 VISC: 69 PV/YP: 40/38 APIWL: 2.8 POH F/LINER Drilling from 10655' to 10799' Small amount of gas to surface. Losing 1 bpm mud to formation. Drilling from 10799' to 10951' 105,043 CUM:$ 1,998,618 ETD:$ 2,283,783 EFC:$ 2,054,835 09/10/97 (D20) TD:10951' ( 0) SUPV:DCL/MK DAILY:$ MW: 12.2 VISC: 70 PV/YP: 39/40 APIWL: 3.0 RIH W/LINER RIH to TD. No problems. Circ and condition mud. Drop rabbit. Pump pill. Hole taking improper fill. RIH to TD. Circ and condition mud. No gas or oil. Pump pill. Held prejob safety meeting. RIH w/4.5" liner. 70,852 CUM:$ 2,069,470 ETD:$ 2,283,783 EFC:$ 2,125,687 09/11/97 (D21) TD:10951' ( 0) SUPV:DCL/MK DAILY:$ MW: 12.3 VISC: 63 PV/YP: 34/40 APIWL: 4.0 POH W/LINER SETTING TOOL RIH w/4.5" liner to 10951' Circ and condition mud. Lost 90% returns. Reduce pump rate to 2 bpm. Pump barafiber LCM. Regained full returns at 4 bpm. Circ out heavy mud. Pump cement. 81,478 CUM:$ 2,150,948 ETD:$ 2,283,783 EFC:$ 2,207,165 09/12/97 (D22) TD:10951' ( 0) SUPV:DCL/MK DAILY:$ MW: 12.3 VISC: 66 PV/YP: 36/40 APIWL: 4.0 DISPLACE W/SEA Set and release hanger. Circ and condition mud w/stinger 15' inside hanger. RIH w/seal assembly and FAB-1 pkr on 3.5" DP. 69,668 CUM:$ 2,220,616 ETD:$ 2,283,783 EFC:$ 2,276,833 09/13/97 (D23) TD:10951' ( 0) SUPV:DCL/MK DAILY:$ MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 ND BOPE Test casing and liner to 3500 psi for 30 min., OK. Freeze protect 9-5/8" x 7" annulus. Held prejob safety meeting. RIH w/4.5" completion equipment. 332,173 CUM:$ 2,552,789 ETD:$ 2,283,783 EFC:$ 2,609,006 09/14/97 (D24) TD:10951' ( 0) SUPV:DCL/MK DAILY:$ MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 MOVE RIG TO 1E-34 Continue to run 4.5" completion. ND BOPE. NU tree. Test packoff to 5000 psi. 80,262 CUM:$ 2,633,051 ETD:$ 2,283,783 EFC:$ 2,689,268 09/15/97 (D25) TD:10951'( 0) SUPV:DCL DAILY:$ MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED Released rig @ 0230 hrs 9/15/97. 7,619 CUM:$ 2,640,670 ETD:$ 2,283,783 EFC:$ 2,696,887 End of WellSummary for Well:AK8917 Date: 1/2/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 REMEDIAL AND COMPLETION OPERATIONS WELL:lE-33 WELL ID: 998774 TYPE: AFC:--998774 AFC EST/UL:$ STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD: RIG: NORDIC 345M/ 625M START COMP:10/31/97 BLOCK: WI: 0% SECURITY:0 API NUMBER: FINAL: 11/02/97 50-029-22797-00 10/31/97 (C1) TD: i095i ' PB: 10884 ' SUPV: DLW DAILY: $ RIH W/TBG CONVEYED PERF G MW:12.2 BRINE Turn key well to well rig move. N/U BOPE. Test BOPE 250/3500 psi. Safety meeting. RIH with 2-7/8" tubing conveyed perforating guns. 36,864 CUM:$ 36,864 ETD:$ 0 EFC:$ 381,864 11/01/97 (C2) TD: 10951 ' PB: 10884 ' SUPV: DLW DAILY: $ N/D BOPE Fire perforating guns. 37,895 CUM:$ 74,759 ETD:$ MW: 12.1 NABR 0 EFC:$ 419,759 11/02/97 (C3) TD: 10951 ' PB: 10884 ' SUPV: DLW DAILY: $ RIG MOVED TO 1E-24 MW:12.1 NABR Safety meeting. NU tree, test packoff to 5000 psi, test tree to 250/5000 psi. Release rig @ 1800 hrs. 11/2/97. 150,402 CUM:$ 225,161 ETD:$ 0 EFC:$ 570,161 End of WellSummary for We11:998774 SPE'-~Y-SUN DRILLING SERVICES AIqCHOR3~GE ALASKA PAGE ARCO ALASKA, INC. KUPARUK RIVER UNIT / 1E-33 500292279700 NORTH SLOPE BOROUGH COMPUTATION DATE: 10/ 3/97 DATE OF SURVEY: 091097 MWD SURVEY JOB NI3MBER: AK-MM-70247 KELLY BUSHING ELEV. = 108.00 OPERATOR: ARCO ALASKA INC FT. 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. 8956.58 6085.30 5977.30 9009.50 6113.09 6005.09 9051.70 6133.55 6025.55 9083.46 6146.85 6038.85 9115.41 6158.99 6050.99 58 19 S 69.97 E .00 1803.24S 5789.79E 58 19 S 72.56 E 4.17 1817.70S 5832.43E 63 38 S 72.43 E 12.59 1828.80S 5867.61E 66 49 S 71.78 E 10.21 1837.66S 5895.05E 68 30 S 71.65 E 5.24 1846.93S 5923.11E 6064.05 6109.06 6145.95 6174.78 6204.32 9147.46 6170.26 6062.26 70 20 9178.42 6180.13 6072.13 72 28 9210.22 6189.24 6081.24 74 13 9241.36 6197.22 6089.22 76 3 9272.77 6204.44 6096.44 77 22 S 70.66 E 6.43 1856.62S 5951.50E S 71.01 E 6.99 1866.26S 5979.21E S 70.35 E 5.82 1876.33S 6007.96E S 70.79 E 6.06 1886.35S 6036.34E S 70.78 E 4.20 1896.41S 6065.21E 6234.31 6263.63 6294.06 6324.13 6354.68 9305.49 6211.45 6103.45 77 52 9339.25 6218.41 6110.41 78 19 9368.92 6223.79 6115.79 80 46 9400.23 6228.01 6120.01 83 41 9432.11 6230.85 6122.85 86 4 S 70.43 E 1.83 1907.02S 6095.35E S 70.29 E 1.42 1918.12S 6126.46E S 69.74 E 8.46 1928.09S 6153.88E S 69.86 E 9.33 1938.80S 6182.99E S 70.61 E 7.82 1949.54S 6212.87E 6386.61 6419.61 6448.75 6479.72 6511.43 9463.68 6232.22 6124.22 88 56 9495.67 6232.32 6124.32 90 42 9527.42 6231.73 6123.73 91 25 9558.79 6230.92 6122.92 91 30 9591.12 6230.24 6122.24 90 55 S 70.82 E 9.12 1959.95S 6242.63E S 70.11 E 5.93 1970.65S 6272.78E S 70.34 E 2.35 1981.39S 6302.65E S 70.15 E .67 1991.99S 6332.16E S 71.25 E 3.86 2002.67S 6362.67E 6542.94 6574.90 6606.61 6637.93 6670.23 9622.77 6229.80 6121.80 90 39 9653.87 6229.44 6121.44 90 41 9686.10 6229.21 6121.21 90 7 9717.75 6229.44 6121.44 89 2 9749.51 6230.21 6122.21 88 10 S 72.84 E 5.10 2012.43S 6392.77E S 73.02 E .60 2021.55S 6422.50E S 73.72 E 2.82 2030.78S 6453.38E S 75.96 E 7.86 2039.05S 6483.92E S 75.78 E 2.77 2046.80S 6514.71E 6701.87 6732.97 6765.19 6796.82 6828.53 9781.72 6231.02 6123.02 9814.17 6231.36 6123.36 9842.74 6231.31 6123.31 9874.89 6231.52 6123.52 9906.21 6232.56 6124.56 88 55 S 75.29 E 2.75 2054.85S 6545.89E 89 52 S 75.77 E 3.31 2062.95S 6577.31E 90 20 S 76.12 E 2.02 2069.89S 6605.02E 88 55 S 76.56 E 4.62 2077.48S 6636.26E 87 15 S 75.82 E 5.80 2084.95S 6666.65E 6860.69 6893.11 6921.64 6953.73 6984.97 9937.82 6234.13 6126.13 87 2 9969.69 6236.10 6128.10 85 52 10001.15 6238.21 6130.21 86 25 10032.93 6240.16 6132.16 86 31 10065.61 6241.76 6133.76 87 52 S 73.96 E 5.92 2093.18S 6697.13E S 74.37 E 3.86 2101.86S 6727.73E S 74.27 E 1.78 2110.35S 6757.95E S 74.14 E .49 2118.98S 6788.47E S 73.70 E 4.37 2128.02S 6819.83E 7016.52 7048.32 7079.70 7111.41 7144.05 ORIGINAL SPF:~Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. KUPARUK RIVER UNIT / 1E-33 500292279700 NORTH SLOPE BOROUGH COMPUTATION DATE: 10/ 3/97 DATE OF SURVEY: 091097 MWD SURVEY JOB NUMBER: AK-MM-70247 KELLY BUSHING ELEV. = 108.00 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. 10098.05 6242.56 6134.56 10128.34 6242.43 6134.43 10160.58 6241.74 6133.74 10192.30 6241.45 6133.45 10223.13 6241.80 6133.80 89 17 91 11 91 15 89 46 88 55 S 73.06 E 4.77 2137.29S 6850.90E 7176.47 S 72.19 E 6.93 2146.34S 6879.81E 7206.76 S 71.88 E .98 2156.28S 6910.47E 7238.99 S 72.29 E 4.84 2166.04S 6940.65E 7270.70 S 73.15 E 3.95 2175.19S 6970.08E 7301.53 10255.48 6242.53 10287.25 6243.12 10318.79 6243.40 10351.08'6243.57 10382.91 6244.27 6134.53 88 29 6135.12 89 22 6135.40 89 37 6135.57 89 45 6136.27 87 43 S 72.33 E 2.86 2184.79S 7000.96E 7333.87 S 71.49 E 3.85 2194.65S 7031.16E 7365.62 S 70.51 E 3.21 2204.92S 7060.98E 7397.14 S 70.96 E 1.44 2215.57S 7091.46E 7429.41 S 70.52 E 6.53 2226.07S 7121.49E 7461.20 10412.70 6245.63 6137.63 87 2 10444.31 6247.38 6139.38 86 38 10474.09 6248.54 6140.54 88 53 10505.60 6249.06 6141.06 89 13 10537.67 6250.05 6142.05 87 11 S 69.97 E 2.93 2236.13S 7149.50E 7490.93 S 69.73 E 1.48 2247.00S 7179.13E 7522.44 S 67.32 E 11.07 2257.89S 7206.82E 7552.11 S 67.76 E 1.76 2269.93S 7235.93E 7583.47 S 68.93 E 7.30 2281.75S 7265.72E 7615.42 10569.36 6251.96 6143.96 85 54 10599.73 6254.45 6146.45 84 41 10632.23 6257.21 6149.21 85 33 10663.74 6259.46 6151.46 86 14 10695.35 6261.37 6153.37 86 49 S 68.99 E 4.11 2293.11S 7295.24E 7646.97 S 68.43'E 4.36 2304.10S 7323.44E 7677.16 S 68.48 E 2.65 2315.99S 7353.56E 7709.44 S 69.07 E 2.85 2327.37S 7382.86E 7740.78 S 68.68 E 2.24 2338.74S 7412.29E 7772.26 10727.37 6263.03 6155.03 87 13 10759.50 6264.49 6156.49 87 33 10790.53 6266.00 6158.00 86 50 10823.37 6268.11 6160.11 85 48 10854.71 6270.59 6162.59 85 5 S 68.76 E 1.27 2350.34S 7442.08E 7804.15 S 69.19 E 1.69 2361.86S 7472.04E 7836.17 S 70.16 E 3.87 2372.62S 7501.11E 7867.11 S 70.79 E 3.70 2383.58S 7531.99E 7899.85 S 71.23 E 2.66 2393.74S 7561.53E 7931.07 10886.11 6273.29 6165.29 85 1 S 70.48 E 2.39 10951.00 6278.91 6170.91 85 1 S 70.48 E .00 2404.00S 7591.09E 7962.33 2425.60S 7652.02E 8026.92 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 8027.26 FEET AT SOUTH 72 DEG. 24 MIN. EAST AT MD = 10951 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 107.06 DEG. TIE-IN SURVEY AT 8,956.58' MD WINDOW POINT AT 9,009.50' MD PROJECTED SURVEY AT 10,951.00' MD SPF"-~-~¥-SUN DRILLING SERVICES ANCHOR_AGE ALASKA PAGE 3 ARCO ALASKA, INC. KUPARUK RIVER UNIT / 1E-33 500292279700 NORTH SLOPE BOROUGH COMPUTATION DATE: 10/ 3/97 DATE OF SURVEY: 091097 JOB NUMBER: AK-MM-70247 KELLY BUSHING ELEV. = 108.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 8956.58 9956.58 10951.00 6085.30 5977.30 6235.16 6127.16 6278.91 6170.91 1803.24 S 5789.79 E 2871.28 2098.34 S 6715.13 E 3721.42 850.14 2425.60 S 7652.02 E 4672.09 950.67 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPF'--~Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 ARCO ALASKA, INC. KUPARUK RIVER UNIT / 1E-33 500292279700 NORTH SLOPE BOROUGH COMPUTATION DATE: 10/ 3/97 DATE OF SURVEY: 091097 JOB NI3MBER: AK-MM-70247 KELLY BUSHING ELEV. = 108.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 8956.58 8999.82 9289.27 10951.00 6085.30 5977.30 6108.00 6000.00 6208.00 6100.00 6278.91 6170.91 1803.24 S 5789.79 E 2871.28 1815.23 S 5824.58 E 2891.82 20.54 1901.73 S 6080.40 E 3081.27 189.44 2425.60 S 7652.02 E 4672.09 1590.82 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS SPF--?Y-SUN DRILLING SERVICES ANCHOR_AGE ALASKA PAGE ARCO ALASKA, INC. KUPARUK RIVER UNIT / 1E-33PB1 500292279770 NORTH SLOPE BOROUGH COMPUTATION DATE: 10/ 3/97 DATE OF SURVEY: 082997 MWD SURVEY JOB NUMBER: AK-MM-70247 KELLY BUSHING ELEV. = 108.00 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. .00 .00 -108.00 121.00 121.00 13.00 281.26 281.26 173.26 464.23 464.23 356.23 554.77 554.75 446.75 0 0 N .00 E .00 .00N .00E 0 0 N .00 E .00 .00N .00E 0 10 S 66.06 E .11 .10S .22E 0 22 N 89.48 E .12 .20S 1.06E 1 34 S 63.25 E 1.39 .76S 2.46E .00 .00 .24 1.07 2.58 644.87 644.74 536.74 738.49 738.04 630.04 830.38 828.95 720.95 922.56 918.78 810.78 1015.24 1007.97 899.97 3 34 S 61.71 E 2.22 2.65S 6.05E 5 44 S 73.97 E 2.53 5.33S 13.12E 10 46 S 80.15 E 5.55 8.07S 26.01E 15 1 S 77.82 E 4.64 12.07S 46.18E 16 31 S 74.25 E 1.94 18.18S 70.61E 6.56 14.11 27.23 47.69 72 . 83 1105.35 1094.14 986.14 1196.49 1180.45 1072.45 1284.61 1262.84 1154.84 1375.43 1346.62 1238.62 1471.80 1433.27 1325.27 17 27 S 72.16 E 1.23 25.80S 95.80E 20 0 S 70.41 E 2.88 35.21S 123.51E 21 31 S 70.83 E 1.72 45.58S 152.98E 23 49 S 69.63 E 2.59 57.43S 185.91E 28 1 S 69.97 E 4.36 71.97S 225.45E 99.16 128.40 159.62 194.58 236.65 1562.12 1512.25 1404.25 1656.80 1593.33 1485.33 1749.48 1670.50 1562.50 1844.84 1747.04 1639.04 1931.95 1814.44 1706.44 29 58 S 72.56 E 2.56 86.00S 266.92E 32 10 S 72.33 E 2.34 100.74S 313.50E 35 2 S 71.00 E 3.20 116.90S 362.19E 38 10 S 72.78 E 3.46 134.54S 416.24E 40 25 S 73.97 E 2.72 150.31S 469.09E 280.40 329.26 380.55 437.40 492.55 2029.24 1886.74 1778.74 2121.64 1951.86 1843.86 2214.77 2013.74 1905.74 2307.67 2072.89 1964.89 2495.76 2189.08 2081.08 43 34 S 74.24 E 3.25 168.13S 531.70E 46 46 S 74.31 E 3.46 185.89S 594.78E 49 55 S 74.43 E 3.38 204.64S 661.79E 50 58 S 74.03 E 1.17 224.11S 730.72E 52 43 S 71.77 E 1.33 267.62S 872.03E 557.63 623.14 692.70 764.31 912.17 2778.98 2359.16 2251.16 3059.82 2526.11 2418.11 3339.75 2696.76 2588.76 3618.74 2868.32 2760.32 3901.03 3040.65 2932.65 53 27 S 70.69 E .40 340.49S 1086.43E 53 35 S 73.69 E .86 409.53S 1301.36E 51 16 S 73.30 E .84 472.54S 1514.05E 52 49 S 72.61 E .59 537.03S 1724.36E 51 55 S 71.28 E .49 606.31S 1936.91E 1138.51 1364.24 1586.06 1806.03 2029.56 4085.28 3153.34 3045.34 4274.06 3267.22 3159.22 4551.40 3435.14 3327.14 4831.15 3605.03 3497.03 5109.96 3773.27 3665.27 52 39 S 70.69 E .47 653.80S 2074.72E 53 8 S 71.76 E .52 702.25S 2217.27E 52 19 S 73.32 E .53 768.49S 2427.79E 52 52 S 73.20 E .20 832.50S 2640.62E 52 53 S 73.51 E .09 896.19S 2853.63E 2175.23 2325.73 2546.41 2768.66 2990.98 OCT 1 5 i997 SPx--~Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE Al{CO ALASICA, INC. KUPARUK RIVER UNIT / 1E-33PB1 500292279770 NORTH SLOPE BOROUGH COMPUTATION DATE: 10/ 3/97 DATE OF SURVEY: 082997 MWD SURVEY JOB NUMBER: AK-MM-70247 KELLY BUSHING ELEV. = 108.00 FT. OPERATOR: ARCO ALASKA INC. TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES VERT. DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 5414.66 3958.17 3850.17 52 23 5677.69 4120.21 4012.21 51 32 5865.40 4237.48 4129.48 51 7 6145.02 4410.43 4302.43 52 27 6424.55 4577.55 4469.55 54 7 S 71.90 E .45 968.17S 3084.85E 3233.14 S 71.28 E .37 1033.59S 3281.42E 3440.26 S 72.26 E .47 1079.44S 3420.63E 3586.79 S 70.02 E .79 1150.48S 3628.47E 3806.34 S 73.63 E 1.19 1220.29S 3841.34E 4030.31 6707.33 4747.59 4639.59 51 56 6987.28 4918.84 4810.84 52 37 7269.32 5088.25 4980.25 53 31 7548.30 5255.93 5147.93 52 34 7827.63 5426.99 5318.99 51 53 S 75.05 E .87 1281.30S 4058.81E 4256.12 S 73.29 E .56 1341.71S 4271.84E 4477.49 S 73.65 E .33 1405.86S 4488.00E 4702.96 S 72.65 E .44 1470.47S 4701.38E 4925.91 S 73.50 E .34 1534.76S 4912.62E 5146.71 8012.54 5539.07 5431.07 53 28 8199.87 5649.06 5541.06 54 36 8384.90 5756.24 5648.24 54 35 8572.90 5865.60 5757.60 54 16 8667.33 5920.97 5812.97 53 56 S 72.79 E .91 1577.41S 5053.35E 5293.76 S 72.90 E .61 1622.13S 5198.23E 5445.39 S 73.35 E .20 1665.91S 5342.56E 5596.21 S 74.44 E .50 1708.33S 5489.47E 5749.10 S 71.67 E 2.40 1730.62S 5562.63E 5825.58 8757.73 5973.32 5865.32 55 16 8851.46 6026.72 5918.72 55 16 8898.24 6053.22 5945.22 55 41 8956.58 6084.99 5976.99 58 19 9026.46 6121.69 6013.69 58 20 S 72.18 E 1.54 1753.48S 5632.68E 5899.25 S 73.84 E 1.46 1775.99S 5706.34E 5976.28 S 72.17 E 3.07 1787.25S 5743.20E 6014.82 S 69.97 E 5.51 1803.14S 5789.47E 6063.72 S 73.39 E 4.17 1821.83S 5845.92E 6123.16 9178.30 6201.91 6093.91 57 53 9272.70 6252.01 6144.01 58 0 9366.93 6302.17 6194.17 57 40 9388.20 6313.58 6205.58 57 29 9417.76 6329.54 6221.54 57 7 S 70.21 E 1.80 1862.08S 5968.38E 6252.04 S 70.59 E .36 1888.92S 6043.75E 6331.97 S 71.41 E .82 1914.89S 6119.17E 6411.69 S 70.66 E 3.09 1920.72S 6136.15E 6429.63 S 71.37 E 2.36 1928.82S 6159.67E 6454.49 9505.00 6376.89 6268.89 57 7 S 71.37 E .00 1952.22S 6229.10E 6527.74 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 6527.86 FEET AT SOUTH 72 DEG. 35 MIN. EAST AT MD = 9505 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 107.06 DEG. TIE-IN SURVEY AT SUFACE 0.00' MD PROJECTED SURVEY AT 9,505.00' MD SP'~-~qY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. KUPARUK RIVER UNIT / 1E-33PB1 500292279770 NORTH SLOPE BOROUGH COMPUTATION DATE: 10/ 3/97 DATE OF SURVEY: 082997 JOB NUMBER: AK-MM-70247 KELLY BUSHING ELEV. = 108.00 OPERATOR: ARCO ALASKA INC. INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH FT. TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION .00 .00 -108.00 .00 N .00 E .00 1000.00 993.36 885.36 17.00 S 66.43 E 6.64 2000.00 1865.39 1757.39 162.69 S 512.47 E 134.61 3000.00 2490.61 2382.61 396.01 S 1255.16 E 509.39 4000.00 3101.62 2993.62 631.38 S 2010.73 E 898.38 6.64 127.97 374.78 388.99 5000.00 3706.93 3598.93 871.29 S 2769.55 E 1293.07 6000.00 4321.97' 4213.97 1111.37 S 3520.42 E 1678.03 7000.00 4926.56 4818.56 1344.62 S 4281.52 E 2073.44 8000.00 5531.61 5423.61 1574.43 S 5043.72 E 2468.39 9000.00 6107.80 5999.80 1815.15 S 5824.41 E 2892.20 394.69 384.96 395.41 394.95 423.81 9505.00 6376.89 6268.89 1952.22 S 6229.10 E 3128.11 235.91 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DiMENSION MINIMUM CURVATURE METHOD. SP?--~Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. KUPARUK RIVER UNIT / 1E-33PB1 500292279770 NORTH SLOPE BOROUGH COMPUTATION DATE: 10/ 3/97 DATE OF SURVEY: 082997 JOB NI/MBER: AK-MM-70247 KELLY BUSHING ELEV. = 108.00 FT. OPERATOR: ARCO ALASKA INC. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -108.00 108.00 108.00 .00 208.00 208.00 100.00 308.00 308.00 200.00 408.00 408.00 300.00 .00 N .00 E .00 .00 N .00 E .00 .00 .01 S .02 E .00 .00 .13 S .29 E .00 .00 .20 S .69 E .00 .00 508.01 508.00 400.00 608.05 608.-00 500.00 708.30 708.00 600.00 809.10 808.00 700.00 911.42 908.00 800.00 .25 S 1.42 E .01 .00 1.56 S 4.02 E .05 .05 4.50 S 10.22 E .30 .25 7.40 S 22.35 E 1.10 .80 11.48 S 43.44 E 3.42 2.31 1015.28 1008.00 900.00 1119.90 1108.00 1000.00 1225.81 1208.00 1100.00 1333.27 1308.00 1200.00 1443.35 1408.00 1300.00 18.18 S 70.62 E 27.16 S 100.00 E 38.58 S 132.96 E 51.57 S 170.05 E 67.48 S 213.17 E 7.28 3.86 11.90 4.62 17.81 5.92 25.27 7.46 35.35 10.08 1557.21 1508.00 1400.00 1674.20 1608.00 1500.00 1795.73 1708.00 1600.00 1923.49 1808.00 1700.00 2058.85 1908.00 1800.00 85.27 S 264.58 E 103.61 S 322.40 E 125.50 S 387.86 E 148.79 S 463.82 E 173.73 S 551.53 E 49.21 13.87 66.20 16.99 87.73 21.53 115.49 27.76 150.85 35.37 2205.91 2008.00 1900.00 2363.43 2108.00 2000.00 2527.00 2208.00 2100.00 2693.05 2308.00 2200.00 2861.01 2408.00 2300.00 202.82 S 655.29 E 236.02 S 772.36 E 275.39 S 895.64 E 317.66 S 1021.27 E 362.28 S 1148.62 E 197.91 47.06 255.43 57.51 319.00 63.58 385.05 66.04 453.01 67.96 3029.30 2508.00 2400.00 3197.77 2608.00 2500.00 3357.71 2708.00 2600.00 3518.91 2808.00 2700.00 3684.42 2908.00 2800.00 402.63 S 1277.79 E 440.71 S 1407.91 E 476.57 S 1527.48 E 513.26 S 1648.44 E 552.68 S 1774.30 E 521.30 68.30 589.77 68.47 649.71 59.95 710.91 61.20 776.42 65.51 3848.10 3008.00 2900.00 4010.52 3108.00 3000.00 4175.39 3208.00 3100.00 4342.05 3308.00 3200.00 592.93 S 1897.45 634.15 S 2018.63 677.49 S 2142.33 719.28 S 2268.93 840.10 63.68 902.52 62.43 967.39 64.87 1034.05 66.65 SP?"r~Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE A~RCO ALASKA, INC. KUPARUK RIVER UNIT / 1E-33PB1 500292279770 NORTH SLOPE BOROUGH COMPUTATION DATE: 10/ 3/97 DATE OF SURVEY: 082997 JOB NUMBER: AK-MM-70247 KELLY BUSHING ELEV. = 108.00 OPERATOR: ARCO ALAS}CA INC. FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 4506.99 3408.00 3300.00 758.40 S 2394.11 E 1098.99 64.94 4670.62 3508.00 3400.00 795.57 S 2518.19 E 1162.62 63.64 4836.06 3608.00 3500.00 833.63 S 2644.37 E 1228.06 65.44 5001.78 3708.00 3600.00 871.70 S 2770.91 E 1293.78 65.71 5167.52 3808.00 3700.00 909.21 S 2897.65 E 1359.52 65.74 5332.45 3908.00 3800.00 947.93 S 3022.95 E 1424.45 64.94 5496.31 4008.00 3900.00 988.26 S 3146.33 E 1488.31 63.86 5658.05 4108.00 4000.00 1028.65 S 3266.86 E 1550.05 61.74 5818.43 4208.00 4100.00 1068.30 S 3385.80 E 1610.43 60.37 5977.74 4308.00 4200.00 1106.09 S 3503.92 E 1669.74 59.31 6141.03 4408.00 4300.00 1149.40 S 3625.50 E 1733.03 63.29 6306.89 4508.00 4400.00 1192.35 S 3750.65 E 1798.89 65.86 6476.50 4608.00 4500.00 1232.15 S 3881.72 E 1868.50 69.60 6643.12 4708.00 4600.00 1268.25 S 4009.97 E 1935.12 66.62 6805.33 4808.00 4700.00 1301.20 S 4133.36 E 1997.33 62.21 6969.42 4908.00 4800.00 1337.63 S 4258.25 E 2061.42 64.10 7134.35 5008.00 4900.00 1375.30 S 4383.88 E 2126.35 64.93 7302.54 5108.00 5000.00 1413.38 S 4513.63 E 2194.54 68.19 7469.43 5208.00 5100.00 1451.79 S 4641.59 E 2261.43 66.89 7633.99 5308.00 5200.00 1490.77 S 4766.34 E 2325.99 64.57 7796.85 5408.00 5300.00 1527.89 S 4889.40 E 2388.85 62.86 7960.32 5508.00 5400.00 1564.99 S 5013.26 E 2452.32 63.47 8128.97 5608.00 5500.00 1605.14 S 5142.99 E 2520.97 68.65 8301.64 5708.00 5600.00 1646.47 S 5277.54 E 2593.64 72.67 8474.22 5808.00 5700.00 1686.76 S 5412.30 E 2666.22 72.58 8645.30 5908.00 5800.00 1725.02 S 5545.72 E 2737.30 71.08 8818.60 6008.00 5900.00 1768.46 S 5680.40 E 2810.60 73.30 9000.39 6108.00 6000.00 1815.24 S 5824.73 E 2892.39 81.79 9189.76 6208.00 6100.00 1865.36 S 5977.51 E 2981.76 89.37 9377.81 6308.00 6200.00 1917.84 S 6127.87 E 3069.81 88.05 9505.00 6376.89 6268.89 1952.22 S 6229.10 E 3128.11 58.30 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS sper, r j-sLJr. 0 F:! I I--I--I IM G S I=: F:! L/I r' I:: S WELL LOG TRANSMITTAL To: State of Alaska October 22, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 1E-33 & 1E-33 PB1, AK-MM-70247 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Yn~n Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1E-33: 2" x 5"MD Gamma Ray Logs: 50-029-22797-00 2"x 5" TVD Gamma Ray Logs: 50-029-22797-00 1E-33 PBI: 2"x 5"MD Gamma Ray Logs: 50-029-22797-70 2" x 5" TVD Gamma Ray Logs: 50-029-22797-70 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia OCT 22 1997 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9,07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company OF:IICI--lNG S ES F! ~J I C::: E S WELL LOG TRANSMYrTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs October 15, 1997 1E-33 & 1E-33 PB1, AK-MM-70247 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of~ Jan Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 2 LDWG formatted Discs with verification listing. API#: 50-029-22797-00 & 50-029-22797-70 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company 0 I::t I I--I__ I I~ G S~FlVl r' I~ ~ October 8, 1997 ARCO Alaska, Inc. AOGCC, Lori Taylor 700 G Street .Anchorage, AK 99501 Re: MWD Survey 1E-33 and IE-33 PB1 Dear Sir/Madam: Enclosed is two hard copy of the above mentioned file(s). Well 1E-33 MWD survey tie-in point at 8,956.58', window point at 9,009.50' to projected survey at 10,951.00'. Well 1E-33 PB1 MWD survey tie-in point at 0.00' to projected survey at 9,505.00'. Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachments. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company 9/25/97 ... GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11382 Company: Alaska Oil & Gas Cons Corem Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk (Open Hole) Well Job # Log Description Date BL RF Sepia LIS ..~ '~:)~[.L~ Tape I1E-33 C~--/~./-~-7 ~ 97401 DSl/LDT/CNTG 970901 1 ,!E-33 ~ 97401 DSI 970901 I 1 :1 E-33~ 97401 CNL 970901 I 1 '1 E-33 .~ 97401 CNL/LDT 970901 1 1 1 E-33 97401 SSTVD 970901 I 1 Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. p, CE VED SEP 2 9 ' 997 ARCo Alaska,/nc ..... Post Office Box * _Ancfloran,~., 100360 AUgust 28, I997 Mr. David j. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation 300I Porcupine Drive Commission Anchorage, Alaska 99501 Subject: 1E-33 ~-J " [5 [ Dear Mr. Commissioner: Enclosed please find a L for Kuparuk ~ OT inform~,:_ ell 1~ ~ plot, co~.A . th~s Well Prior to * ~ese forms ~_ detail and t~ coo& ~~ ~ ~CO be,;-_, are to sa,o~- "~ Casin~ detail sheets ~',mng annul .... "~Y AOGc~ ~~ If there are any ques~ons, please C~1263-4183. vvrat~ons, q f ~ [9 p ~ uiSpos~ o .... ~ s request for Sincerely, D. Petrash Drilling Engineer Kuparuk Drill Site Development DKP/skad cc: Blair WOndzell RECEIVED 0,3 t99 .~Jaska 0il & ~as Cons. ~ommi~sion Anchorago ARCO Alaska, inc. Cementing Details Well#: 1 E-33 Field: Kuparuk River Unit Date: 8/26/97 Casing Size Hole Diameter KOP & Angle I Shoe Depth Float Depth % washout 9-5/8" 12-1/4" 575' - 530I 5481' 5391 ~entralizers State type used, intervals covered and spacing 29 Gemoco Bow Spring Centralizers: One on each of first 27 joints, 1st two on stop rings in middle of float joints; One on stop ring in middle of joint on each side of Gemoco Stage Cementing Collar. Mud Weight PV(prior cond) PV(after cond) IYP(prior cond) YP(after cond) 9.8 ppg 21 1 6I 20 1 2 Gels before Gels after Total Volume Circulated _ 6/8 4/5 Stg 1' 921 Bbls / Stg2' 232 Bbls Spacer Type Volume J Weight Water 50 Bbls / 20 Bbls 8.34 ppg Lead Type J Mix wtr temp No. of sacks J Weight Yield Cement AS ill LWJ _+75° F 210 sx / 307 sxJ 10.5 ppg 4.42 cfs Additives' Class G + 3.5% D44 + 0.60% D46 + 30% D53 + 1.5% D79 + 50% D124 + 1.5% S1 Tail Type JMix water temp No. of sacks J Weight Yield Cement ClassG&ASIJ _+75° F 650 sx / 60 sxJ 15.8 / 15.7 1.15 / 0.93 Additives: Stage 1' Class G + 0.266% D29 + 0.2% D46 + 0.3% D65 + 1% S1 Stage 2' Arctic Set 1 Displacement Rate(before tail at shoe) Rate(tail around shoe) Str. Wt. Up 7.0 BPM / 6,8 BPM 7.0 BPM / 6,1 BPM 270K# Reciprocation length Reciprocation speed Str. Wt. Down _+1 2' _+45 FPM 1 70K# Theoretical Displacement Actual Displacement Str. Wt. in mud 405.5 Bbls / 138.2 Bbls 405.2 Bbls / 139,6 Bbls 186K# Calculated top of cement I CIP Bumped plug I Floats held Cemented to Surface 2015, 8/26 Yes Yes Remarks- Include whether full returns were obtained, reciprocation throughout operation and any other pertinent information. 1st Stage: 5 Bbls water, test lines 4000 psi, 50 Bbls water, Mix & Pump 165 Bbls Lead, drop ,bypass plug, Mix & Pump 122.5 Bbls Class G Tail, drop top shut-off plug, pump 10 Bbls Tail on t.op of plug, pump 20 Bbls wash-up water, rig pump 375.5 Bbls mud & bumped plug to 1700 psi, floats held. Full returns. Reciprocated until 120 Bbls Lead cement had rounded the shoe. 1st Stage ClP @ 1800 hrs, 8/26/97. 2nd Stage: Opened Stage Cementing Tool @ 1823' with 3000 psi, circulate annulus clean, circulated out _+85 Bbls contaminated mud & cement, circulated 232 Bbls. Pump 20 Bbls water, Mix & Pump 10.5 ppg Lead cement until getting good 10.5 ppg cement returns, pumped 242 Bbls Lead, switch to Tail & pump 10 Bbls AS 1, drop top closing plug, pump 20 Bbls wash-up water, rig pump 119.6 Bbls mud & bumped plug, pressured up & closed stage collar @ 1450 psi, pressure up & hold 1800 psi, floats held, full returns. 2nd Stage ClP @ 2015 hrs, 8/26/97. Cement Company Rig Contractor Signature ~' Dowell Parker Rig #245 Don E. Breeden CASING / TUBING / LINER DETAIL 9-5/8" Surface Casino WELL: 1 E-33 KRU ARCO Alaska, Inc. DATE: 8/26/97 Subsidiary of Atlantic Richfield Company 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH TOPS Above RKB -4.74 Landing Joint 45.82 -4.74 FMC Fluted Mandrel Casing Hanger 4.1 2 41.08 41 Jts 9-5/8", 40#, L-80, BTC, Range 3, Class A Casing 1 734.70 45.20 Joint 'B' 9-5/8", 40#, L-80, BTC, Range 3, Class A Casing - Baker Locked 43.24 1 779.90 Gemoco 754 PDC Cementing Stage Tool 2.77 1 823.14 Joint 'A' 9-5/8% 40#, L-80, BTC, Range 3, Class A Casing - Baker Locked 42.50 1 825.91 83 Jts 9-5/8", 40#, L-80, BTC, Range 3, Class A Casing 3479.25 1 868.41 Gemoco Insert Shut-Off Baffle 5347.66 1 Jt 9-5/8", 40#, L-80, BTC, Range 3, Class A Casing 43.1 4 5347.66 Gemoco Float Collar 1.52 5390.80 2 Jts 9-5/8", 40#, L-80, BTC, Range 3, Class A Casing 86.99 5392.32 Gemoco Float Shoe 1.58 5479.31 Bottom of Shoe ==>> 5480.89 I TD = 5496' MDi (15' Rathole)~ BakerLock thru Float Collar, plus Stage Collar 29 BOw Sprin.o Centralizers: Install a Centralizer on each of the first 27 Joints, Install a Centralizer in the middle of Joints 'A' & 'B: (Put Centralizers on Stop Rings in middle of Jts #1, 2, 'A ; & 'B') Run Stage Cementing Collar ( Jts 'A' & 'B') between joints #86 & #87, Run Fluted Hanger on top of Joint #127. .Leave 13 Joints in the Shed (Jts #128 thru #140). Remarks: String Weights with Blocks: 270K# Up, 170K# Dn, 75K# Blocks. Ran 129 joints of casing. Drifted casing with 8.679" plastic rabbit & hanger with 8.525" rabbit. Used National Arctic Grade APl Modified No Lead thread compound on all connections (National = BOL 2000). Torqued to the base of the triangle stamp. Parker Ri~7 #245 Drilling7 Supervisor: Don E. Breeden CASING AND LEAK-OFF FRACTURE TESTS Well Name: Supervisor: 1 E-33 KRU Date: 8/27/97 Don E. Breeden 9-5/8", 40#, L-80, BTC Casing Size and Description: Casing Setting Depth' Mud Weight: 8.4 5481' TMD 3999' TVD PPg EMW --- Leak-off Pressure (PLO). + MW 0.052 x TVD EMW = 1025 psi/(0.052 x 3999 ft) + 8.4 ppg Drilled 8-1/2" hole to 5516' MD. EMW= 13.3ppg Pumped 2.6 Bbls. 2100 2000 1900 1800 1700 1600 1500 1400 1300 1200 1100 1000 900 800 700 600 500 400 300 200 100 0 0 I I Down (8 l I)25 )s, ' I'l:l.i...i_l.l.l;I_1 I -- --,-- LEAK-OFF TEST ~ CASING TEST -- i i i i i I 2 4 6 8 10 12 4 16 18 20 22 24 26 28 30 32 34 36 38 40 STROKES 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 August 8.1997 Michael Zanghi, Drilling Superintendent ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 1E-33 ARCO Alaska, Inc. Permit No: 97-151 Sur. Loc.: 126'FSL, 227'FEL, Sec. 16, T11N, R10E. UM Btmhole Loc: 2233'FNL. 2182'FWL. Sec. 23, T11N, R10E. UM Dear Mr. Zanghi: Enclosed is the approved application for permit to drill the above referenced xvell. 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. This approval includes annular disposal of drilling wastes and is contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT) - cementing records. FIT data. and any CQLs are to be submitted to the Commission prior to the start of disposal operations. Blo~vout prevention equipment (BOPE) must be tested in accordance ~vith 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field 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 Envinornment Conservation w/o encl. STATE OF ALASKA AL~,,',A OIL AND GAS CONSERVATION COMMIS~UN PERMIT TO DRILL 2O AAC 25.OO5 la. Type of Work Drill X Redrill [] I lb Type of Well Exploratory [] Stratigraphic Test [] Development Oil X Re-Entry [] Deepen []I Service [] OevelopmentGas [] Single Zone X Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 41' Pad 67' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchoracje, 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) 126' FSL, 227' FEL, Sec. 16, T11N, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1776' FNL, 693' FWL, Sec. 23, T11N, R10E, UM 1E-33 #U-630610 At total depth 9. Approximate spud date Amount 2233' FNL, 2182' FWL, Sec. 23, T11N, R10E, UM 8/1 3/97 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TV•) property line 1 E-25 10981' MD 693'@ Target feet 14' @ 725' feet 2560 6243' TVD feet 16, To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 575' feet Maximum hole angle 53/9 0 Maximum surface 3562 psig At total depth (TVD) 3900 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include sta~e dataI 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' _+200 CF 12.25" 9.625" 40.0# L-80 BTC-ER~ 5456' 41' 41' 5497' 4000' 1620 Sx Arcticset III & 550 Sx Class G 8.5" 7" 26.0# L-80 BTCMOE 8959' 41' 41' 9000' 61 04' 70 Sx ClassG Top 500' above shoe 6.125" 4.5" 12.6# L-80 NSCT 2181' 8800' 5990' 10981' 6243' 190 Sx ClassG 19, To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk(measured)ORIGINAL true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate ro uc,io Liner "~' i~) ~; Perforation depth: measured true vertical 20. Attachments Filing fee X Property plat BI BOP Sketch X Diverter Sketch . ¥ r, ,. ~rilling program~ X Drilling fluid program X Time vs depth plot [] Refraction analysis [] Seabed report [] -20 AAC 25;050'¢'equiri~men[s X 21' I hereby certify thai,/iIi°~ true and c°rrect t° the best °f my kn°wledge Signed Title Drilling Superintendent Date For questions~ please call Denise Petrash ~ Commission Use Only Permit Number APl number I Approval d I See cover letter for ?7 -/~""'// 50- O,~..¢"'" ,~.--'--~--. ,~ 7 ~I aC __~.~, ¢ 7I other requirements Conditions of approval Samples required ~ Yes J~ No Mud Icg required ~ Yes ,,~ No Hydrogen sulfide measures J~ Yes [~ No Directional survey required 'J~ Yes ~ No Required workingpressureforBOPE r-~ 2M [] 3M ~ 5M [] 10M [] 15M Other: dr~r..j~nal Signed By Approved by David W. J0h.s'[0r~ by order of ~ ~'L .,~ Commissioner the commission Date -- Form 10-401 Rev. 7-24-89 Submit in triplicate GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD KRU 1 E-33 1. Move in and rig up Parker #245. 2. Install diverter system. 3. Drill 12.25" hole to 9-5/8" surface casing point (5,497')according to directional plan. 4. Run and cement 9-5/8" casing, using stage collar placed at least 200' below the base of the permafrost, and light weight lead cement. 5. Install and test BOPE to 5000 psi. Test casing to 2000 psi. 6. Drill out cement and 10' of new hole. Perform formation integrity test, taken to leak off if possible, maximum pressure allowed 16.0 ppg EMW. 7. Drill 8.5" hole to intermediate TD (9,000') according to directional plan. 8. Run and cement 7" intermediate casing string. Note: If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. 9. Test breaks in BOPE to 5000 psi. Test casing to 3500 psi. 10. Drill out cement and 10' of new hole. Perform formation integrity test, taken to leak off if possible, maximum pressure allowed 16.0 ppg EMW. 1 1. Drill 6-1/8" pilot hole to total depth (9,272') according to directional plan. 1 2. Run open hole electric line evaluation logs as needed. 1 3. P&A pilot hole section from formation TD to 7" intermediate casing shoe. 1 4. Kick off below 7" casing shoe and drill horizontal section to total depth (10,981) according to directional plan, running LWD logging equipment as needed. 15. Run and cement 4-1/2" NSCT liner with Baker liner-top hanger and integral PBR. Set +_200' inside intermediate casing shoe to provide appropriate liner lap. 1 6. Run Baker 'FAB-1° packer with seal assembly. Sting into liner PBR and set packer. Pressure test liner to 3500 psi. 1 7. Run completion assembly. Latch PBR and seal assembly into FAB-1 packer. Pressure test tubing and annulus. 1 8. ND BOPE and install production tree. 19. Shut in and secure well. 20. Clean location and RDMO in preparation for coiled tubing cleanout and perforating. ¢~....¢~..~ Note: Perforating strategy is still being decided. This well may be tubing-conveyed perforated ~.;,--~ ~3; ' ~'~' with Parker 245. ~..,~¢r~ Note: As a dedicated producer, cased hole cement bond logs (SLT-J or CBT) will not be run unless the cement job requires evaluation. DRILLING FLUID PROGRAM Well KRU 1E-33 Spud to 9-5/8" surface casing Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids 9.0-10.0 15-25 15-35 50-80* 5-15 15-4O 10-12 9.5-10 +_10% Drill out to 7" interm, casing 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes- Drill out to TD 12.5 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.O33. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 2,368 psi could be reached. Maximum anticipated surface pressure is calculated using a intermediate casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3,562 psi could be reached. Therefore, ARCO Alaska, Inc. will do a one-time test of the BOP equipment to 5000 psi, retesting only broken flanges or after 7 day limit. The nearest existing well to 1 E-33 is 1 E-25. As designed, the minimum distance between the two wells would be 14.0' @ 725' MD. Drilling Area Risks: Risks in the 1 E-33 drilling area include lost circulation and high pressures in the Kuparuk formation. Both are addressed by setting intermediate casing above the Kuparuk. Careful analysis of pressure data from offset wells shows that a mud weight of 12.5 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 9-5/8" and 7" casing shoes will be tested to leak-off, or to a maximum equivalent mud weight of 16.0 ppg upon drilling out of the casing. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. ANNULAR PUMPING OPERATIONS WELL KRU 1E-33 Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of an existing well. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non- freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 1E-33 surface/production casing annulus will be filled with diesel after setting the production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations on significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover the formation. It is requested that 1 E-33 be permitted for annular pumping occurring as a result of drilling operations, per proposed regulations 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating any annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Please reference the enclosed directional drilling plan for other formation markers in this well. A list of all publicly recorded wells within 1/4 mile of the disposal operation is included in this permit application. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoes will be set +200' vertical below the base of the West Sak into the heart of the shales. The maximum volume of fluids pumped down the annulus of this well will not exceed 35,000 bbls without the specified permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1500 psi, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1500 psi Max Pressure = 3996 psi The pressure is very conservative as frictional losses while pumping are not accounted for. The surface and production casing strings exposed to the annular pumping operations are determined to have sufficient strength by using the 85% collapse and burst ratings listed below. OD Wt Conx Collapse 85% of Burst 85% of (in) (Ib/ft)Grade Range Type (psi) Collapse (psi) Burst 9.625 40 L-80 3 BTC 3090 2627 5750 4 8 8 8 7.000 26 L-80 3 BTC-M 5410 4 5 9 9 7240 6154 Fluids to be disposed of in subject annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.254 (g) (1). ARCO ALASKA, Inc. Pad 1E 33 slot #33 Kuparuk River Unit North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE REPORT Baker Hughes INTEQ Your ref : 33 Version #6 Our ref : prop2252 License : Date printed : 28-Jul-97 Date created : 7-May-97 Last revised : 28-Jul-97 Field is centred on nT0 16 18.576,w150 5 56.536 Structure is centred on nT0 18 1.316,w149 35 26.769 Slot location is n?0 18 2.555,w149 35 33.387 Slot Grid coordinates are N 5959715.568, E 550300.375 Slot local coordinates are 126.00 N 227.00 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 we11path GMS <O-7310'>,,30,Pad 1E GMS <O-7715'>,,16,Pad 1E G~MS <0-8017'>,,26A, Pad 1E MSS <2370-3605'>,,26,Pad 1E GMS <O-6835'>,,29,Pad 1E GMS <O-8754'>,,11,Pad 1E GMS <O-7811'>,,10,Pad 1E GMS <0-7000'>,,9,Pad 1E GMS <O-7590'>,,8,Pad 1E G~S <O-9310'>,,7,Pad 1E GMS <O-9837'>,,6,Pad 1E GMS <O-7195'>,,5,Pad 1E GMS <0-9150'>,,4,Pad 1E Gg~S <0-8905'>,,3,Pad 1E GMS <O-8440'>,,2,Pad 1E MSS <2819-7345'>,,1,Pad 1E GMS <O-7310'>,,1A, Pad 1E TOTCO Sur-~ey,,WS-2,Pad 1E GMS <0-7665'>,,28,Pad 1E GMS <0-6800'>,,27,Pad 1E GMS <O-7467'>,,25,Pad 1E GMS <O-8350'>,,23,Pad 1E GMS <O-9480'>,,22,Pad 1E GMS <O-7420'>,,21,Pad 1E GMS <0-8650'>,,20,Pad 1E Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 9-Jul-97 417.4 20.0 9-Jul-97 617.4 575.0 25-Jun-97 74.8 520.0 4-Aug-92 74.8 520.0 25-Jun-97 455.0 0.0 4-Aug-92 987.9 160.0 4-Aug-92 1082.0 600.0 4-Aug-92 1189.2 20.0 4-Aug-92 969.2 600.0 4-Aug-92 864.6 575.0 4-Aug-92 763.3 0.0 4-Aug-92 665.2 420.0 4-Aug-92 575.6 0.0 4-Aug-92 486.4 875.0 4-Aug-92 441.8 20.0 4-Aug-92 412.7 20.0 4-Aug-92 412.7 20.0 4-Aug-92 996.5 4060.0 4-Aug-92 516.0 575.0 4-Aug-92 598.9 180.0 4-Aug-92 14.0 725.0 4-Aug-92 88.4 1425.0 4-Aug-92 130.1 1075.0 4-Aug-92 224.2 625.0 4-Aug-92 283.9 480.0 575.0 575.0 520.0 520.0 0.0 160.0 600.0 20.0 600.0 575.0 0.0 20.0 20.0 4060.0 .... 725.0 ........ ~25.0 ~00.0 625.0 ~80.0 QMS <0-7898~>,,19,i QMS <0-8150~>,,18,Pad 1E QMS <O-7885'>,,17,Pad 1E QMS <0-8435~>,,15,Pad 1E QMS <O-?190~>,,14,Pad gMS <O-7750~>,,13,Pad 1E QMS <O-7512~>,,12,Pad 1E QMS <O-7420~>,,24,Pad 1E PMSS <121 - ?????">,,B(32),Pad 1E -Aug- 92 -Aug- 92 -Aug- 92 -Aug- 92 -Aug- 92 -Aug- 92 -Aug- 92 -Aug- 92 22-Jul- 97 345.0 405.0 594.6 667.1 727.9 806.8 893.1 42.6 588.4 20.0 20.0 520.0 320.0 575.0 575.0 575.0 440.0 600.0 20.0 20.0 520.0 560.0 575.0 575.0 575.0 440.0 600.0 5OO lOP0 1500 2000 _CZ 2500 3000 -q~ ~ 3500 400O 4500 5000- 55OO 6OO0 Ic~te~ ~ ~.~ For: D PETRASH Dote plotted: 29-Ju[-97 F~o[ Re[erence is ~ Ve~on Coordinotes ore in feet r~erence JTma Vedicol Oep~~ mB (Pa~er ~245). A2C0 ALASKA, Inc. Structure : Pod 1E Well : 33 Field : Kuporuk River Unit Locofion : North Slope, Alosko 6500 East (feet) -> 500 1000 1500 2000 2500 .3000 .3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I u Permofrost · 1776' FNL, 69,3' FWL lid SEC. 23, T11N, RlOE SURFACE LOCATION: I ~ TARGET 126' FSL, 227' FEL [ ~p West Sok TWn--~o~n SEC. 16, T11N, RIOEI aos. West. So~-'~---.~..~ 9 5/8 Cesing "~-~--~---~---~.~._Companion SS DEP=6485 1~C60 SOUTH 1902 EAST 6200 Bose HRZ p C4 1E-33 (C3#4) 13-Jul-97 0 RKB ELEVATION: 108' 1E-33 (C3 Toe) Rvsd 13-Jul-g7 500 6/3 50O 0 1000 .-i- 1500 I V 2000 250O K0P TVD=575 TMI)=575 DEP=O TD LOCATION: 5.00 2233' FNU 2182' FWL 9.00 107.06 AZIMUTH SEC. 23, T11N, RIOE 15 O0 DLS' 3 O0 deg per 100 ft ~1.00 ' ' 6485 (TO TARGET) '~ 27.00 k 53 O0 B/ PERMAFROST TVD=1558 TMD=1608 DEP=272 Rk 39.00 ",% 45.00 ~ 51.00 ENO ANGLE BULL0 W0=2100 TM0=2341 0EP=760 ~ ~ ***NOTE*** ~ I SEE PAGE 2 FOR PILOT ~ [ HOLE CONTINUATION AND AVERAGE ANGLE~ I H02IZONTAL SECTION 52.98 DEG ~SAK W0=3318 TMD=4364 DEP=2375 ~ ~WSIO (B/ W SAK) W0=3800 TMD=5164 DEP=3014 O ~/~" rcr DT ~/n~nn ~n--~ov nc~ovo~c100 9 5/8" CSG PT ~D~D=5497 DER=3~9 ~ ~90 CAMP.SS. WD=4216 TMD=5855 DEP=3566~ ~-10) C50 TARGET ANGLE (K-S) 56.00 ~"~ TARGET T/ C3 TVD=6210 TMD=9423 DEP=6485 ,(.ICJ 4 !99)' A~a"[''''~' i I i i I I i i i i ! i i i i i i i I I i i i i I i i 0 500 1000 1500 2000 2500 5000 5500 4000 4500 5000 5500 6000 6500 Verficel Section (fed) -> Azimuth 107.06 with reference 0.00 N, 0.00 E from slot #33 c,eot~ ~x a.e~ For: D PETRASH Dote plot[ed: 29-Jul-97 Fqot Reference is 33 Version ~6. C~r~n~tes ere in feet r~erence ~at T~e Vertical Oep~s~~8 (Po~ ~243). ARCO ALASKA, Inc. Structure : Pad 1E Well : 55 Field : Kuporuk River Unit Locofion : North Slope, Alosko East (feet) -> 5250 5400 5550 5700 5850 6000 6150 6300 6450 6600 6750 6900 7050 7200 7350 7500 7650 7800 I I I I I I I I I t I I I I I I I I I I I I I I I I ~ I I I I I I I I "~C30 (K-2) I 1776' FNL, 693' FWL -'"'~C20 (HRZ Mid Pt) I SEC. 2.3, T11N, RI OE Bose HRZ ~ Belgian Angle Build TARGET K-1 M a r k e r ~-~._-Co si._n g .... TVD=6210 -----...~op ~,up u,+ TMD=9423 ~ ~ DEP=6485 * V E~R~A~GoE 52.98 DEG 1E-33 (C3 Toe) Rvsd 13-Jul-97 1500 1650 1800 1950 '-~ --I- 2100 I 225O 24OO 107.06 AZIMUTH 6485' (TO TARGET) TO LOCATION: 223.3' FNL, 2182' FWL SEC. 23, T11N, RIOE PILOT HOLE ANGLE ~7oo ~ ~ END OF BUILD WD=6095 P~0T TD ~D=6243 65o0 TARGET ANGLE 90.1 DEG i i i i t i i ~ i i i i i i i i i i i i i i i i i i i i ~ i i i i i i i 5550 5700 5850 6000 6150 6500 6450 6600 6750 6900 7050 7200 7550 7500 7650 7800 7950 81 O0 Verffcol Sectfon (feet) -> Azimuth 107.06 with reference 0.00 N, 0.00 E from slot I/.53 ICreoted by fi.cb For: D PETRASH gate plotted : 2g-Jul-g7 Plot Rcf~rmnce is 33 V~rsion ~/6. Coordinotes ore in feet reference slot ~33. True Vertical Depths o~RK8 (Porker /J245). Pa 1:~5----- Field : Kuparuk River Unit Location : North Slope, Alaska 160 120 8O 4O ,'-", 4O 0 120 I V ~6o 200 240 280 320 360 East (feet) -> 80 40 0 40 80 120 160 200 240 280 320 360 400 4¢0 480 520 560 600 640 680 720 760 I I I I I I I I I I t I I I [ I I I I I I I I I I I I I I I I I I I I I I I I I I 160 500 ~..~ 120 000 ~ 80 -% oo -~2oo ~ ~1 14~?0 1500 O0 ¢1000 1900~ ....... --]~.~. ...... ~ 0 .~.oo ............ 200 ........ _!,~o /1500 x 3:O0 2100~ .... ~-~ 2¢0 1 ~00 ~ 700~ 220~ 1 gOO 280 320 i i i i i i i i t i i i i I I I I I I t I I I I I I I I I I I I I t I I I I I I I 56O 80 40 0 40 80 120 160 200 240 280 ~20 560 400 440 480 520 560 600 640 680 720 760 Eosf (feet) -> 40 o 8O 120 I ~6o V 7 , 6 I 5 4 I II 13 5/8" 5000 BOP STACK 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. 16"- 2000 PSI STARTING HF_AD 2. 11"- 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI VARIABLE PIPE RAMS 5. 19-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. TEST ANNULAR PREVENTOR TO 3000 PSI ONLY. 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. TESTTO 250 PSI AND 5000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOWAND 5000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 5000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 5000 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 5000 PSI FOR 3 MINUTES. 12. TEST KELLY COCKS AND INSIDE BOP TO 5000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. NOTE' PRIOR TO DRILLING OUT OF THE INTERMEDIATE CASING SHOE ALL FLANGES AND SEALS BROKEN BETWEEN THIS TEST AND THE PRIOR ONE WILL BE TESTED TO 250 PSI LOW AND 5000 PSI HIGH ,~UPARUK RIVER UN~ 1' 20" DIVERTER SCHEMATIC 6 4 3 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. . MAINTENANCE & OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16"CONDUCTOR. 2. SLIP-ON WELD STARTING HEAD. 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE. 4. 20" - 2000 PSI DRILLING SPOOL WITH ONE 16" OUTLET. 5. ONE 16" HCR KNIFE VALVE WITH 16" DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20" - 2000 PSI ANNULAR PREVENTER. DKP 11/9/94 · WELL PERMIT CHECKLIST COMPANY . .,~,,'-¢,,..~ WELL NAME/~ FIELD & POOL ~.~r"2.,/ ~ INIT CLASS /~/,,.z..., .,/..-~ ., // GEOL AREA PROGRAM: exp [] dev/,~redrll [] serv [] wellbore seg ['J ann. disposal para req~,, UNIT# //,/~' ~ ON/OFF SHORE c~,~L..) ADMINISTRATION 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 ENGINEERING APPR DATE 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 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 ........ ~ N 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... Y N Adequate wellbore separation proposed ............. (~ N If diveder required, does it meet regulations .......... N Drilling fluid program schematic & equip list adequate ..... (~ N BOPEs, do they meet regulation ................ (~ N BOPE press rating appropriate; test to -~O orb psig. N Choke manifold complies w/APl RP-53 (May 84) ........ (~ N Work will occur without operation shutdown ........... (~) N Is presence of H2S gas probable ................. (~) N GEOLOGY 31. Data presented on potential overpressure zones ....... . . 32. Seismic analysis of shallow gas zones ............. 33. Seabed condition survey (if off-shore) ............. J Y N 34. Contact name/phone for we.eklypro~lress reDo. ds ..... J. Y N lexp~orarory omyj REMARKS GEOLOGY: RP. t ENGINEERING: COMMISSION: JDH .~ RNC Comments/Instructions: HOW/Ijt - A:\FORMS\cheklist rev 07/97 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. Sperry-Sun Drilling Services LIS Scan Utility Wed Oct 08 15:18:04 1997 Reel Header Service name ............. LISTPE Date ..................... 97/10/08 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments .................. STS LIS Writing Library. Technical Services Tape Header Service name ............. LISTPE Date ..................... 97/10/08 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... ~OWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT ~4D/~D LOGS WELL N~E: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NITMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TO%~NSHIP: RANGE: FNL: FSL: FEL: FWL: MWD RUN 2 AK-MM-70247 K. FERGUSON D. BREEDEN ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 500292279770 ARCO A~AS~, INC. SPERRY-S~ DRILLING SERVICES 08-OCT-97 MWD RUN 3 AK-MM-7 0247 P. SMITH D. BREEDEN 16 lin 10E 126 227 108.20 108.20 67.10 Dato~ WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 9.625 5480.0 8.500 7.000 8997.0 6.125 9505.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL ONLY AND IS NOT PRESENTED. 3. MWD RUN 2 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) . 4. ~TD RUN 3 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4) . 5. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9505'MD, 6376'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 (S~ALLOW 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 ....... 97/10/08 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. .5000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR ROP FET RPD RPM RPS RPX $ START DEPTH 5451 5 5494 0 8987 5 8987 5 8987 5 8987 5 8987 5 STOP DEPTH 9432 0 9505 5 9439 0 9439 0 9439 0 9439 0 9439 0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH 5451 8910 8912 8914 8916 8919 8922 8926 8930 8981 8982 8984 8998 9004 9010 9013 9015 9016 9020 9021 9023 9026 9028 9029 9032 9038 9040 9042 9047 9050 9052 9071 9072 9074 9083 9085 9089 9098 9106 9108. 9114 9116 9120 9121 9124 9129 9134 9157 9160 9162 9166 9169 9172 9190 9194 9195 9197 9199 9205 GR 5455 8914 8916 8918 8921 8924 8927 8930 8934 8983 8985 8987 9003 9007 9010 9012 9015 9018 9023 9026 9028 9031 9032 9033 9039 9042 9044 9046 9052 9055 9058 9075 9077 9078 9088 9091 9093 9101 9110 9112 9117 9120 9122 9126 9129 9133 9137 9161 9162 9164 9169 9172 9174 9193 9195 9196 9199 9200 9207 9208 5 9210 0 9230 5 9236 0 9237 5 9241 0 9243 0 9247 0 9251 5 9259 5 9267 0 9272 0 9296 0 9319 5 9329 5 9340 0 9343 0 9350 0 9352 9367 9377 9387 9401 9405 9409 9505 MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: 9210 0 9212 0 9233 0 9237 0 9240 0 9243 5 9245 5 9249 0 9253 5 9260 0 9268 5 9273 5 9297 0 9322.0 9331.5 9343.5 9345.5 9351.5 9354 0 9371 0 9379 5 9389 0 9402 0 9406 5 9409 5 9505 5 BIT RUN NO MERGE TOP MERGE BASE 2 5498.0 9013.0 3 9013.0 9505.0 MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Legging Directien ................. Down Optical leg depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per recerd ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR ~D AAPI 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMH 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 Naille DEPT ROP GR RPX RPS RPM RPD FET Min 5451.5 9 8475 28 9479 0 1678 0 1225 0 1231 0 0643 0 5809 Max Mean Nsam 9505.5 7478.5 8109 639.844 237.679 8024 437.75 115.836 7962 83.733 12.3975 904 2000 14.829 904 2000 51.9699 904 2000 20.5829 904 59.8083 4.46723 904 First Last Reading Reading 5451.5 9505.5 5494 9505.5 5451.5 9432 8987.5 9439 8987.5 9439 8987.5 9439 8987.5 9439 8987.5 9439 First Reading For Entire File .......... 5451.5 Last Reading For Entire File ........... 9505.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/08 Maximum Physical Record..65535 File Type ................ LO Next File N~me ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/08 Maximum Physical Record..65535 File Type ................ LO Previeus File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUM~RY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 5455.5 8970.5 ROP 5498.0 9012.0 $ LOG HEADER DATA DATE LOGGED: SOF~ARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: II 2.17F DATA TYPE (MEMORY OR REAL-TIME): 29-AUG-97 ISC 5.06 CIM 5.46/SP4 5.03/DEP MEMORY TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VIENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (O~) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 9013.0 5498.0 9013.0 51.1 58.3 TOOL NUMBER P0827CG6 8.5OO 8.5 LSND 176.90 42.0 9.0 45O 6.2 .000 .000 .000 .000 52.2 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 AAPI 4 1 68 4 2 ROP MWD 2 FT/H 4 1 68 8 3 Name Min Max Mean Nsam DEFT 5455.5 9012 7233.75 7114 GR 41. 6744 437.75 120. 113 7031 ROP 25.1075 639.844 258.327 7029 First Last Reading Reading 5455.5 9012 5455.5 8970.5 5498 9012 First Reading For Entire File .......... 5455.5 Last Reading Fer Entire File ........... 9012 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8939 0 9432.0 FET 8991 0 9439 0 RPD 8991 0 9439 0 RPM 8991 0 9439 0 RPS 8991 0 9439 0 RPX 8991 0 9439 0 ROP 9013 5 9505 5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: II 2.17F DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): 31-AUG-97 ISC 5.O6 CIM 5.46/SP4 5.03/DEP MEMORY 9505.0 TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMIC) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: b~D 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 T!rpe .................. 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 9013.0 9505.0 57.1 58.3 TOOL NUMBER P0669SP4 P0669SP4 6.130 6.1 LSND 230.80 48.0 9.0 35O 4.8 4.900 3.144 6.000 6.100 50.0 .6 Name Service Order Units Size Nsam Rep Code Offset Channel DEFT FT 4 1 68 0 1 GR MWD 3 A_AP1 4 1 68 4 2 RPX MWD 3 OHMM 4 1 68 8 3 RPS MIa~D 3 OHMI~ 4 1 68 12 4 RPM MIgD 3 O~ 4 1 68 16 5 RPD }~WD 3 0~M 4 1 68 20 6 ROP MWD 3 FET MWD 3 FT/H 4 1 68 HOUR 4 1 68 24 28 Na/ae DEPT GR RPX RPS RPM RPD ROP FET Min 8939 28 9479 0 1678 0 1225 0 1231 0 0643 9 3847 0 5809 Max Mean Nsam 9505.5 9222.25 1134 241.14 83.1669 987 83.733 12.3859 897 2000 14.8951 897 2000 58.936 897 2000 22.8613 897 309.535 90.2866 985 59.8083 4.04459 897 First Reading 8939 8939 8991 8991 8991 8991 9013.5 8991 Last Reading 9505.5 9432 9439 9439 9439 9439 9505.5 9439 First Reading For Entire File .......... 8939 Last Reading For Entire File ........... 9505.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/10/08 Origin ................... STS Tape Name ................ UNKNO~ ' Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 97/10/08 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNO~ Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File Sperry-Sun Drilling Services LIS Scan Utility Fri Oct 10 13:59:57 1997 Reel Header Service name ............. LISTPE Date ..................... 97/10/10 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... %rNKNOK~ Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 97/10/10 Origin ................... STS Tape Name ................ UNKNOWN Centinuation Number ...... 01 Previeus Tape Name ....... UNKNO~N Cemments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS WELL N~E: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: gate~ ----"---- 1E-33 500292279700 ARCO A~ASKA, INC. SPERRY-SUI~ DRILLING SERVICES 10-OCT-97 OCT 1 5 'i997 Oil & Gts C~i',s. ,;"::~.~,~,,-ni~.:~:i~, MWD RUN 2 AK-MM-70247 K. FERGUSON D. BREEDEN MWD RUN 3 AK-MM-7 0247 P. SMITH D. BREEDEN MWD RUN 4 AK-MM-70247 B. HENNINGSE D. LUTRICK JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 AK-MM-70247 B. HENNINGSE D. LUTRICK MWD RUN 5 AK-MM-70247 S. BURKHARDT D. LUTRICK MWD RUN 5 AK-MM-7 0247 S. BURKHARDT D. LUTRICK JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION MWD RUN 6 AK-MM-70247 B. HENNINGSE D. LUTRICK MWD RUN 6 AK-MH-70247 B. HENNINGSE D, LUTRICK SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 16 liN 10E 126 227 108.60 108.60 67.10 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (PT) 12 . 250 9 . 625 5480 . 0 8.500 7.000 8997.0 6 . 125 10951 . 0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ANNULAR HYDRAULICS ARE CALCULATED USING THE POWER LAW MODEL. 3. MP~D RUN 1 IS DIRECTIONAL ONLY AND IS NOT PRESENTED. '4. MWD RUN 2 IS DIRECTIONAL WITH DUAL G~kMMA RAY (DGR) . 5. MWD RUNS 3 THROUGH 6 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4). 6. ONLY GAMMA RAY DATA (SGRC) UTILIZED FROM MWD RUN #3. 7. DURING MWD RUN 5 THE CALIBRATION OF THE 4 PHASE ELECTRO-MAGNETIC WAVE RESISTIVITY TOOL SHIFTED DUE TO DOWNHOLE DAMAGE. THE DATA FROM 10,070'MD TO 10,609'MD (6241'TVD TO 6255'TV D) HAS BEEN REPROCESSED WITH NEW CALIBRATION FACTORS OBTAINED AFTER RUN 5. 8. MEASURMENT AFTER DRILLING (MAD} PASSES WERE PERFORMED AFTER MWD RUNS 4-6. THE DATA IS PRESENTED AT THE END OF THIS LOG. 9. THIS WELL REACHED A TOTAL DEPTH (TD) oF 10951'MD, 6278'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 FORb~TION EXPOSURE TIME. SRAT = SMOOTHED TOOL SPEED WHEN NOT DRILLING. CURVES WITH AN "M" EXTENTION ARE MEASURED AFTER DRILLING (MAD). $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/10 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. .5000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR ROP PET RPD RPM RPS RPX $ START DEPTH 5451 5 5494 0 9006 0 9006 0 9006 0 9006 0 9006 0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 5451 5 8910 5 8912 0 8914 5 8916 5 8919 5 8922 0 8926 5 8930 5 8981 0 8982.5 8984.5 8998.5 9004.5 10947.5 $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD $ RE~ZLARKS: GR 5455 5 8914 5 8916 5 8918 5 8921 0 8924 5 8927 0 8930 5 8934 0 8983 5 8985 5 8987 5 9003 5 9007 5 10950 5 STOP DEPTH 10905 5 10947 5 10912 5 10912 5 10912 5 10912 5 10912 5 EQUIVALENT UNSHIFTED DEPTH -- # Data Format Specification Record Data Record Type .................. 0 MERGED MAIN PASS. $ BIT RUN NO MERGE TOP MERGE BASE 2 5498.0 9009.0 3 9012.0 9505.0 4 9009.0 9888.0 5 9888.0 10655.0 6 10655.0 10951.0 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 DEPT ROP GR RPX RPS RPM RPD FET Name Service Order Units Size Nsam Rep FT 4 1 68 MWD FT/H 4 1 68 Nf~D AAP I 4 1 68 M~D OHMM 4 1 68 MWD OHM~ 4 1 68 MWD OHMM 4 1 68 M~D OHMM 4 1 68 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 5451.5 10947.5 8199.5 10993 ROP 4.9528 639.844 215.124 10908 GR 23.2942 437.75 99.1639 10909 RPX 1.8947 100.85 38.1789 3814 RPS 1.8857 82.4266 38.2084 3814 RPM 2.083 2000 41.9846 3814 RPD 2.3815 2000 52.3802 3814 FET 0.3502 29.9062 2.58928 3814 First Reading 5451.5 5494 5451.5 9006 9006 9006 9006 9006 Last Reading 10947 5 10947 5 10905 5 10912 5 10912 5 10912 5 10912 5 10912 5 First Reading For Entire File .......... 5451.5 Last Reading For Entire File ........... 10947.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/10 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 ....... 97/10/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; passes. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR FET RPD RPM RPS RPX RAT $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: .5000 START DEPTH 9201.5 9208.0 9208.0 9208.0 9208.0 9208.0 9252.0 all MAD runs merged using earliest STOP DEPTH 10906 0 10913 0 10913 0 10913 0 10913 0 10913 5 10948 0 MAD RUN NO. MAD PASS NO. 4 5 6 MERGED MAD 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 DEPT FT 4 1 RAT MAD FT/H 4 1 GR MAD AAPI 4 1 RPX MAD OHMM 4 1 RPS MAD OHM~ 4 1 RPM MAD OHMH 4 1 RPD MAD OHMM 4 1 FET MAD OHMM 4 1 MERGE TOP 9009.0 9888.0 10655.0 MERGE BASE 9888.0 10655.0 10951.0 Rep Code Offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 Name Min Max Mean DEPT 9201.5 10948 10074.8 RAT 36.5625 2119.23 370.177 GR 22.1061 146.317 53.1432 RPX 2.661 91.7072 41.1695 RPS 2.825 72.6071 40.4657 First Last Nsam Reading Reading 3494 9201.5 10948 3393 9252 10948 3410 9201.5 10906 3412 9208 10913.5 3411 9208 10913 RPM 3.13 2000 44.6021 3411 RPD 3.5603 2000 56.5113 3411 FET 4.371 62.4746 21.3085 3411 9208 10913 9208 10913 9208 10913 First Reading For Entire File .......... 9201.5 Last Reading For Entire File ........... 10948 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 # - FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 5455 . 5 8970 . 5 ROP 5498 , 0 9008 . 5 $ LOG HEADER DATA DATE LOGGED: 29 -AUG- 97 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: II 2.17F DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 9009,0 TOP LOG INTERVAL (FT) : 5498.0 BOTTOM LOG INTERVAL (FT) : 9009.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 51 . 1 MAXII~JI~ ANGLE: 58 . 3 ISC 5,06 CIM 5,46/SP4 5.03/DEP TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: I~LATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefine~ Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 TOOL NUMBER P0827CG6 8.500 8.5 LSND 176.90 42.0 9.0 450 6.2 .000 .000 .000 .000 52.2 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 AAPI 4 1 68 4 2 ROP MWD 2 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 5455.5 9008.5 7232 7107 5455.5 GR 41.6744 437.75 120.113 7031 5455.5 ROP 25.1075 639.844 258.295 7022 5498 Last Reading 9008.5 8970.5 9OO8.5 First Reading For Entire File .......... 5455.5 Last Reading For Entire File ........... 9008.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8971 . 0 9008 . 5 $ · LOG HEADER DATA DATE LOGGED: 31-AUG- 97 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: II 2.17F DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 9505.0 TOP LOG INTERVAL (FT) : 9012.0 BOTTOM LOG INTERVAL (FT) : 9505.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 57 . 1 MA~XIMUM ANGLE: 58 . 3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL G~IA RAY EWR4 ELECTROMAG. RESIS. $ BOREHOLE AND CASING DATA ISC 5.~6 CIM 5.46/SP4 5.03/DEP TOOL NUMBER P0669SP4 P0669SP4 OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 6.130 6.1 LSND 230.80 48.0 9.0 35O 4.8 4.900 3.144 6.000 6.100 .6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 3 AAPI 4 1 68 4 2 50.0 First Name Min Max Mean Nsam Reading DEPT 8971 9008.5 8989.75 76 8971 GR 64.7562 111.167 79.9376 76 8971 Last Reading 9008.5 9008.5 First Reading For Entire File .......... 8971 Last Reading For Entire File ........... 9008.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date o[ Generation ....... 97/10/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/10 Maximum Physical Record..65535 File Type ................ LO Previeus File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BlT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SLPPLARY VENDOR TOOL CODE START DEPTH FET RPD RPM RPS RPX GR ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 9009.0 9009 0 9009 0 9009 0 9009 0 9009 0 9009 0 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: II 2.17F DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 9842 0 9842 0 9842 0 9842 0 9842 0 9835 9888 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL G~qA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE ~qD CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 06-SEP-97 ISC 5.06 CIM 5.46/SP4 5.03/DEP MEMORY 9888.0 9009.0 9888.0 63.6 91.5 TOOL NUMBER P0669SP4 P0669SP4 6.130 6.1 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHlV~4) 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): RE[~RKS: $ 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 LSND 234.60 61.0 10.0 300 3.1 2.150 1.292 1.800 3.400 .6 Name Service Order Units Size Nsam DEPT FT 4 1 GR MWD 4 AAPI 4 1 RPX MWD 4 OHN~4 4 1 RPS MWD 4 OHMM 4 1 RPM MWD 4 OHPIM 4 1 RPD MWD 4 OHlViM 4 1 ROP MWD 4 FT/H 4 1 FET MWD 4 HOUR 4 1 Rep Code Offset Channel 68 ' 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 49.5 Name Min Max Mean DEPT 9009 9888 9448.5 GR 32.7783 242.2 78.0123 RPX 1.8947 82.4625 26.495 RPS 1.8857 82.4266 26.9653 RPM 2.083 2000 33.6859 RPD 2.3815 2000 47.887 ROP 4.9528 457.91 133.423 FET 0.4427 5.601 1.27929 First Last Nsam Reading Reading 1759 9009 9888 1653 9009 9835 1667 9009 9842 1667 9009 9842 1667 9009 9842 1667 9009 9842 1759 9009 9888 1667 9009 9842 First Reading For Entire File .......... 9009 Last Reading For Entire File ........... 9888 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NLTMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR FET RPD RPM RPS RPX ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 9830 0 9840 0 9840 0 9840 0 9840 0 9840 0 9880 0 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: II 2.17F DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10602 0 10609 0 ' 10609 0 10609 0 10609 0 10609 0 10654 5 08-SEP-97 ISC 5.06 CIM 5.46/SP4 5.03/DEP MEMORY 10655.0 9888.0 10655.0 85.9 91.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH-(FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHPR4) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ...... ~ .......... Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lIN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 TOOL NUMBER P0669SP4 P0669SP4 6.130 6.1 LSND 234.60 61.0 10.5 3OO 2.8 2.400 1.253 1.700 3.100 51.7 .6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR I~TD 5 AAPI 4 1 68 4 2 RPX MWD 5 OHNIM 4 1 68 8 3 RPS MWD 5 0 HIf~4 4 1 68 12 4 RPM MWD 5 OHMM 4 1 68 16 5 RPD MWD 5 OHMM 4 1 68 20 6 ROP MWD 5 FT/H 4 1 68 24 7 FET MWD 5 HOUR 4 1 68 28 8 First Last Name Min Max Mean Nsam DEPT 9830 10654.5 10242.2 1650 GR 23.2942 77.7104 47.0155 1545 RPX 20.1794 100.85 50.0108 1539 RPS 24.481 81.5922 49.6736 1539 RPM 27.238 78.6373 51.9 1539 RPD 33.75 98.7833 58.5848 1539 ROP 6.3721 563.044 146.146 1550 FET 0.4357 28.6516 2.95583 1539 Reading 9830 9830 9840 9840 9840 9840 9880 9840 Reading 10654.5 10602 10609 10609 10609 10609 10654.5 10609 First Reading For Entire File .......... 9830 Last Reading For Entire File ........... 10654.5 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER · FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NIIMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10600 0 FET 10605 0 RPD 10605 0 RPM 10605 0 RPS 10605 0 RPX 10605 0 ROP 10650 0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: STOP DEPTH 10908.5 10915 5 10915 5 10915 5 10915 5 10915 5 10950 5 09-SEP-97 ISC 5.06 DOWNHOLE SOFTWARE VERSION: II 2.17F DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT sIZE (IN): DRILLER'S CASING DEPTH (FT) BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OH14M) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type ' 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 CIM 5.46/SP4 5.03/DEP MEMORY 10951.0 10655.0 10951.0 84.7 87.6 TOOL NUMBER P0715SP4 P0715SP4 6.130 6.1 LSND 234.60 69 .0 9.6 4OO 2.8 2.200 1.356 2 .100 1.700 49 .5 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 6 AAPI 4 1 68 4 2 RPX MWD 6 RPS MWD 6 RPM MWD 6 RPD MWD 6 ROP MWD 6 FET MWD 6 OHMM 4 1 68 OHFiM 4 1 68 OHMM 4 1 68 OHMM 4 1 68 FT/H 4 1 68 HOUR 4 1 68 8 12 16 20 24 28 NaIne DEPT GR RPX RPS RPM RPD ROP FET Min 10600 28 7894 22 3911 23 4483 21 4795 27 6197 12 2097 0 3502 Max Mean Nsam 10950.5 10775.2 702 77.0925 48.7359 618 67.2432 40.4995 622 59.703 40.1517 622 59.3707 39.7263 622 75.146 49.1319 622 350.341 130.592 602 29.9062 5.76822 622 First Reading 10600 10600 10605 10605 10605 10605 10650 10605 Last Reading 10950 5 10908 5 10915 5 10915 5 10915 5 10915 5 10950 5 10915 5 First Reading For Entire File .......... 10600 Last Reading For Entire File ........... 10950.5 File Trailer Service n~me ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF File Header Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUIqNUMBER: 4 MAD PASS NUMBER: FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9204.5 9833.5 FET 9211 0 RPD 9211 0 RPM 9211 0 RPS 9211 0 RPX 9211 0 RAT 9255 0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: II 2.17F DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: I~uXXIMUM ANGLE: 9839.0 9840.0 9840.0 9840.0 9840.0 9886.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STA~NDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. Data Speci[ication Block Type 06-SEP-97 ISC 5.06 CIM 5.46/SP4 5.03/DEP MEMORY 9888.0 9009.0 9888.0 63 .6 91.5 TOOL NUMBER P0669SP4 P0669SP4 6.130 6.1 LSND 234.60 61.0 10.0 '300 3.1 2.150 1.292 1.800 3.400 49.5 .6 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 DEPT GR RPX RPS RPM RPD RAT FET Name Service Order Units Size Nsam Rep FT 4 1 68 MAD 4 AAPI 4 1 68 MAD 4 OHMM 4 1 68 I~LAD 4 OHNiM 4 1 68 MAD 4 OHMM 4 1 68 MAD 4 OHl~4 4 1 68 MAD 4 FT/H 4 1 68 MAD 4 OHMM 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 9204.5 9886 9545.25 1364 GR 30.0606 146.317 62.9226 1259 RPX 2.661 91.7072 34.2912 1259 RPS 2.825 72.6071 33.8264 1259 RPM 3.13 2000 43.0776 1259 RPD 3.5603 2000 63.5366 1259 RAT 36.5625 1873.83 316.242 1263 FET 11.6894 29.1979 19.7331 1257 First Reading 9204.5 9204.5 9211 9211 9211 9211 9255 9211 Last Reading 9886 9833.5 9840 9840 9840 9840 9886 9839 First Reading For Entire File .......... 9204.5 Last Reading For Entire File ........... 9886 File Trailer Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.009 Physical EOF File Header Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.008 Comment Record FILE HEADER FILE NUMBER: 9 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: MAD RUN NUMBER: MAD PASS .NUMBER: FILE SUMMARY .5000 5 VENDOR TOOL CODE START DEPTH GR 9768.5 FET 9773.5 RAT 9814.5 RPD 9840.5 RPM 9840.5 RPS 9840.5 RPX 9840.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: II 2.17F DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10603 5 10609 5 10656 0 10609 5 10609 5 10609 5 10609 5 08-SEP-97 ISC 5.06 CIM 5.46/SP4 5.03/DEP MEMORY 10655.0 9888.0 10655.0 85.9 91.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ TOOL NUMBER P0669SP4 'P0669SP4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 6.130 6.1 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: LSND 234.60 61.0 10.5 30O 2.8 2.400 1.253 1.700 3 .100 51 .7 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMJIRKS: $ 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 .6 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MAD 5 AAPI 4 1 68 RPX MAD 5 O~M 4 1 68 RPS MAD 5 OH~IM 4 1 68 RPM MAD 5 OHNIM 4 1 68 RPD MAD 5 O~M 4 1 68 RAT IfLAD 5 FT/H 4 1 68 FET MhD 5 OHNIM 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 9768.5 10656 10212.2 1776 GR 22.1061 81.0392 47.8722 1671 RPX 19.4139 88.7257 48.5022 1539 RPS 20.5625 68.7252 47.1577 1539 RPM 20.2822 70.4096 48.7889 1539 RPD 25.761 74.5117 54.6323 1539 RAT 41.1673 2119.23 422.035 1684 FET 9.6294 63.6075 28.2081 1673 First Reading 9768 5 9768 5 9840 5 · 9840 5 9840 5 9840 5 9814 5 9773 5 Last Reading 10656 10603.5 10609.5 10609.5 10609.5 10609.5 10656 10609.5 First Reading For Entire File .......... 9768.5 Last Reading For Entire File ........... 10656 File Trailer Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.010 Physical EOF File Header Service n~me ............. STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/10 Maximum Physical Record..65535 File Type ................ LO Previeus File Name ....... STSLIB.009 Comment Record FILE HEADER FILE NUMBER: 10 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 6 MAD PASS NUMBER: FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10532.0 FET 10539.0 RPD 10539.0 RPM 10539.0 RPS 10539.0 RPX 10539.0 RAT 10578.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: II 2.17F DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIPKgM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS }~D TYPE: I~3D DENSITY (LB/G): STOP DEPTH 10909 0 10916 0 10916 0 10916 0 10916 0 10916 5 10951 0 09-SEP-97 ISC 5.06 CIM 5.46/SP4 5.03/DEP 'MEMORY 10951.0 10655.0 10951.0' 84.7 87.6 TOOL NUMBER P0715SP4 P0715SP4 6.130 6.1 LSND 234. 60 MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 69.0 9.6 400 2.8 2.200 1.356 2.100 1.700 .6 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MAD 6 AAPI 4 1 68 RPX MAD 6 OHMM 4 1 68 RPS MAD 6 OHMM 4 1 68 RPM MAD 6 OHMM 4 1 68 RPD MAD 6 OHMM 4 1 68 RAT MAD 6 FT/H 4 1 68 FET MAD 6 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 '16 5 20 6 24 7 28 8 49.5 Name Min Max Mean DEPT 10532 10951 10741.5 GR 23.3031 69.5964 46.7569 RPX 20.817 68.2578 39.2114 RPS 23.2185 57.7835 39.2828 RPM 21.044 59.3829 39.1346 RPD 26.2255 73.2161 48.8894 RAT 77.5943 455.345 359.274 FET 4.371 47.9842 20.6412 Nsam 839 755 756 755 755 755 746 755 First Reading 10532 10532 10539 10539 10539 10539 10578.5 10539 Last Reading 10951 10909 10916.5 10916 10916 10916 10951 10916 First Reading For Entire File .......... 10532 Last Reading For Entire File ........... 10951 File Trailer Service name ............. STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.011 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/10/10 Origin ................... STS Tape Name ................ IINKNOWN Continuation Number ...... 01 Next Tape Name ........... UlqKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 97/10/10 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 * ALASKA COMPUTING CENTER * . , ***~*****~*****************~** * ............................ . ....... SCHLUMBERGER ....... * ............................ . R CE VED SEP 2.9 1997 ............................ *~aska 0;; & Gas Corns. Comm/a~ COMPANY NAME : ARCO ALASKA, INC. WELL NAME : 1E-33 FIELD NAlVlE : KUPARUK RIVER UNIT BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-22797-00 REFERF~CE NO : 974 O1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-SEP-1997 10:25 PAGE: **** REEL HEADER **** SERVICE NA~iE : EDIT DATE : 97/09/23 ORIGIN · FLIC REEL NA~E : 97401 CONTINUATION # : PREVIOUS REEL : COF~iENT : ARCO ALASKA INC, 1E-33, KUPARUKRIVER, API #50-029-22797-00 **** TAPE HEADER **** SERVICE NAM~ : EDIT DATE : 97/09/23 ORIGIN : FLIC TAPE NAFiE : 97401 CONTINUATION # : 1 PREVIOUS TAPE COMFiF2F~ : ARCO ALASKA INC, 1E-33, KUPARUK RIVER, API #50-029-22797-00 TAPE HEADER Kuparuk River Unit OPEN HOLE WIRELINE 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: ELEVATION(FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: RUN1 97401 E. Bartz D. LUTRICK WELL CASING RECORD 1ST STRING 2ND STRING 1E-33 500292279700 ARCO ALASKA, INC. SCHLUMBERGER WELL SERVICES 23-SEP-97 RUN 2 RUN 3 16 liN iOE 126 227 108.00 67.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.125 7. 000 8997.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-SEP-1997 10:25 3RD STRING PRODUCTION STRING CONTAINED HEREIN IS THE LDWG FORMATTED DATA ACQUIRED ON ARCO ALASKA'S 1E-33 WELL. THESE LOGS ARE CONSIDERED TO BE THE PRIMARY DEPTH CONTROL LOGS FOR THIS WELL. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER: 1 EDITED OPEN HOLEMAIN PASS Ail tool strings; Depth shifted and clipped curves; all runs merged; no cased hole data. DEPTH INCREMENT: 0.5000 FILE SUM~IARY LDWG TOOL CODE DAS SDN CNTG $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH ..................... 9469.0 8997.0 9445.0 8997.0 9430.0 8997.0 BASELINE DEPTH .............. $ FiERGED DATA SOURCE LDWG TOOL CODE .............. $ REMARKS: THIS FILE CONTAINS THE MAIN PASS OPENHOLE LOGS THAT HAVE BEEN CLIPPED TO REMOVE INVALID READINGS. NO DEPTH CORRECTIONS HAVEBEENAPPLIED TO THESE LOGS. $ .......... EQUIVALENT UNSHIFTEDDEPTH .......... DAS SDN CNTG ..................... RUN NO. PASS NO. FiERGE TOP f4ERGE BASE LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-SEP-1997 10:25 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 2 3 4 5 66 6 73 7 65 8 68 9 65 11 66 12 68 13 66 14 65 15 66 16 66 0 66 __ 66 0 66 0 73 88 66 1 0.5 FT 11 0 FT 68 1 0 ** SET TYPE - CHA1V ** NAFiE SERV UNIT SERVICE API API API API FILE ND?4~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1022689 O0 000 TENS DAS LB 1022689 O0 000 GR DAS GAPI 1022689 O0 000 DT DAS US/F 1022689 O0 000 DTSH DAS US/F 1022689 O0 000 SCRADAS 1022689 O0 000 RHOB SDN G/C3 1022689 O0 000 PEF SDN BN/E 1022689 O0 000 DRHO SDN G/C3 1022689 O0 000 CALl SDN IN 1022689 O0 000 NPHI CNTG PU-S 1022689 O0 000 CPHI CNTG ' PU-S 1022689 O0 000 CRAT CNTG 1022689 O0 000 NRAT CNTG 1022689 O0 000 ClFTC CNTG CPS 1022689 O0 000 CFTC CNTG CPS 1022689 O0 000 NCNT CNTG CPS 1022689 O0 000 FCNT CNTG CPS 1022689 O0 000 ENPH CNTG PU-S 1022689 O0 000 ENRA CNTG 1022689 O0 000 CFEC CNTG CPS 1022689 O0 000 CNEC CNTG CPS 1022689 O0 000 O0 0 1 1 1 4 68 0000000000 O0 0 1 1 1 4 68 0000000000 O0 0 1 1 1 4 68 0000000000 O0 0 1 1 1 4 68 0000000000 O0 0 1 1 1 4 68 0000000000 O0 0 1 1 1 4 68 0000000000 O0 0 1 1 1 4 68 0000000000 O0 0 1 1 1 4 68 0000000000 O0 0 1 1 1 4 68 0000000000 O0 0 1 1 1 4 68 0000000000 O0 0 1 1 1 4 68 0000000000 O0 0 1 1 1 4 68 0000000000 O0 0 1 1 1 4 68 0000000000 O0 0 1 1 1 4 68 0000000000 O0 0 1 1 1 4 68 0000000000 O0 0 1 1 1 4 68 0000000000 O0 0 1 1 1 4 68 0000000000 O0 0 1 1 1 4 68 0000000000 O0 0 1 1 1 4 68 0000000000 O0 0 1 1 1 4 68 0000000000 O0 0 1 1 1 4 68 0000000000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-SEP-1997 10:25 PAGE: ** DATA ** DEPT. 9498.000 TENS.DAS 4232.000 GR.DAS DTSH.DAS -999.250 SCRA.DAS -999.250 RHOB.SDN DRHO.SDN -999.250 CAL1.SDN -999.250 NPHI. CNTG CRAT. CNTG -999.250 NRAT. CNTG -999.250 CNTC. CNTG NCNT. CNTG -999.250 FCNT. CNTG -999.250 ENPH. CNTG CFEC. CNTG -999.250 CNEC. CNTG -999.250 DEPT. 8997.000 TENS.DAS 3686.000 GR.DAS DTSH.DAS 196.479 SCRA.DAS 1.977 RHOB.SDN DRHO.SDN -0.643 CAL1.SDN 6.351 NPHI. CNTG CRAT. CNTG 3.980 NRAT. CNTG 3.990 CNTC. CNTG NCNT. CNTG 1730.202 FCNT. CNTG 387.064 ENPH. CNTG CFEC. CNTG 489.121 CNEC. CNTG 2876.215 -999.250 DT.DAS -999.250 PEF. SDN -999.250 CPHI.CNTG -999.250 CFTC. CNTG -999.250 ENRA.CNTG 80.931 DT.DAS 1.947 PEF. SDN 54.650 CPHI.CNTG 1686.322 CFTC. CNTG 44.491 ENRA.CNTG -999.250 -999.250 -999.250 -999.250 -999.250 99.362 -46.444 51.686 426.058 5.880 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE~ER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED CASED HOLE MAIN PASS Depth shifted and clipped curves for open hole logs run into casing. PASS NUM~ER: 1 DEPTH INCREIVlENT: 0.5000 FILE SUlVlPIARY LDWG TOOL CODE START DEPTH DAS 8997.0 CNTG 8997.0 STOP DEPTH 8907.0 8907.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-SEP-1997 10:25 PAGE: $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) .......... EQUIVALENT UNSHIFTEDDEPTH .......... BASELINE DEPTH DAS CNTG $ REMARKS: THIS FILE CONTAINS THE MAIN PASS DATA THAT WAS ACQUIRED IN CASING. THERE WERE NO DEPTH CORRECTIONS APPLIED TO THIS DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 72 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 14 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAFIE SERV UNIT SERVICE API API API API FILE NUMB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELE~ CODE (HEX) DEPT FT 1022689 O0 000 O0 0 2 1 1 4 68 0000000000 TENS DAS LB 1022689 O0 000 O0 0 2 1 1 4 68 0000000000 GRCHDAS GAPI 1022689 O0 000 O0 0 2 1 1 4 68 0000000000 DT DAS US~Fl022689 O0 000 O0 0 2 1 1 4 68 0000000000 DTSH DAS US/F 1022689 O0 000 O0 0 2 1 1 4 68 0000000000 SCRA DAS 1022689 O0 000 O0 0 2 1 1 4 68 0000000000 NPHI CNTG PU-S 1022689 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-SEP-1997 10:25 PAGE: NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NU~B SAMP ELE~ CODE (HEX) CPHI CNTG PU-S 1022689 O0 000 O0 0 2 1 1 4 68 0000000000 CRAT CNTG 1022689 O0 000 O0 0 2 1 1 4 68 0000000000 N-RAT CNTG 1022689 O0 000 O0 0 2 1 1 4 68 0000000000 CNTC CNTG CPS 1022689 O0 000 O0 0 2 1 1 4 68 0000000000 CFTC CNTG CPS 1022689 O0 000 O0 0 2 1 1 4 68 0000000000 NCNT CNTG CPS 1022689 O0 000 O0 0 2 1 1 4 68 0000000000 FCNTCNTG CPS 1022689 O0 000 O0 0 2 1 1 4 68 0000000000 ENPH CNTG PU-S 1022689 O0 000 O0 0 2 1 1 4 68 0000000000 ENRA CNTG 1022689 O0 000 O0 0 2 i 1 4 68 0000000000 CFECCNTG CPS 1022689 O0 000 O0 0 2 1 1 4 68 0000000000 CNEC CNTG CPS 1022689 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 8997~000 TENS.DAS 3686.000 GRCH.DAS 80.931 DT. DAS DTSH.DAS 196.479 SCRA.DAS 1.977 NPHI.CNTG 54.650 CPHI.CNTG CRAT. CNTG 3.980 NRAT. CNTG 3.990 CNTC. CNTG 1686.322 CFTC. CNTG NCNT. CNTG 1730.202 FCNT. CNTG 387.064 ENPH. CNTG 44.491 ENRA.CNTG CFEC. CNTG 489.121 CNEC. CNTG 2876.215 DEPT. 8907.000 TENS.DAS 3703.000 GRCH.DAS 82.193 DT.DAS DTSH.DAS 255.216 SCRA.DAS 2.455 NPHI.CNTG 51.254 CPHI.CNTG CRAT. CNTG 3.791 NRAT. CNTG 4.040 CNTC. CNTG 1693.642 CFTC. CNTG NCNT. CNTG 1655.369 FCN~f. CNTG 421.457 ENPH. CNTG 42.713 ENRA.C~G CFEC. CNTG 496.009 CNEC. CNTG 2841.254 99.362 51.686 426.058 5.880 103.973 48.152 453.305 5.728 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE . FLIC VERSION : O01CO1 DATE : 97/09/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-SEP-1997 10:25 PAGE: **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : RUN NDWiBER : TOOL STRING NUM~ER: PASS NUMBER: DEPTH INC~: FILE SUF~L~RY FILE HEADER FILE NUM~ER 3 RAW OPEN HOLEMAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. 1 1 1 0.5000 VENDOR TOOL CODE START DEPTH STOP DEPTH DSI 9498.0 8997.0 LDT 9498.0 8997.0 CNTG 9498.0 8997.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TI~IE CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) V~NDOR TOOL CODE TOOL TYPE GR GAM~IA RAY CNTG COMP. NEUTRON LDT LITHODENSITY DSI DIPOLE SONIC $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT) : 1-SEP-97 8C0-609 400 1-SEP-97 1330 3-SEP-97 9505.0 9500.0 8907.0 9498.0 1800.0 TOOL NUMBER SGT-L CNT-G LDT-D DSST-A 6.125 8997.0 8997.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-SEP-1997 10:25 PAGE: BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 12.60 MUD VISCOSITY (S) : 48.0 MUD PH: 9.0 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : 147.0 RESISTIVITY (OH~) AT TEMPERATURE (DEGF): MUD AT f4EASURED TEMPERATURE (MT): 3. 770 MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): 2. 828 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): 5. 655 MUD CAKE AT (BHT): 66.0 66.0 66.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): E P I THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): 1.0 REMARKS: ALL TOOLS RUN IN COMBINATION W/SONIC ON BOTTOM AS PER CLIENT REQUEST. SIX .5" STANDOFFS RUN ON SONIC / TWO .5" STANDOFFS RUN ON THE HEAD. HOLEFINDER RUN ON BOTTOM OF THE SONIC. TWO TOOL TURNERS RUN ON STRING IN ORDER TO ORIENT NUCLEAR TOOLS. RIG TOOK A GAS KICK AND HAD TO INCREASE MUD WEIGHT FROM 12.0 TO 12.6 LB/GAL. 18% SOLIDS IN MUD; 15~ BARITE DRASTICALLY AFFECTED DENSITY PEF. DENSITY CORRECTION NEGATIVE DUE TO BARITE. SANDSTONE MATRIX MBEN=2.65 G/CC USED FOR ALL POROSITY CORRECTIONS. HAD A TOUGH TIME GETTING PAST 9170'. RIG MADE A WIPER TRIP. VERY DIFFICULT TO GET DOWN EVEN AFTER WIPER TRIP. PULLED MAIN PASS FROM TD TO CSG FIRST. COULD NOT GET PAST 9432 FOR REPEAT PASS. LOGGED REPEAT FROM 9432' AFTER REPEATED ATTEMPTS TO GET DOWN. CA~iE OUT OF HOLE STICKING SEVERAL TIMES. ALL LOGS DID REPEAT.****12 FT. ADDED FOR STRETCH CORRECTION. * * * * * THIS FILE CONTAINS THE RAW OPENHOLE MAIN PASS. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-SEP-1997 10:25 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 160 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 6 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAlVlE SERV UNIT SERVICE API API API API FILE AU3BIB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 1022689 O0 000 O0 0 3 1 1 4 68 0000000000 TENS DSI LB 1022689 O0 000 O0 0 3 1 1 4 68 0000000000 GR DSI GAPI 1022689 O0 000 O0 0 3 1 1 4 68 0000000000 PR DSI 1022689 O0 000 O0 0 3 1 1 4 68 0000000000 RSHC DSI 1022689 O0 000 O0 0 3 1 i 4 68 0000000000 DT2 DSI US/Fl022689 O0 000 O0 0 3 1 1 4 68 0000000000 DT4P DSI US/F 1022689 O0 000 O0 0 3 1 1 4 68 0000000000 DRHOLDT G/C3 1022689 O0 000 O0 0 3 1 1 4 68 0000000000 LSRHLDT G/C3 1022689 O0 000 O0 0 3 1 1 4 68 0000000000 LURHLDT G/C3 1022689 O0 000 O0 0 3 1 1 4 68 0000000000 PEF LDT 1022689 O0 000 O0 0 3 1 1 4 68 0000000000 QLS LDT 1022689 O0 000 O0 0 3 1 1 4 68 0000000000 QSS LDT 1022689 O0 000 O0 0 3 1 1 4 68 0000000000 RHOB LDT G/C3 1022689 O0 000 O0 0 3 1 1 4 68 0000000000 DPHILDT PU 1022689 O0 000 O0 0 3 1 1 4 68 0000000000 S1RHLDT G/C3 1022689 O0 000 O0 0 3 1 1 4 68 0000000000 LSHVLDT V 1022689 O0 000 O0 0 3 1 1 4 68 0000000000 SSHVLDT V 1022689 O0 000 O0 0 3 1 1 4 68 0000000000 LL LDT CPS 1022689 O0 000 O0 0 3 1 1 4 68 0000000000 LU LDT CPS 1022689 O0 000 O0 0 3 1 1 4 68 0000000000 LS LDT CPS 1022689 O0 000 O0 0 3 1 1 4 68 0000000000 LITHLDT CPS 1022689 O0 000 O0 0 3 1 1 4 68 0000000000 SSI LDT CPS 1022689 O0 000 O0 0 3 1 1 4 68 0000000000 SS2 LDT CPS 1022689 O0 000 O0 0 3 1 1 4 68 0000000000 CALI LDT IN 1022689 O0 000 O0 0 3 1 1 4 68 0000000000 RTNR CNTG 1022689 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-SEP-1997 10:25 PAGE: 10 NAME SERVUNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD ND?4B SAMP ELEM CODE (HEX) ENRA CNTG 1022689 O0 000 O0 0 3 1 1 4 68 0000000000 RCNTCNTG CPS 1022689 O0 000 O0 0 3 1 1 4 68 0000000000 RCFTCNTG CPS 1022689 O0 000 O0 0 3 1 1 4 68 0000000000 RCENCNTG CPS 1022689 O0 000 O0 0 3 1 1 4 68 0000000000 RCEF CNTG CPS 1022689 O0 000 O0 0 3 1 1 4 68 0000000000 CNTCCNTG CPS 1022689 O0 000 O0 0 3 1 1 4 68 0000000000 CFTC CNTG CPS 1022689 O0 000 O0 0 3 1 1 4 68 0000000000 T1FRA CNTG 1022689 O0 000 O0 0 3 1 1 4 68 0000000000 CNEC CNTG CPS 1022689 O0 000 O0 0 3 1 1 4 68 0000000000 CFEC CNTG CPS 1022689 O0 000 O0 0 3 1 1 4 68 0000000000 TNPH CNTG PU 1022689 O0 000 O0 0 3 1 1 4 68 0000000000 ENPH CNTG PU 1022689 O0 000 O0 0 3 1 1 4 68 0000000000 NPHI CNTG PU 1022689 O0 000 O0 0 3 1 1 4 68 0000000000 NPOR CNTG PU 1022689 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 9525.000 TENS.DSI 1024.000 GR.DSI RSHC.DSI 1.863 DT2.DSI 169.270 DT4P.DSI LSRH. LDT 2.453 LURJ~.LDT 2.458 PEF. LDT QSS.LDT 0.097 RtIOB.LDT 2.449 DPHI.LDT LSHV. LDT 1628.839 SSHV. LDT 1664.354 LL.LDT LS.LDT 297.352 LITH.LDT 18.225 SS1.LDT CALI.LDT 6.788 RTNR.CNTG 2.818 ENRA. CNTG RCFT. CNTG 1306.150 RCEN. CNTG 3275.149 RCEF. CNTG CFTC. CNTG 1447.052 TNRA. CNTG 2.660 CNEC. CNTG TNPH. CNTG 30.499 ENPH. CNTG 17.877 NPHI. CNTG DEPT. 8997.000 TENS.DSI 3686.000 GR.DSI RSHC.DSI 1.977 DT2.DSI 196.479 DT4P.DSI LSRH. LDT 2.592 LURH. LDT 2.445 PEF. LDT QSS.LDT 0.158 RHOB.LDT 1.947 DPHI.LDT LSHV. LDT 1680.059 SSHV. LDT 1663.571 LL.LDT LS.LDT 228.457 LITH. LDT 10.008 SS1.LDT CALI. LDT 6. 351 RTNR. CNTG 3. 990 ENRA. CNTG RCFT. CNTG 387. 064 RCEN. CNTG 2716. 253 RCEF. CNTG CFTC. CNTG 426. 058 TNRA. CNTG 3. 980 CNEC. CNTG TNPH. CNTG 51.686 ENPH. CNTG 44.491 NPHI.CNTG 84 967 90 838 -18 268 12 164 141 002 238 846 3.183 1065.429 3543.799 30.591 80.931 99.362 -46.444 42.618 68.563 105.341 5.880 468.000 2876.215 54.650 PR. DSI DRHO. LDT QLS. LDT S1RH. LDT LU. LDT SS2. LDT RCNT. CNTG CNTC. CNTG CFEC. CNTG NPOR. CNTG PR. DSI DRHO. LDT QLS. LDT S1RH. LDT LU. LDT SS2. LDT RCNT. CNTG CNTC. CNTG CFEC. CNTG NPOR. CNTG 0.298 0.002 -0.144 2.445 312.699 276.938 3782.010 3813.955 1113.313 30.499 0.328 -0.643 -0.454 3.766 319.789 120.175 1730.202 1686.322 489.121 49.817 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-SEP-1997 10:25 PAGE: 11 **** FILE TRAILER **** FILE NAM~ : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAM~ : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : RUN NUMBER: TOOL STRING NUMBER: PASS NUFiBER : DEPTH INC~: FILE SUIVlM_ARY FILE HEADER FILE~ER 4 RAW OPEN HOLEREPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. 1 1 2 0.5000 VENDOR TOOL CODE START DEPTH STOP DEPTH DSI 9439.0 8900.0 LDT 9439.0 8997.0 CNTG 9439.0 8997.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAi~4A RAY CNTG COMP. NEUTRON 1-SEP-97 8C0-609 400 1-SEP-97 1330 3-SEP-97 9505.0 9500.0 8907.0 9498.0 1800.0 TOOL NUMBER SGT-L CNT-G LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-SEP-1997 10:25 PAGE: 12 LDT L I THODENS I TY DSI DIPOLE SONIC $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): LD T- D DSST-A 6.125 8997.0 8997.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 12.60 MUD VISCOSITY (S) : 48.0 MUD PH: 9.0 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): 147.0 RESISTIVITY (OHPI~) AT TEMPERATURE (DEGF) : MUD AT MEAStrRED TEMPERATURE (MT): 3. 770 MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): 2. 828 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): 5. 655 MUD CAKE AT (BHT): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): EP I THERMAL SANDSTONE 2.65 66.0 66.0 66.0 TOOL STANDOFF (IN): 1.0 REMARKS: ALL TOOLS RUN IN CO~INATION W/SONIC ON BOTTOM AS PER CLIENT REQUEST. SIX .5" STANDOFFS RUN ON SONIC / TWO .5" STANDOFFS RUN ON THE HEAD. HOLEFINDER RUN ON BOTTOM OF THE SONIC. TWO TOOL TURNERS RUN ON STRING IN ORDER TO ORIENT NUCLEAR TOOLS. RIG TOOK A GAS KICK ANDHAD TO INCREASE MUD WEIGHT FROM 12.0 TO 12.6 LB/GAL. 18% SOLIDS IN MUD; 15~ BARITE DRASTICALLY AFFECTED DENSITYPEF. DENSITY CORRECTION NEGATIVE DUE TO BARITE. SANDSTONE MATRIXMDEN=2.65 G/CC USED FOR ALL POROSITY CORRECTIONS. HAD A TOUGH TI~E GETTING PAST 9170'. RIG MADE A WIPER TRIP. VERY DIFFICULT TO GET DOWN EVENAFTER WIPER TRIP. PULLED MAIN PASS FROM TD TO CSG FIRST. COULD NOT GET PAST 9432 FOR REPEAT PASS. LOGGED REPEAT FROM 9432' AFTER REPEATED ATTEMPTS TO GET DOWN. CAM~ OUT OF HOLE STICKING SEVERAL TIMES. ALL LOGS DID REPEAT.****12 FT. ADDED FOR STRETCH CORRECTION.***** THIS FILE CONTAINS THE RAW OPENHOLE REPEAT PASS. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-SEP-1997 10:25 PAGE: 13 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 160 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 6 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUMB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELE~ CODE (HEX) DEPT FT 1022689 O0 000 O0 0 4 1 1 4 68 0000000000 TENS DSI LB 1022689 O0 000 O0 0 4 1 1 4 68 0000000000 GR DSI GAPI 1022689 O0 000 O0 0 4 1 1 4 68 0000000000 PR DSI 1022689 O0 000 O0 0 4 1 1 4 68 0000000000 RSHC DSI 1022689 O0 000 O0 0 4 1 1 4 68 0000000000 DT2 DSI US/F 1022689 O0 000 O0 0 4 1 1 4 68 0000000000 DT4P DSI US/F 1022689 O0 000 O0 0 4 1 1 4 68 0000000000 DREO LDT ~/C3 1022689 O0 000 O0 0 4 1 1 4 68 0000000000 LSRH LDT G/C3 1022689 O0 000 O0 0 4 1 1 4 68 0000000000 LURH LDT G/C3 1022689 O0 000 O0 0 4 1 1 4 68 0000000000 PEF LDT 1022689 O0 000 O0 0 4 1 1 4 68 0000000000 QLS LDT 1022689 O0 000 O0 0 4 1 1 4 68 0000000000 QSS LDT 1022689 O0 000 O0 0 4 1 1 4 68 0000000000 RHOB LDT G/C3 1022689 O0 000 O0 0 4 1 1 4 68 0000000000 DPHI LDT PU 1022689 O0 000 O0 0 4 1 1 4 68 0000000000 S1RH LDT G/C3 1022689 O0 000 O0 0 4 1 1 4 68 0000000000 LSHV LDT V 1022689 O0 000 O0 0 4 1 1 4 68 0000000000 SSHV LDT V 1022689 O0 000 O0 0 4 1 1 4 68 0000000000 LU LDT CPS 1022689 O0 000 O0 0 4 1 1 4 68 0000000000 LU LDT CPS 1022689 O0 000 O0 0 4 1 1 4 68 0000000000 LS LDT CPS 1022689 O0 000 O0 0 4 1 1 4 68 0000000000 LITH LDT CPS 1022689 O0 000 O0 0 4 1 1 4 68 0000000000 SSI LDT CPS 1022689 O0 000 O0 0 4 1 1 4 68 0000000000 SS2 LDT CPS 1022689 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-SEP-1997 10:25 PAGE: 14 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) CALI LDT IN 1022689 O0 000 O0 0 4 1 1 4 68 0000000000 RTNR CNTG 1022689 O0 000 O0 0 4 1 1 4 68 0000000000 ENRA CNTG 1022689 O0 000 O0 0 4 1 1 4 68 0000000000 RCNT CNTG CPS 1022689 O0 000 O0 0 4 1 1 4 68 0000000000 RCFT CNTG CPS 1022689 O0 000 O0 0 4 1 1 4 68 0000000000 RCEN CNTG CPS 1022689 O0 000 O0 0 4 1 1 4 68 0000000000 RCEF CNTG CPS 1022689 O0 000 O0 0 4 1 1 4 68 0000000000 CNTCCNTG CPS 1022689 O0 000 O0 0 4 1 1 4 68 0000000000 CFTC CNTG CPS 1022689 O0 000 O0 0 4 1 1 4 68 0000000000 TNRA CNTG 1022689 O0 000 O0 0 4 1 1 4 68 0000000000 CNECCNTG CPS 1022689 O0 000 O0 0 4 1 1 4 68 0000000000 CFEC CNTG CPS 1022689 O0 000 O0 0 4 1 1 4 68 0000000000 TNPHCNTG PU 1022689 O0 000 O0 0 4 1 1 4 68 0000000000 ENPH CNTG PU 1022689 O0 000 O0 0 4 1 1 4 68 0000000000 NPHI CNTG PU 1022689 O0 000 O0 0 4 1 1 4 68 0000000000 NPOR CNTG PU 1022689 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. RSHC. DSI LSRH. LDT QSS. LDT LSHV. LDT LS. LDT CALI. LDT RCFT. CNTG CFTC. CNTG TNPH. CNTG 9439. 000 1. 846 2 478 -0 005 1627 288 303 451 6 079 1057 604 1171. 694 30.217 DEPT. 8887.000 RSHC.DSI 2.302 LSRH. LDT 2.888 QSS.LDT -0.097 LSHV. LDT 1627.000 LS.LDT 157.289 CALI.LDT 6.296 RCFT. CNTG 379.070 CFTC. CNTG 431.768 TNPH. CNTG 49.691 TENS. DSI 3104. 000 GR. DSI DT2.DSI 155. 279 DT4P.DSI LURH. LDT 2. 509 PEF. LDT RHOB.LDT 2. 435 DPHI.LDT SSHV. LDT 1667. 515 LU. LDT LITH. LDT 45. 235 SSI. LDT RTNR . CNTG 2. 778 ENRA . CNTG RCEN. CNTG 3375. 690 RCEF. CNTG TNRA. CNTG 2. 622 CNEC. CNTG ENPH. CNTG 22. 637 NPHI. CNTG TENS. D S I DT2. DSI LURH. LDT RHOB. LDT SSHV. LDT LITH. LDT RTNR. CNTG RCEN. CNTG TNRA. CNTG ENPH. ClVTG 3470.000 244.052 2.905 2 133 1669 198 14 809 4 165 2728 143 4 011 43.116 56. 235 PR. DSI 84.137 DRHO. LDT 11 996 QLS.LDT 13 031 S1RH. LDT 159 265 LU. LDT 215 144 SS2.LDT 3 724 RCNT. CNTG 938 681 CNTC. CNTG 3652.588 CFEC. CNTG 30.658 NPOR.CNTG GR.DSI 96. 676 PR.DSI DT4P. DSI 106.122 DRHO. LDT PEF. LDT -2423. 011 QLS.LDT DPHI. LDT 31.317 S1RH. LDT LU. LDT 74. 291 LU. LDT SSI. LDT 76.125 SS2. LDT ENRA. CNTG 5.762 RCNT. CNTG RCEF. CNTG 503.342 CNTC. CNTG CNEC. CNTG 2919. 891 CFEC. CNTG NPHI. CNTG 55. 288 NPOR. CNTG O. 292 -0. 038 -0. 005 2. 612 288. 373 281. 202 3001.201 3026. 550 980. 868 30.217 0.384 - O. 751 -0. 074 4 452 165 996 109 260 1631 290 1654 557 506 706 50. 002 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-SEP-1997 10:25 PAGE: 15 **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE · FLIC VERSION : O01CO1 DATE : 97/09/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE~ER **** FILE NAFIE : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~ER 5 RAW CASED HOLE MAIN PASS Curves and log header data for open hole logs run into casing. PASS AU3f4~ER: 1 DEPTH INC~: 0.5000 FILE SU~bLARY VENDOR TOOL CODE START DEPTH STOP DEPTH ..................................... DSI 8997.0 8907.0 LDT 8997.0 8907.0 CNTG 8997.0 8907.0 $ LOG HEADER DATA DATE LOGGED: 1-SEP- 97 SOFTWARE VERSION: 8C0- 609 TIM~ CIRCULATION ENDED: 400 1-SEP-97 TIM~ LOGGER ON BOTTOM: 1330 3-SEP-97 TD DRILLER (FT) : 9505.0 TD LOGGER (FT) : 9500.0 TOP LOG INTERVAL (FT) : 8907.0 BOTTOM LOG INTERVAL (FT) : 9498.0 LOGGING SPEED (FPHR): 1800.0 TOOL STRING (TOP TO BOTTOM) VF2FDOR TOOL CODE TOOL TYPE TOOL NUMBER GR GAM~A RAY SGT-L CNTG COMP. NEUTRON CNT-G LDT LITHODENSITY LDT-D DSI DIPOLE SONIC DSST-A LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-SEP-1997 10:25 PAGE: 16 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT) : 6.125 8997.0 8997.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 12.60 MUD VISCOSITY (S) : 48.0 MUD PH: 9.0 FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : 147.0 RESISTIVITY (OH~) AT TEMPERATURE (DEGF) : MUD AT F~=ASURED TEMPERATURE (MT): 3. 770 MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): 2. 828 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): 5. 655 MUD CAKE AT (BHT) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): E P I THERMAL SANDSTONE 2.65 66.0 66.0 66.0 TOOL STANDOFF (IN): 1.0 REMARKS: ALL TOOLS RUN IN COMBINATION W/SONIC ON BOTTOM AS PER CLIENT REQUEST. SIX .5" STANDOFFS RUN ON SONIC / TWO .5" STANDOFFS RUN ON THE HEAD. HOLEFINDER RUN ON BOTTOM OF THE SONIC. TWO TOOL TURNERS RUN ON STRING IN ORDER TO ORIENT NUCLEAR TOOLS. RIG TOOK A GAS KICK ANDHAD TO INCREASE MUD WEIGHT FROM 12.0 TO 12.6 LB/GAL. 18~ SOLIDS IN MUD; 15% BARITE DRASTICALLY AFFECTED DENSITY PEF. DENSITY CORRECTION NEGATIVE DUE TO BARITE. SANDSTONE MATRIX ~DEN=2.65 G/CC USED FOR ALL POROSITY CORRECTIONS. HAD A TOUGH TIFIE GETTING PAST 9170'. RIG MADE A WIPER TRIP. VERY DIFFICULT TO GET DOWN EVENAFTER WIPER TRIP. PULLED MAIN PASS FROM TD TO CSG FIRST. COULD NOT GET PAST 9432 FOR REPEAT PASS. LOGGEDREPEAT FROM 9432' AFTER REPEATED ATTEMPTS TO GET DOWN. CAFIE OUT OF HOLE STICKING SEVERAL TIMES. ALL LOGS DID REPEAT.****12 FT. ADDED FOR STRETCH CORRECTION.***** THIS FILE CONTAINS THE RAW MAIN PASS DATA ACQUIRED UP INTO CASING. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-SEP-1997 10:25 PAGE: 17 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 *~ SET TYPE - CHAN ** NAFIE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1022689 00 000 O0 0 5 1 1 4 68 0000000000 TENS DSI LB 1022689 O0 000 O0 0 5 1 1 4 68 0000000000 GR DSI GAPI 1022689 O0 000 O0 0 5 1 1 4 68 0000000000 PR DSI 1022689 O0 000 O0 0 5 1 1 4 68 0000000000 RSHC DSI 1022689 O0 000 O0 0 5 1 1 4 68 0000000000 DT2 DSI US/F 1022689 O0 000 O0 0 5 1 1 4 68 0000000000 DT4P DSI US/Fl022689 O0 000 O0 0 $ 1 1 4 68 0000000000 RTNR CNTG 1022689 O0 000 O0 0 5 1 1 4 68 0000000000 ENURA CNTG 1022689 O0 000 O0 0 5 1 1 4 68 0000000000 RCNT CNTG CPS 1022689 O0 000 O0 0 5 1 1 4 68 0000000000 RCFT CNTG CPS 1022689 O0 000 O0 0 5 1 1 4 68 0000000000 RCEN CNTG CPS 1022689 O0 000 O0 0 5 1 1 4 68 0000000000 RCDF CNTG CPS 1022689 O0 000 O0 0 5 1 1 4 68 0000000000 CNTC CNTG CPS 1022689 O0 000 O0 0 5 1 1 4 68 0000000000 CFTC CNTG CPS 1022689 O0 000 O0 0 5 1 1 4 68 0000000000 TNRA CNTG 1022689 O0 000 O0 0 5 1 1 4 68 0000000000 CNEC ClFTG CPS 1022689 O0 000 O0 0 5 1 1 4 68 0000000000 CFEC CNTG CPS 1022689 O0 000 O0 0 5 1 1 4 68 0000000000 TNPH CNTG PU 1022689 O0 000 O0 0 5 1 1 4 68 0000000000 ENPH CNTG PU 1022689 O0 000 O0 0 5 1 1 4 68 0000000000 NPHI CNTG PU 1022689 O0 000 O0 0 5 1 1 4 68 0000000000 NPOR CNTG PU 1022689 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-SEP-1997 10:25 PAGE: 18 ** DATA ** DEPT. 8997. 000 TENS.DSI 3686. 000 GR.DSI RSHC.DSI 1 . 977 DT2 .DSI 196. 479 DT4P.DSI E1VRA. CNTG 5.880 RCNT. CNTG 1730.202 RCFT. CNTG RCDF. CNTG 468.000 CNTC. CNTG 1686.322 CFTC. CNTG CNEC. CNTG 2876. 215 CFEC. CNTG 489.121 TNPH. CNTG NPHI. CNTG 54. 650 NPOR. CNTG 49.817 DEPT. 8894.500 TENS.DSI 3679. 000 GR.DSI RSHC.DSI 2. 325 DT2 .DSI 245. 761 DT4P.DSI ENRA. CNTG 5. 728 RCNT. CNTG 1656.573 RCFT. CNTG RCDF. CNTG 482.603 CNTC. CNTG 1682.283 CFTC. CNTG CNEC. CNTG 2851. 015 CFEC. CNTG 497. 697 TNPH. CNTG NPHI. CNTG 54. 399 NPOR. CNTG 50. 078 80.931 PR.DSI 99.362 RTNR.CNTG 387.064 RCEN. CNTG 426.058 TNRA.CNTG 51.686 ENPH. CNTG 91.868 PR.DSI 103.461 RTNR.CNTG 394.076 RCEN. CNTG 439.233 TNRA.CNTG 49.700 ENPH. CNTG 0.328 3.990 2716.253 3.980 44.491 0.386 4.292 2568.984 3.959 42.741 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION . O01CO1 DATE : 97/09/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~ER 6 RAW CASED HOLEREPEAT PASSES Curves and log header data for each pass in separate files. PASS NUM~ER: 2 DEPTH INCREM~2F~: 0.5000 FILE S~Y VENDOR TOOL CODE START DEPTH STOP DEPTH DSI 8997.0 8900.0 LDT 8997.0 8900.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-SEP-1997 10:25 PAGE: 19 CNTG LOG HEADER DATA 8997.0 DATE LOGGED: SOFTWARE VERSION: TI~E CIRCULATION ENDED: TI~E LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAM~A RAY CNTG COMP. NEUTRON LDT LITHODENSITY DSI DIPOLE SONIC $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): 8900.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OH~M) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): 1-SEP-97 8C0-609 400 1-SEP-97 1330 3-SEP-97 9505.0 9500.0 8907.0 9498.0 1800.0 TOOL NUMBER ........... SGT-L LDT-D DSST-A 6.125 8997.0 8997.0 LSND 12.60 48.0 9.0 147.0 3.770 66.0 2. 828 66.0 5.655 66.0 E P I THERMAL SANDSTONE 2.65 1.0 ALL TOOLS RUN IN CO~INATION W/SONIC ON BOTTOM AS PER CLIENT REQUEST. SIX .5" STANDOFFS RUN ON SONIC / TWO .5" STANDOFFS RUN ON THE HEAD. HOLEFINDER RUN ON BOTTOM OF THE SONIC. TWO TOOL TURNERS RUN ON STRING LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-SEP-1997 10:25 PAGE: 2O IN ORDER TO ORIENT NUCLEAR TOOLS. RIG TOOK A GAS KICK AND HAD TO INCREASE MUD WEIGHT FROM 12.0 TO 12.6 LB/GAL. 18% SOLIDS IN MUD; 15~ BARITE DRASTICALLY AFFECTED DENSITY PEF. DENSITY CORRECTION NEGATIVE DUE TO BARITE. SANDSTONE MATRIX MDEN=2.65 G/CC USED FOR ALL POROSITY CORRECTIONS. HAD A TOUGH TIME GETTING PAST 9170'. RIG MADE A WIPER TRIP. VERY DIFFICULT TO GET DOWN EVEN AFTER WIPER TRIP. PULLED MAIN PASS FROM TD TO CSG FIRST. COULD NOT GET PAST 9432 FOR REPEAT PASS. LOGGED REPEAT FROM 9432' AFTER REPEATED ATTEMPTS TO GET DOWN. CAME OUT OF HOLE STICKING SEVERAL TIMES. ALL LOGS DID REPEAT. ***'12 FT. ADDED FOR STRETCH CORRECTION. * * * * * THIS FILE CONTAINS THE RAW REPEAT PASS ACQUIRED UP INTO CASING. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN** NA~E SERV UNIT SERVICE API API API API FILE NUM~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1022689 O0 000 O0 0 6 1 1 4 68 0000000000 TENS DSI LB 1022689 O0 000 O0 0 6 1 1 4 68 0000000000 GR DSI GAPI 1022689 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-SEP-1997 10:25 PAGE: 21 NAbfE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) PR DSI 1022689 O0 000 O0 0 6 1 1 4 68 RSHC DSI 1022689 O0 000 O0 0 6 1 1 4 68 DT2 DSI US/F 1022689 O0 000 O0 0 6 1 1 4 68 DT4P DSI US/F 1022689 O0 000 O0 0 6 1 1 4 68 RTNR CNTG 1022689 O0 000 O0 0 6 1 1 4 68 EArRA CNTG 1022689 O0 000 O0 0 6 1 1 4 68 RCNT CNTG CPS 1022689 O0 000 O0 0 6 1 1 4 68 RCFT CNTG CPS 1022689 O0 000 O0 0 6 1 1 4 68 RCEN CNTG CPS 1022689 O0 000 O0 0 6 1 1 4 68 RCEF CNTG CPS 1022689 O0 000 O0 0 6 1 1 4 68 CNTC CNTG CPS 1022689 O0 000 O0 0 6 1 1 4 68 CFTC CNTG CPS 1022689 O0 000 O0 0 6 1 1 4 68 TNRA CNTG 1022689 O0 000 O0 0 6 1 1 4 68 CNEC CNTG CPS 1022689 O0 000 O0 0 6 1 1 4 68 CFEC CNTG CPS 1022689 O0 000 O0 0 6 1 1 4 68 TNPH CNTG PU 1022689 O0 000 O0 0 6 1 1 4 68 ENPH CNTG PU 1022689 O0 000 O0 0 6 1 1 4 68 NPHI CNTG PU 1022689 O0 000 O0 0 6 1 1 4 68 NPOR CNTG PU 1022689 O0 000 O0 0 6 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ** DATA ** DEPT. 9439.000 TENS.DSI 3104.000 GR.DSI 56.235 PR.DSI RSHC.DSI 1.846 DT2.DSI 155.279 DT4P.DSI 84.137 RTNR.CNTG ENRA. CNTG 3.724 RCNT. CNTG 3001.201 RCFT. CNTG 1057.604 RCEN. CNTG RCEF. CNTG 938.681 CNTC. CNTG 3026.550 CFTC. CNTG 1171.694 TNRA.CNTG CNEC. CNTG 3652.588 CFEC. CNTG 980.868 TNPH. CNTG 30.217 ENPH. CNTG NPHI.CNTG 30.658 NPOR.CNTG 30.217 DEPT. 8887.000 TENS.DSI 3470.000 GR.DSI 96.676 PR.DSI RSHC.DSI 2.302 DT2.DSI 244.052 DT4P.DSI 106.122 RTNR.CNTG ENRA. CNTG 5.762 RCNT. CNTG 1631.290 RCFT. CNTG 379.070 RCEN. CNTG RCEF. CNTG 503.342 CNTC. CNTG 1654.557 CFTC. CNTG 431.768 TNRA.CNTG CNEC. CNTG 2919.891 CFEC. CNTG 506.706 TNPH. CNTG 49.691 ENPH. CNTG NPHI. CNTG 55.288 NPOR.CNTG 50.002 O. 292 2. 778 3375. 690 2. 622 22.637 0.384 4. 165 2728.143 4. 011 43.116 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-SEP-1997 10:25 PAGE: 22 **** FILE TRAILER **** FILE NA~E : EDIT .006 SERVICE · FLIC VERSION : O01CO1 DATE : 97/09/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 97/09/23 ORIGIN : FLIC TAPE NA~E : 97401 CONTINUATION # : 1 PREVIOUS TAPE : CO~iENT : ARCO ALASKA INC, 1E-33, KUPARUK RIVER, API #50-029-22797-00 **** REEL TRAILER **** SERVICE NA~E : EDIT DATE : 97/09/23 ORIGIN : FLIC REEL NAFIE : 97401 CONTINUATION # : PREVIOUS REEL : COMPiFJFr : ARCO ALASKA INC, 1E-33, KUPARUK RIVER, API #50-029-22797-00 ; ~ . . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Johns / Chairma~ DATE: August 2, 1997 THRU: Blair Wondzell, ~ FILE NO: P. I. Supervisor '0/{( r ,.(" Goc::ró wo I\o'd(,l.J gaxhhaee.doc Confidential : Yes _' No.! , Attachment Only_" FROM: Doug Amos, ~ ~ SUBJECT: Petroleum Inspector Surface Csg. Cement Job Kuparuk River Field 1 E-31 , Parker 245 11-/5/ Fridav. AUQust 01. 1997: I was contacted by Arco Kuparuk PE Denise Petrash and informed that the surface casing cement job on well 1 E-31 had not produced returns to surface. Denise wanted my permission to proceed with a top job and have me grant a waiver for the CBT to verifying the location of cement behind the 9 5/8" surface casing. Based on the information faxed to me, I contacted Denise and informed her that I could not waive the CBT requirem~nt and until the results of the CBT were review I could not authorize proceeding with well operations. The first stage cement had been placed without problems however even with a 5 bbl over displacement the plug could not be bumped. A free-fall stage tool opening plug was dropped and the stage tool opened (2nd Stage Tool @ 2066'). 400 bbls of cement were pumped in different stages at different pressures while working the casing, no returns were seen at surface. When shut-in the wellbore would pressure up and flow back with gradually diminishing returns, 140 bbl's of mud was recovered before the well stabilized from pumping attempts. Saturday. AUQust 02. 1997: A wireline run was made and verified that the 2nd stage collar was indeed open. A 50 bbl Arctic Set I cement plug was pumped and the closing plug dropped to close the collar. The casing was successfully tested to 2000 psi prior to drilling out the EZ cemeter at 2072'. Cement was tagged at 5,476 and cleaned out to 5,573, during this time very thick contaminated mud was circulated out to clean the hole. Schlumberger was rigged up and the CBT-GR log ran from 5,573 to surface, the log results showed cement to 700' +/-, a copy of this log is attached for reference PARKER-245 .~, ID:907-559-7105 AUG 05'97 6:23 No.G06 P.Ol . . CASING ANQ lEAK-OFF FRACTURE TESTS Wøll Name: KRU 1E·31 Date: 8/3/97 Supervisor: FRED JOHNSON Casing Size and Description: 9 Sl8", 40.0#, L·aO, BTC Casing Setting Depth: 5817' TMD 4087' TVD Mud Wei~t: EMW ~ Leak-off Pressure (PLO) + MW 0.052 x TVD 8.45 ppg LOT = 800 psi! (0.052 x 4087 ft) + 8.45 ppg ... 12.2 ppg Hole Dopth (md)= 5850' Fluid Pumped;:: 2.2 bbls. Pump output ¡¡; .101 bps ...-....--........... _M..'__'" . ~ . _...__.0- ...____ 2000 11100 1800 1700 1$(10 1500 10600 1300 1200 I 11(10 1(100 900 Rnn ;'OU GOO 600 400 300 20(1 '00 0 I ! L._...... .. i ii ! -- -IJ-- l T ---- ! . i -11 J/ - -- --I~ un - ....,.. '''1 ' ~ --- - !-- +i ~t - u_ ~ - -- .., . '1 II Î" . .. I" ._--. 111 .. ~·.·f,' ··tl"-I ~r) ... .. 11.' ...- 'r .- "---1-- - - j! : JÄM! i}~ .--- --l-! ! .j... ---~ ----M· ,.... ..·..ï--··! I +-..~..._. I I'j i.. + ! j:t !)J' J +- i ¡ -- - -- := 1= : :_u:j_-:._ :: ~ _i-I! _~... ~"'I" -.... ... ... .n...... ... --+- LEAK-OFF TEST 1_ j "t' J : -I --. CASING TeST i ~~F n'l - I I ~ -.-.-- -~.... ..~. '-- - -.~-J., I.J..I I I ! ¡- ..--.....¡......, . ""'1 --r+..···..·, _._f- -H ! Ii ! ! I . . ,... J__ --. _._ ! i .. ........ ...... ,~... ... (I ? 4 ß 8 , rJ " '4 , r. , R 7.0 7.Z <!4 2f1 2. 30 32 34 36 38 40 42 44 46 48 SO S~ 54 sa sa 80 STROKES ....................................-..........---...