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Home My WebLink About196-052 ! "##$ % & '()'(' )) "()'*"+,-'( )'*+,-.& )) ' ' ' ./ ' )')''' 0 !' () ! (.(( ! '(' ) ('1 )) 23 3 +( ) '4( ./'('( ( ) '(( )!' ' ' . 5+ ! + ! # 26$#2$ 6 )4 41 . 4 + ! 5(7!48' ( By Samantha Carlisle at 8:48 am, Mar 30, 2021 Digitally signed by Roger Mouser DN: O=Conocophillips, CN=Roger Mouser, E=N1927@conocophilllips.com Reason: I am the author of this document Location: your signing location here Date: 2021.03.27 06:40:14-08'00' Foxit PhantomPDF Version: 10.1.0 Roger Mouser !"#$#$%& '( #)*+,*+" "("'"-+.+/+($ ! "!#!$%%&'&&'()%!&%*%!(*+%'*,-!&&%&!-#-&-&%&!!"!'$%%&'&&((%%%!'(%$&'+!#*,-!&&%&!(-&-&%&!!."!!*$%%&'&---)%%&%(!)('$&-*,-!&&%&!$!-&-&%&!&/"-!-$%!%-&%&))%%!'*&!'0&!,#&*&%!'*-&#&%&!&1"#!$%!%-&%)'%%%&!*!$!%-#,$ !%,)-!&%&%&-&#&%&!&"&%*$%!%-&%$!*%%&%$!*))(,%$!&,-&-&%&!*!-&-&%&!&"-)$%!%-&%&&)%%!'$!%!-%,%&%&(,-&-&%&!')-&-&%&! #"-%# $%!%-&%$$$%% &%)!-& &%+$%2#*, -&#&%&! !% -&#&%&! Originated:Delivered to:6-Apr-21 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 1A-23 50-029-22131-00 906975765 Kuparuk River Multi Finger Caliper Field & Processed 12-Feb-21 0 1 2 1B-11 50-029-20657-00 907041775 Kuparuk River Multi Finger Caliper Field & Processed 20-Mar-21 0 1 3 1D-101 50-029-22986-00 n/a West Sak Packer Setting Record Field- Final 14-Mar-21 0 1 4 1D-130 50-029-22815-00 907025874 West Sak Packer Setting Record Field- Final 13-Mar-21 0 1 5 1F-19 50-029-22660-00 906994361 Kuparuk River Packer Setting Record Field- Final 24-Feb-21 0 1 6 1G-02 50-029-20813-00 906996811 Kuparuk River Multi Finger Caliper Field & Processed 24-Feb-21 0 1 7 1L-11 50-029-22034-00 906914692 Kuparuk River Leak Detect Log Field- Final 15-Jan-21 0 1 8 1Q-10 50-029-21215-00 907035266 Kuparuk River Packer Setting Record Field- Final 18-Mar-21 0 1 9 2H-09 50-103-20050-00 907042522 Kuparuk River Packer Setting Record Field- Final 19-Mar-21 0 1 10 3H-21 50-103-20094-00 907045708 Kuparuk River Packer Setting Record Field- Final 22-Mar-21 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: PTD: 1960520 E-Set: 34905 Received by the AOGCC 04/07/2021 04/07/2021 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: ______________________ ConocoPhillips Alaska, Inc.Development Exploratory 3. Address:Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 9450'feet NA feet true vertical 6579'feet NA feet Effective Depth measured 9124'feet 6887'feet true vertical 6326'feet 4990'feet Perforation depth Measured depth 9124'-9198' feet True Vertical depth 6326'-6383' feet Tubing (size, grade, measured and true vertical depth)3 1/2" L-80 8772' 6059' Packers and SSSV (type, measured and true vertical depth)Baker 45-FA-36 6887' 4990' 12. Stimulation or cement squeeze summary:N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Authorized Title: Contact Email: 2/7/2021 Contact Phone: 196-052 50-0292-00-00 ADL0025652 1F-19 P.O. Box 100630, Anchorage, Alaska 99508 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Operator Name 4. Well Class Before Work:5. Permit to Drill Number: Packer measured true vertical Casing Length Size MD TVD N/A Kuparuk River Plugs measured Junk measured Burst Collapse Conductor 79'16"121'121' Intermediate Surface 4516'7 5/8"4557'3821' Liner Production 9361'5 1/2"9450'6579' NA NA NA NA NA N/A Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 320-427 Authorized Name: Authorized Signature with date: Senior Engineer:Senior Res. Engineer: 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283 WINJ WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Roger Mouser / Roger Winter n1927@conocophillips.com 659-7506 Well Integrity Field Supervisor NA NA NA NA NA ntt e Fra O g g g l O g y e 66. A y G L PG AAC 25 R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 9:11 am, Feb 08, 2021 Digitally signed by Roger Winter DN: CN=Roger Winter, E=n1927@conocophillips.com, C=US Reason: I am the author of this document Location: your signing location here Date: 2021.02.07 08:21:44-09'00' Foxit PhantomPDF Version: 10.1.0 Roger Winter VTL 02/18/2021 SC repair SFD 3/9/2021 9457 6585 DSR-2/8/21 RBDMS HEW 2/8/2021 SFD 3/9/2021 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 7 February 2021 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Enclosed please find the 10-404 from ConocoPhillips Alaska, Inc. for SC repair KRU 1F- 19 (PTD 196-052). Please contact Roger Mouser or myself at 659-7506 if you have any questions. Sincerely, Roger Winter Well Integrity Field Supervisor ConocoPhillips Alaska, Inc. Digitally signed by Roger Winter DN: CN=Roger Winter, E=n1927@conocophillips.com, C=US Reason: I am the author of this document Location: your signing location here Date: 2021.02.07 08:18:44-09'00' Foxit PhantomPDF Version: 10.1.0 Roger Winter Date Event Summary Executive Summary Repair SC leak @ 1' below OA valve w/X65x.500x6'1" sleeve, PT to over 1000 psi w/no leaks to surface. 11/15/20 Cut windows and found SC leak 1' below OA valve. 02/01/21 Weld 6'1" sleeve over damaged area. 02/02/21 PT for 30 mins w/N2 + lift gas. 02/06/21 Install conductor made w/X65x.375x8'7 1/2" pipe. Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: SLM 9,136.0 1/13/2015 1F-19 hipshkf Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: SET POGLM 8/6/2020 1F-19 condijw Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 42.0 Set Depth (ftKB) 121.0 Set Depth (TVD) … Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 7 5/8 ID (in) 6.88 Top (ftKB) 41.6 Set Depth (ftKB) 4,557.1 Set Depth (TVD) … 3,821.9 Wt/Len (l… 29.70 Grade L-80 Top Thread BTC-MOD Casing Description PRODUCTION 5.5"x3.5"@8772' OD (in) 5 1/2 ID (in) 4.95 Top (ftKB) 38.7 Set Depth (ftKB) 9,450.2 Set Depth (TVD) … 6,579.6 Wt/Len (l… 15.50 Grade L-80 Top Thread LTC-MOD Casing Description WINDOW OD (in) 5 1/2 ID (in) 4.95 Top (ftKB) 9,055.5 Set Depth (ftKB) 9,061.0 Set Depth (TVD) … 6,278.1 Wt/Len (l…Grade Top Thread Tubing Strings Tubing Description TUBING WO (Upper) String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 36.8 Set Depth (ft… 6,887.3 Set Depth (TVD) (… 4,990.2 Wt (lb/ft) 9.30 Grade L-80 Top Connection IBTM Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 36.8 HANGER FMC TUBING HANGER 3.500 508.3 508.3 0.24 NIPPLE CAMCO "DS" NIPPLE 2.875 6,869.6 4,980.9 58.24 SEAL ASSY PBR SEAL ASSEMBLY with Space-out 3'2.990 6,872.8 4,982.6 58.25 PBR PBR 80-40 SPECIAL TRIM (4.78" OD) 4.010 6,886.8 4,990.0 58.29 ANCHOR KBH-22 ANCHOR SEAL ASSEMBLY 3.000 Tubing Description TUBING WO (Lower) String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 6,887.3 Set Depth (ft… 8,772.3 Set Depth (TVD) (… 6,059.2 Wt (lb/ft) 9.30 Grade L-80 Top Connection IBTM Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 6,887.3 4,990.2 58.29 PACKER BAKER 45-FA-36 PRODUCTION PACKER 3.020 6,965.2 5,030.7 59.16 NIPPLE HES 'X' NIPPLE 2.812 8,771.3 6,058.5 41.94 SEAL ASSY BAKER 80-40 GBH-22 LT SEAL ASSY w/ 1' space-out 2.990 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 4,300.8 3,695.7 61.26 PATCH - PACKER 2.72" P2P PACKER, SPACER PIPE, POGLM W/ 1" GLV, 5/32", TRO 1348 PSI, SPACER PIPE, ANCHOR LATCH 8/6/2020 1.625 CPP35269 4,302.0 3,696.3 61.25 LEAK - TUBING TUBING LEAK BETWEEN 4302 - 4315', SMART HF, 2 GPM AT 3000 PSI 7/20/2020 2.990 4,304.9 3,697.7 61.24 SPACER PIPE 2-1/16", P110 SPACER PIPE 8/6/2020 1.610 CPAL35020 4,317.0 3,703.5 61.17 PATCH - PACKER 2.72" P2P PACKER, 4.1' OAL 8/6/2020 1.625 CPP35219 8,968.0 6,207.1 40.40 PACKER LINER TOP PACKER 6/27/2015 1.800 8,995.0 6,227.7 40.28 WHIPSTOCK 3.5" MONO XL THRU-TUBING WHIPSTOCK W/TOWS, SET 15 DEG LEFT OF HIGH SIDE 6/9/2015 9,054.0 6,272.8 40.01 WHIPSTOCK 3.5" MONO XL THRU-TUBING WHIPSTOCK W/TOWS, SET 9 DEG LEFT OF HIGH SIDE 5/9/2015 9,400.0 6,540.5 38.89 FISH TWO 6" LONG SEALING ELEMENTS LEFT IN HOLE AFTER PULLING IBP 7/19/2014 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 9,124.0 9,136.0 6,326.5 6,335.8 A-5, 1F-19 2/21/2009 6.0 APERF 2" PJ HSD CHARGES 9,156.0 9,176.0 6,351.2 6,366.6 A-4, 1F-19 5/20/1996 4.0 IPERF 2.5" Hollow Case; 180 deg. PhasE; 54 deg CCW Orient 9,161.0 9,171.0 6,355.1 6,362.8 A-4, 1F-19 9/29/2006 6.0 RPERF 2" HSD BH 2006 Powerflow 9,183.0 9,198.0 6,372.0 6,383.6 A-4, 1F-19 2/20/2009 6.0 APERF 2" PJ HSD CHARGES Frac Summary Start Date 10/2/2006 Proppant Designed (lb) Proppant In Formation (lb) Stg # 1 Start Date 10/2/2006 Top Depth (ftKB) 9,156.0 Btm (ftKB) 9,176.0 Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,625.6 2,588.2 CAMCO KBG-2- 9 1 GAS LIFT GLV BTM 0.156 1,359.0 7/3/2020 2 4,305.4 3,697.9 CAMCO KBG-2- 9 1 GAS LIFT OPEN BTM 7/21/2020 3 5,863.8 4,472.8 CAMCO KBG-2- 9 1 GAS LIFT GLV BTM 0.188 1,371.0 7/3/2020 4 6,812.4 4,950.7 CAMCO KBG-2- 9 1 GAS LIFT OV BTM 0.250 0.0 7/19/2020 EXT PKG 1F-19, 8/7/2020 5:11:17 AM Vertical schematic (actual) L1 LINER; 9,050.8-11,264.0 L1-01 LINER; 8,973.3-10,394.0 Perf; 9,188.6-10,393.6 PRODUCTION 5.5"x3.5"@8772'; 38.7-9,450.2 FISH; 9,400.0 APERF; 9,183.0-9,198.0 IPERF; 9,156.0-9,176.0 RPERF; 9,161.0-9,171.0 FRAC A-SAND; 9,156.0 APERF; 9,080.9-9,200.4 APERF; 9,124.0-9,136.0 WINDOW; 9,055.5-9,061.0 WHIPSTOCK; 9,054.0 Perf; 9,039.8-9,069.3 WHIPSTOCK; 8,995.0 WINDOW; 8,996.0-9,000.0 PACKER; 8,968.0 NIPPLE; 6,965.2 PACKER; 6,887.3 ANCHOR; 6,886.8 SEAL ASSY; 6,869.6 GAS LIFT; 6,812.4 GAS LIFT; 5,863.8 SURFACE; 41.6-4,557.1 PATCH - PACKER; 4,317.0 SPACER PIPE; 4,304.9 GAS LIFT; 4,305.4 LEAK - TUBING; 4,302.0 PATCH - PACKER; 4,300.8 GAS LIFT; 2,625.5 NIPPLE; 508.3 CONDUCTOR; 42.0-121.0 HANGER; 36.8 KUP PROD KB-Grd (ft) Rig Release Date 3/23/1996 1F-19 ... TD Act Btm (ftKB) 9,457.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292266000 Wellbore Status PROD Max Angle & MD Incl (°) 63.78 MD (ftKB) 5,520.93 WELLNAME WELLBORE1F-19 Annotation Last WO: End Date 6/14/2014 H2S (ppm) 80 Date 8/14/2012 Comment SSSV: NIPPLE Originated:Delivered to:9-Nov-20 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #Digital # 1 1A-24 50-029-22984-00 906642121 Kuparuk River Plug Setting Record Field- Final 5-Aug-20 0 1 2 1C-27 50-029-22943-00 n/a Kuparuk River Packer Setting Record Field- Final 25-Aug-20 0 1 3 1F-19 50-029-22660-00 906642776 Kuparuk River Packer Setting Record Field- Final 6-Aug-20 0 1 4 1Y-27 50-029-22379-00 n/a Kuparuk River Production Profile Field- Final 29-Aug-20 0 1 5 2B-02A 50-029-21154-01 906679203 Kuparuk River Multi Finger Caliper Field- Processed 29-Aug-20 0 1 6 2C-15 50-029-21219-00 n/a Kuparuk River Packer Setting Record Field- Final 30-Aug-20 0 1 7 2G-08 50-029-21125-00 906659316 Kuparuk River Packer Setting Record Field- Final 16-Aug-20 0 1 8 2L-301 50-103-20588-00 906671629 Kuparuk River Plug Setting Record Field- Final 24-Aug-20 9 2L-301 50-103-20588-00 906671629 Kuparuk River Tubing Punch Record Field- Final 25-Aug-20 10 2M-33 50-103-20240-00 906598622 Kuparuk River Leak Detect Log Field- Final 13-Aug-20 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: 0 1 Received by the AOGCC 11/09/2020 11/09/2020 Abby Bell PTD: 1960520 E-Set: 34221 Originated:Delivered to:1-Oct-20 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #CD # 1 2T-08 50-103-20070-00 906569204 Kuparuk River Multi Finger Caliper Field & Processed 25-Jun-20 0 1 2 3H-20 50-103-20093-00 906581746 Kuparuk River Multi Finger Caliper Field & Processed 30-Jun-20 0 1 3 1F-19 50-029-22660-00 906611163 Kuparuk River Multi Finger Caliper Field & Processed 20-Jul-20 0 1 4 1G-05 50-029-20908-00 906614905 Kuparuk River Packer Setting Record Field- Final 27-Jul-20 0 1 5 1R-34 50-029-22534-00 906617820 Kuparuk River Plug Setting Record Field- Final 22-Jul-20 0 1 6 2C-15 50-029-21219-00 906631899 Kuparuk River Multi Finger Caliper Field & Processed 31-Jul-20 7 2C-15 50-029-21219-00 906631899 Kuparuk River Plug Setting Record Field- Final 30-Jul-20 8 2T-08 50-103-20070-00 906595629 Kuparuk River Packer Setting Record Field- Final 13-Jul-20 0 1 9 2U-02 50-029-21268-00 906629021 Kuparuk River Multi Finger Caliper Field & Processed 29-Jul-20 10 2U-02 50-029-21268-00 906629020 Kuparuk River Leak Detect Log Field- Final 29-Jul-20 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: 0 1 0 1 Received by the AOGCC 10/05/2020 PTD: 1960520 E-Set: 34053 10/07/2020 Abby Bell \c► G- o52 2-51N O WELL LOG TRANSMITTAL Ten' bi$i2O1g K BENDER To: Alaska Oil and Gas Conservation Comm. May 18, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED MAY 2 1 2015 RE: Whipstock Setting Record: 1F-19 Run Date: 5/9/2015 AOGCC The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1F-19 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-22660-00 SCANNED JUN 1 2 2015 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: k - _ , ,/, . :. —.,...�._, ,�.—.,tee»r .."a _._.._." ., "Z:"`5`" - -- — ——�.. J — : _l�� 333 �dPt Seve�'n A�er.ue /-, ( ( \ -R\CR y H RNH. 1. Anchorage Alaska 99531 3572 907 iT433 Ray Oakley Workover Engineer KRIM jij 1 6 2014 ConocoPhillips Alaska, Inc. G_ W A P.O. Box 100360 q Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk Oil Pool, 1F-19 Sundry Number: 314-295 Dear Mr. Oakley: 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, a/6_7 ,_))ze..„1 4_____Cathy P. oerster Chair DATED this 22-day of May, 2014. Encl. STATE OF ALASKA RECEIVED AL :A OIL AND GAS CONSERVATION COMM._ BION ' APPLICATION FOR SUNDRY APPROVALS MAY 0 20j 20 AAC 25.280 ,7-r )(2.2/1 9- 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell r. Change A. t re,C.9: i Suspend r Rug Perforations r Perforate r Pull Tubing r , Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate r Alter casing r Other: r 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc.' Exploratory r Development 17, 196-052 3.Address: Stratigraphic r Service r 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-029-22660-00' 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 P--i, KRu. 1F-19 t 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25652 - Kuparuk River Field/Kuparuk River Oil Pool . 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 9457 - 6585 ' 9385' 6529' 8799' none Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 121' 121' SURFACE 4516 7.625 4557' 3822' PRODUCTION 8731' 5.5 8772' 6059' LINER 678' 3.5" 9450' 6580' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9124'-9136',9156'-9176',9183'-9198'. 6327'-6336',6351'-6367,6372'-6384' 3.5 L-80 8772 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) no packer NIPPLE-CAMCO DS NIPPLE MD=495 TVD=495 12.Attachments: Description Sunmary of Proposal p • 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r . Service r 14.Estimated Date for Commencing Operations: G/i/14 ✓L,F 15. Well Status after proposed work: 6/ 14 Oil FI- Gas r WDSPL r Suspended r 16.Verbal Approval: ate: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Ray Oakley @ 263-4759 Email: Raymond.Oakley@contractor.concophillips.com Printed Name Rav Oakley , Title: Workover Engineer Signature J / -Phone:263-4759 Date 5.75Z.� 0lily// Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 3\ii"'2 ckS Plug Integrity r BOP Test jv Mechanical Integrity Test r Location Clearance r Other: 50 / tc5 1- 7LO 3 0 0 o e, 5 Spacing Exception Required? Yes 0 No d Subsequent Form Required: it _ 4 a 4 6 �) APPROVED BY Approved by: / COMMISSIONER THE COMMISSION DateS '2Z - pproved application Is valid tor 12 months tro pmlthe date of approval. Form 10-403(Revised 10/2012) ?I( S/ /i Submit Form and Attachments in Dupli s to VLF5/zi)/,4 ORIGINAL ,,0l RBDMSMAY_.2-zv20 RECEIVED MAY 062014 ConocoPh i l l i ps Alaska AOGCC P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 May 5, 2014 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 the Kuparuk Production Well 1F-19 (PTD# 196-052). Well 1F-19 was drilled and completed in 1996. 1F-19 was shut in July 4th, 2013 after a failed TIFL. An inflatable bridge plug (IBP)was set at 8,799' MD,just below the casing seal bore. A CMIT-TxIA failed. A leak detect log indicated a tubing leak at 6639' MD, the bottom of a patch across gas lift mandrel #3. The log also indicated that the IBP was holding. Further analysis of the temperature log indicated a casing leak at 6953' MD. 1F-19 is currently shut-in with the IBP in place just below the casing seal bore. The proposed workover will pull the existing 3-1/2" tubing'and re-complete the well with a new 3-1/2" straddle packer and gas lift completion,thus isolating the suspected leak in the production casing. The planned packer set depth is 6900' MD, above the casing leak, but that may be adjusted depending upon the condition of the pulled tubing. This Sundry is intended to document the proposed work on the production well, and to request approval to workover the well. If you have any questions or require any further information, please contact me at 263-4759. Regards, Ray7?_ Oakley y Workover Engineer CPAI Drilling and Wells Raymond.Oakley@contractor.conocophillips.com 1F-19 Kuparuk Producer Rig Workover (PTD #: 196-052) Current Status The well is currently SI with an inflatable bridge plug (IBP) set just below the packer at 8,799' MD. Scope of Work The proposed workover will pull the 3-1/2" tubing and re-complete the well with a new 3-1/2" straddle packer and gas lift completion. The planned packer set depth is 6900' MD, above the casing leak, but that may be adjusted depending upon the condition of the pulled tubing. General Well info MPSP: 1,587 psi using SBHP from 7/10/2013 with a 0.1 psi/ft gas gradient Reservoir pressure/TVD: 2071 psi at 6,600' MD (4,838' TVD) SBHP taken on 7/10/2013 Wellhead type/pressure rating: FMC Gen IV, 11" 3K btm x 7-1/16" 5K top flange BOP configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams MIT Results: CMIT-TxIA: Failed, October 25, 2013 TIFL: Failed on June 28, 2013 (IA tracked tubing while stacking out tbg) Well Type: Producer Estimated Start Date: June 11, 2014 Production Engineer: Dody Cahyadi (263-3720/ Dodv.Cahyady c(D,conocophillips.com ) Workover Engineer: Ray Oakley (263-4759/ Raymond.OakleyAcontractor.conocophillips.com Pre-Rig Work 1. Set Catcher atop IBP 2. Set Dummy Valve (DV) in GLM#2 3. Pull DV from GLM#5, leave open for circulation point. 4. Set BPV within 24 hours of rig arrival • Proposed Procedure 1. MIRU 2. Pull BPV. Load well with workover fluid. Ensure well is dead. 3. Set BPV and blanking plug. ND tree. 4. NU BOPE. Pressure test to 3000 psi the BOPE including annular. Pull blanking plug and BPV. 5. Make up landing joint, BOLDS, POOH laying down tubing. a. If tubing will not pull free, RU E-line and cut tubing 6. RIH w/ casing scraper assembly on drill pipe to just above the original casing seal bore. Circulate wellbore clean and spot corrosion inhibitor. a. If tubing was cut, then make fishing run on drill pipe for tubing stub. 7. RIH on drill pipe with packer-setting tool, permanent straddle packer, tail pipe and locator seal assembly (to sting into the original casing seal bore.) Engage seal assembly in casing seal bore, with permanent packer above the casing leak. Drop ball and rod, and pressure up drill pipe to set the packer. Bleed off pressure. Pressure up annulus to test packer. Then rotate to release setting tool from packer. POOH and lay down drill pipe. 8. Make up anchor seal assembly, polished bore receptacle (PBR,) and 3-1/2" tubing with gas lift completion and run in to just above the straddle packer. 9. Latch the anchor into the packer and shear out of the PBR. 10. Sting the seal assembly into the PBR until fully located. 11. Pick up, space out with pups, make up tubing hanger, engage seals in the PBR, land the hanger, and RILDS. 12. PT the tubing and IA. Shear the SOV. ✓ 13. Install the BPV or two-way check. Pressure up on the IA to 1000 psi to test the BPV or two-way check from below. Bleed IA to 0 psi. 14. ND BOPE. NU tree. If BPV is installed, pull BPV and install tree test plug. Test tree. 15. Pull test plug/two-way check. Freeze protect well. Set BPV. 16. RDMO. Post-Riq Work request: 1. Reset well house(s) and flowlines of adjacent wells. 2. Pull BPV. 3. RU Slickline: a. Pull Ball and Rod, pull RHC plug body b. Pull SOV from GLM#2 c. Run GLD d. MIT-tubing e. Pull catcher, and pull IBP f. Tag bottom 4. Return well to production. KUP PROD 1F-19 .0.-- 6 Conocorl lillips 2 Well Attributes Max Angle&MD TD Alaska Inc Wellbore APIIUWI Field Name Wellbore Status ncl("I MD(ftKB) Act Btm(ftKB) rrrrxrinvnyn 500292266000 KUPARUK RIVER UNIT PROD 1 63.78 5,520.93 9,457.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date IF-19,12/14/20133.13:23 PM SSSV: NIPPLE 80 8/14/2012 Last WO: 3/23/1996 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation last Mod By End Date Last Tag.RKB 9.311.0 2/5/2009 Rev Reason:MANDREL ORIENTATION hipshkf 12/14/2013 HUNGER;368 allill1Till Casing Strings III ial Casing Description OD(in) ID(in) Top(ft(B) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 420 121.0 62.50 H-40 WELDED Casing Description OD(in) •ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... WULen(I...Grade Top Thread SURFACE 7 5/8 6.875 41.5 4,557.1 3,822.0 29 70 L-80 BTC-MOD IjII I Casing Description OD(in) ID(in) Top(RKB) Set Depth(ftKB) Set Depth(TVD)...WULen(I...Grade Top Thread PRODUCTION 51/2 4.950 39.4 9,450.2 6,579.6 15.50 L-80 LTC-MOD • 5.5"x3.5"@8722' 'Tubing Strings Tubing Description String Ma...ID ID(in) I Top(ftKB) I Set Depth(ft..f Set Depth(ND)(...I Wt(Iblft) I Grade I Top Connection • TUBING 31/2 2.992 36.8 8,772.31 6,0592 9.30 L-80 ABM-EUE .Mi fONDUCTOR;12.P11.0 I Completion Details Nominal ID Top(ftKB) Top(ND)(RKB) Top Incl(°) Item Des Com (in) NIPPLE;495.1 I 36.8 HANGER FMC GEN IV HANGER 3.500 I 495.1 495.1 0.23 NIPPLE CAMCO DS NIPPLE 2.812 8,764.0 6,053.1 42.04 NIPPLE CAMCO D NIPPLE NO GO 2.75"ID-NIPPLE 2250 REDUCER SET 11/19/2002 GAS LIFT,2,483.3 ' `l 8,771.0 6,058.3 41.94 LOCATOR BAKER LOCATOR 3.000 I 8,771.8 6,058.9 41.93 SEAL ASSY BAKER GBH-22 SEAL ASSEMBLY w/OAL 11.92' 3.000 STABBED INTO PROD CSG SEAL BORE Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Ind Top(RKB) (ftKB) (°) Des Com Run Date ID(in) 6,613.0 4,844.4 57.69 PATCH PATCH SET ACROSS MANDREL @ 6622' 11/24/2002 2.375 SURFACE;41.5-4,557.1-. 8.764.0 6,053.1 42.04 NIPPLE NIPPLE REDUCER SET IN'13'NIPPLE 11/19/2002 2.250 REDUCER 1 8,799.0 6,0792 41.56 PLUG BAKER 2.125"IBP @ 8799 10/23/2013 OAL=10.5' GAS LIFT;4,801.2 Perforations&Slots Snot Dens (shots/f s - Date t) Type Com 1 ,l 221/2009 6.0 APERF 2"PJ HSD CHARGES 9,156.0 9,176.0 6,351.2 6,366.6 A-4,1F-19 5/20/1996 4.0 IPERF 2.5"Hollow Case;180 PATCH;6,613.0` deg.PhasE;54 deg GAS UFT;6,621.6 I A CCW Orient till IA 9,161.0 9,171.0 6,355.1 6,362.8 A-4,1F-19 929/2006 6.0 RPERF 2"HSD BH 2006 Powerflow 9,183.0 9,198.0 6,372.0 6,383.6 A-4,1F-19 2/20/2009 6.0 APERF 2"PJ HSD CHARGES Stimulations&Treatments Min Top Mao Btm Depth Depth Top(ND) Min(ND) GAS LIFT;7646.9 II; (RKB) (ftKB) (RKB) (11KB) Type Date Com 9,156.0 9,176.0 6,351.2 6,366.6 FRAC A-SAND 10/2/2006 BREAKDOWN,DATA FRAC AND A-SAND FRACTURE TREATMENT DESIGNED FOR 158,000#16/20 W/YF150D.PUMPED 176240# II 16/20 TO COMPLETION 10 PPA ON FORMATION, ADJUSTED PAD FROM 260 BBLS TO 240 BBLS GAS LIFT;6711.2 4 Mandrel Inserts St • ati C on Top(NO) Valve Latch Port Size TRO Run No Top(ftKB) (ftKB) Make Model 00(in) Sen./ Type Type (in) (psi) Run Date m 1 2,483.3 2,458.9 BST AXT 1 GAS LIFT GLV T-1 0.188 1,380.0 10/5/2006 NIPPLE;8,764 0 NIPPLE REDUCER;8.764.01 1.1 2 4,801.2 3,946.2 BSTAXT 1 GAS LIFT OPEN 9/302013 3 6,621.6 4,849.0 BST AXT 1 GAS LIFT PATCH T-1 0.000 0.0 11/24/2002 4 7,946.9 5,535.4 BST AXT 1 GAS LIFT DMY T-1 0.000 0.0 2/202003 LOCATOR;8,771.0 • SEAL ASSY;8.771.8 !;a 5 8,711.2 6,014.0 BST AXT 1 GAS LIFT DMY T-1 0.000 0.0 2/21/2003 40 Notes:General&Safety -O. End Date Annotation Mt 2/2/2003 NOTE:DO NOT PULL DMYs @ 7947"OR 8711"-GLM5 APPARENTLY GETTING WORN&DIFFICULT TO SEAL. 9/14/2010 NOTE:View Schematic w/Alaska Schematic9.0 PLUG;8,799.0 12/5/2013 'NOTE:Mandrel Orientation:1)12:00 2)5:00 3)7:30 4)2:30 APERF;9,124.09,136.0 ' FRAC A-SAND;9,156.0 I U (PERF;9,156.0.9,176.0 111- a RPERF;9,161.0.9,171.0 ■ ■ , APERF;9,183.0.9,198.0 PRODUCTION 5.5-43.5188727;39.49,450.2 . . ConocoPhillips 1 F-19 - Current PLAN Schematic Nabors 7ES tJ • 4 2.875" DS-Nipple @ 500 MD Casing —7-5/8"29.7#, L-80 BTCM @ 4,557' MD Gas Lift Mandrels: Type MD TVD KBG-2-9, 1" 2,483 2,459 KBG-2-9, 1" 4,801 3,946 KBG 2 9, 1" 6,622 4,849 r :1 __,,F -41— Stacker Packer (FA) @ 6900' MD C Q -4 2.813" DS-Nipple @ 6942' MD Casing Leak @ 6,953' MD Tubing —3-1/2" 9.3#, L-80, 8rd IBTM SCC ► Casing—5.5" 15.5#, L-80 LTCM ► @ 8,772' MD f Baker GBH-22 Seal Assy into Prod Csg Seal Bore @ 8,772' MD ILI I �— Baker 2.125" IBP (OAL 10.5') @ 8,799' DSLM A-5 Perf@ 9,124'-9,136' MD _...., T A-4 Perf @ 9,156'-9,198' MD Casing—3.5" 9.3#, L-80 EUE 8rd ► @ 9,450' MD Date: May 5,2014 Drawn By: Ray Oakley WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. October 14, 2009 Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Production Profile: 1F-19 Run Date: 8/23/2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1 F-19 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-22660-00 Injection Profile Log ~,~~ DES ~ ~ ~OD~ 1 Color Log 50-029-22660-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael. barreto@halliburton. com Date: 1`~ ~ " ~'~ ~ ~ ~`/ ~'~ l ~; Jr` ~ 1 ~ Signed: ~ ~ ~~ ~~~_._~___ ~N M1'~° ~` -~~~ E~ 2 ~ ~i ~' STATE OF ALASKA • ~sk~ ®~ ~ ~~f~, ALASKA OIL AND GAS CONSERVATION COMMISSION ~ ~aS ~~~ REPORT OF SUNDRY WELL OPERATIONS "~~horan,.~ ~~~ntisrs. 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other ^ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate Q - Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: COnoCOPhillips Alaska, InC. Development ^~ Exploratory ^ 196-052 / 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-22660-00 - 7. KB Elevation (ft): 9. Well Name and Number: RKB 41'; Pad 77' 1 F-19 " 8. Property Designation: 10. Field/Pool(s): ADL 25652 - Kuparuk River Field / Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 9457' - feet true vertical 6585' - feet Plugs (measured) Effective Depth measured 9385' feet Junk (measured) true vertical 6529' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 121' 121' SURFACE 4516' 7-5/8" 4557' 3824' PRODUCTION 8731' 5-1/2" 8772' 6059' LINER 678' 3-1/2" 9450' 6579' ,/ Perforation depth: Measured depth: 9124'-9136', 9156'-9176', 9183'-9198' „. ;;+~~ggrr~~ f „ ~ true vertical depth: 6327'-6336', 6351'-6367', 6372'-6384' Tubing (size, grade, and measured depth) 3.5", L-80, 8772' MD. Packers & SSSV (type & measured depth) no packer Camco'DS' nipple @ 495' 12. Stimulation or cement squeeze summary: Intervals treated (measured} not applicable Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 67 378 80 -- 162 Subsequent to operation 73 417 82 -- 165 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^~ - Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil^~ - Gas ^ WAG ^ GINJ © WINJ ^ WDSPL ^ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.O. Exempt: none Contact John Peirce @ 265-6471 Printed Name John Peirce Title Wells Engineer Signature ~ rf }~ r ~- Phone: 265-6471 Date Z ~z~ "O~ ,. W ~'" -' •- - Pre ared b Shar n Allsu Drake 263-4612 Form 10-404 Revised 04/2006 u earu~oaams~ es , cis ~~•t~^vre U f_ (t1U.;+ ~3/~~ Submit Original Only ,r ~OI'~(~(?~'11~~IpS F1`td?R.A ~(1C, Stllernetlc - Aqu CONDUCTOR, 121 NIPPLE 695 KUP Well Attributes Wellbore APVU WI Ii Field Nam 500292266000 KUPARL Com em SSSV: NIPPLE 'Well Status Pr< UNIT PRODUCING pm) (Date Annotatioi 90 8/18!2008 Last WO: 1 F-19 3/23/1996 1 Date 2/21/2009 2,483 2,458. 23.11 GAS LIFT BST/AXT/1/GLVR-1/.188/1380/Comment STA 1 10/5/2006 1 2.9001 4,801 6 3,947.0 58.50 GAS LIFT -- BST/AXT/1/OV/T-1/.188// Commenr STA 2 10/6/2006 ~ 2.900 6,613 4,844.51 57.69 PATCH j PATCH SET ACROSS MANDREL @6613' 11/242002 ~ 2.375 6,622 4,849.3 57.63 GAS LIF7 BST/AXT/1/PATCH/T-1///Comment: STA 3, TOP OF 11242002 2.900 `` PERMANENT PATCH @ 6613, W/ID 2.375" 7,947 5,535.61 54.15 GAS LIFT BST/AXTl1/DMY/T-1!// Comment: STA 4, EXT PKG -DO 2/20/2003 2.900 1 NOT PULL DMYS @ 7947 OR 8711' - GLMS 1 APPARENTLY GETTING WORN & DIFFICULT TO SEAL 8,711 6 013.51 41.54 GAS LIFT , i BSTIAXT/1/DMY/T-1 /// Commenr STA 5, EXT PKG 2/212003 2.900 8,764 6,052.9 41.30 NIPPLE ~ Camco'D' Nipple NO GO; 2.75' X 2.25" NIPPLE 5/13/1996 12.250 i REDUCER SET 11/19/2002 8,772 6,058.9 41.271 SEAL Baker GBH-22 LOCATOR SEAL ASSEMBLY stabbedinto 5/13/1996 3.000 1 3.5 Csg Perforat ions 8 Slots snot Top(ND) Bim (TVD) Dens Top (ftK6) Btrn (ftK6) (ftK6) (flKB) Zona Date (sh... Type Comment 9,124 9,136 6,326.6 6,335.8 A-5, 1F-19 2/21/2009 6.0 APERF 2" PJ HSD CHARGES 9,156 9,176 6,351.2 6,366.6 A-4, 1F-19 5/20/1996 4.0 IPERF ; 2.5" Hollow Case; 180 deg. PhasE; 1 54 deg CCW Orient 9,161' 9,1711 6.355.1 6,362.8 A-0, 1F-19 929/2006 6.0! RPERF j 2" HSD BH 2006 Powerflow 9,183' 9,198 1 6,372.0 6,383.6A-0, 1F-19 12/20/2009 6.0 ~ APERF j2"PJ HSD CHARGES Stimula tions & Treatments Min Top Max etm Top Depth Bonom Depth 'i Dapih Depth (ND) (TVD) (fl KB) (ftK6) (ftK6) (ftKB) Tvoe Data Comment TURE TREATMENT DESIGNED FOR DO# 16/20 W/YF 150D. PUMPED 176240 # TO COMPLETION 10 PPA ON FORMATION, STED PAD FROM 260 BBLS TO 240 BBLS 9,1839,198 LINER, 9A50 \ TD.9p57 1 F-19 Well Work Summary DATE SUMMARY 2/5/09 TAGGED @ 9311' RKB, EST. 1 ATHOLE. DRIFTED WITH 20' x 2.00" 311' RKB, NO PROBLEMS. READY FOR E/L. 2/20/09 PERFORATED FROM 9183'-9198' WITH 2" 6 SPF PJ HSD CHARGES. 2/21/09 PERFORATED FROM 9124'-9136' WITH 2" 6 SPF HSD PJ CHARGES. s. ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 RECEIVED JAN 0 7 2009 Alaska Oil 8 Gas Cons. Commission Anchorage Jan 2, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7`" Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: 49~"~6~~t~ JAN ~' ~ ~,OG~ ~~~ ~~~v ~~~ ,~ \~' `~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Some of these wells were found to have a void in the conductor by surface casing annulus. The volume of annular void subsequently was filled with a corrosion inhibiter 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. Similarly, It was noticed In August 2007 that 5 wells on DS 1 C had similar cement and sealant treatments. These wells were inadvertently omitted from the 10-404 submitted at that time for other work being performed. These wells are included here. Please call Perry Klein or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, Perry K1 ' _ ConocoPhillips Well Integrity Supervisor '~ i ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) ______. Kuparuk Field 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 1F-09 183-104 11" na 11" na 1.70 12/7/2008 1 F-14 183-146 18" na 18" na 2.00 12/7/2008 1 F-17 196-047 8" na 8" na 1.70 12/7/2008 1 F-19 96-052 8" na 8" na 1.70 12/7/2008 1 F-20 196-053 6" na 6" na 1.00 12/7/2008 1C-111 201-128 5' 9" 0.50 18" 8/27/2007 21.00 8/29/2007 1 C-13 198-011 32' 10" 4.00 18" 8/27/2007 17.00 8/29/2007 1 C-14 206-001 14' 6" 2.00 18" 8/27/2007 9.00 8/29/2007 1 C-21 205-034 38' 10" 4.00 18" 8/27/2007 8.60 8/29/2007 1 C-23 199-034 10' 10" 1.50 18" 8/27/2007 23.00 8/29/2007 (,) Ii jI ~/J/JJC--~... 03/05/07 Schlumbepge.1' NO. 4173 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite '100 Anchorage, AK 99501 t1AR (D ~ 10m ('l)\nrn\!J~.~o6GANNED MAR 3 Ü ZOU7 81, Field: Kuparuk tCj(¿, -OSd Well Job# Log Description Date BL Color CD 2G-03 11638824 INJECTION PROFILE 02/15/07 1 1 R-08 11628971 INJECTION PROFILE 02/15/07 1 1 F-17 11638827 SBHP SURVEY 02/17/07 1 1F-14 11638826 SBHP SURVEY 02/17/07 1 1F-19 11638828 SBHP SURVEY 02/19/07 1 1C-13 11628977 SBHP SURVEY 02/19/07 1 1 C-02 11628978 SBHP SURVEY 02/19/07 1 2M-02 11628979 INJECTION PROFILE 02/20/07 1 3S-26 11638813 INJECTION PROFILE 01/21/07 1 1C·121 11665391 INJECTION PROFILE 02/05/07 1 1 J-180 11665390 US IT 02/06/07 1 3J-14 11638825 PROD PROFILE 02/16/07 1 1 J-118 11665392 USIT 02/22/07 1 1 D-11 11665393 INJECTION PROFILE 02/24/07 1 2M·05 11665400 INJECTION PROFILE 03/01/07 1 2M-04 11665399 INJECTION PROFILE 03/01/07 1 1F-13 11665401 INJECTION PROFILE 03/02/07 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 1'75 . . . RECEIVED . STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS nr'- 2 7 2 U l, I 006 Repair Well D Pull Tubing D Ope rat ShutdownD Alaska Oil & Gas Cons. Commissior Other horage Time Extension D D Abandon D Alter Casing D Change Approved Program D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 118' 8. Property Designation: ADL 25652, ALK 2578 11. Present Well Condition Summary: 1. Operations Performed: Total Depth Effective Depth Casing Structural CONDUCTOR SUR. CASING PROD. CASING LINER Perforation depth: Stimulate Q Waiver D Plug Perforations D Perforate New Pool D Perforate Q' 4. Current Well Status: Development Q Stratigraphic D Service Re-enter Suspended Well 5. Permit to Drill Number: 196-052 I . 6. API Number: 50-029-22660-00 Exploratory D D 9. Well Name and Number: 1F-19 10. Field/Pool(s): Kuparuk River Field I Kuparuk Oil Pool measured 9457' feet true vertical 6585' feet measured 9277' feet true vertical 6445' feet Length Size MD 80' 16" 121' 4439' 7-518" 4557' 8654' 5-1/2" 8772' 678' 3-1/2" 9450' Plugs (measured) Junk (measured) TVD Burst Collapse 121' 3822' 6060' 6579' Measured depth: 9156'-9176' true vertical depth: 6351'-6367' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 8772' MD. Packers & SSSV (type & measured depth) no packer Cameo 'DS' nipple @ 495' 12. Stimulation or cement squeeze summary: .." '~ {, 9 2006 Intervals treated (measured) 9156'-9176' pumped 176240# of 16/20 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mef Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 149 493 105 146 Subsequent to operation 119 . 803 113 146 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory D Development Q. Service D Daily Report of Well Operations _X 16. Well Status after proposed work: OilQ GasD WAGD GINJD WINJ D WDSPLD 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: Contact Printed Name Signature Howard Gober @ 263-4220 Howard Gober Title Phone Wells Group Engine~te It:l'''Z-ú !o<.,t. Pre ared b Sha" n AlIsu Drake 263-4612 .A> II. 7· ~ 7i~;;'7O¡ð6 Form 10-404 Revised 04/2004 ORIGINAL ~\Al ~ ConocoPhillipe 'aSIea. Inc. . KRU 1F-19 ~ 1F-19 API: 500292266000 Well Type: PROD Angle @ TS: 41 deo ( 8864 SSSV Tvoe: Nipple Oria Completion: 3/23/1996 Anale (â) TD: 39 dea 9457 NIP (495-496, Annular Fluid: Last W/O: Rev Reason: TAG FILL, GLV OD:3.500) C/O, PERF, FRAC TUBING Reference LOQ: Ref LOQ Date: Last Uodate: 10/3/2006 (0-8772, Last Tag: 9277' RKB TD: 9457 ftKB OD:3.500, Last TaQ Date: 9/26/2006 Max Hole Anale: 64 deQ @ 5521 ID: 2. 992) Casing String - ALL STRING Description Size Top Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 121 121 62.50 H-40 Gas Lift SUR. CASING 7.625 0 4557 3822 29.70 L-80 landreVDummy PROD. CASING 5.500 0 8772 6060 15.50 L-80 Valve 1 LINER 3.500 8772 9450 6579 9.30 L-80 (2483-2484, Tubing String - TUBING OD:4.750) Size I TOD I Bottom I TVD Wt Grade I Thread 3.500 I 0 I 8772 I 6060 9.30 L-80 I ABM-EUE Perforations Summary Gas Lift Interval TVD Zone Status Ft SPF Date Type Comment landreVDummy 9156 - 9161 6351 - 6355 A-4 5 4 5/20/1996 IPERF 2.5" Hollow Case; 180 deg. Valve 2 PhasE; 54 dea CCW Orient (4801-4802, 9161 - 9171 6355 - 6363 A-4 10 10 9/29/2006 RPERF 2" HSD BH 2006 Powerflow OD:4.750) 9171-9176 6363 - 6367 A-4 5 4 5/20/1996 IPERF 2.5" Hollow Case; 180 deg. PhasE; 54 deo CCW Orient Stimulations & Treatments Interval Date TYDe Comment 9156 - 9176 10/212006 FRAC A-SAND BREAKDOWN, DATA FRAC AND A-SAND FRACTURE TREATMENT DESIGNED FOR 158,000# 16/20WIYF150D. PUMPED 176240 # 16120 TO COMPLETION 10 PPA ON FORMATION, ADJUSTED PAD FROM 260 BBLS TO 240 BBLS Gas Lift MandrelsNalves PATCH (6613-6634, St MD TVD Man Man Type VMfr V Type VOD Latch Port TRO Date Run Vlv OD: 2. 992) Mfr Cmnt Gas Lift 1 2483 2459 BST AXT DMY 1.0 T-1 0.156 1420 9/27/2006 land reVDummy 2 4801 3947 BST AXT DMY 1.0 T-1 0.188 0 9/27/2006 Valve 3 3 6622 4849 BST AXT PATCH 1.0 T-1 0.000 0 11/24/200 (1) (6622-6623, 4 7947 5536 BST AXT DMY 1.0 T-1 0.000 0 2/20/2003 (2) OD:4.750) 5 8711 6015 BST AXT DMY 1.0 T-1 0.000 0 2/21/2003 (3) 1. Top of Permanent Patch @ 6613, wIlD 2.375" 2. EXT Pkg Gas Lift 3. EXT Pkg landreVDummy Other [plugs, equip., etc.) . JEWELRY Valve 4 Depth TVD TYDe Description ID (7947-7948, OD:4.750) 495 495 NIP Cameo'DS' 2.813 6613 4845 PATCH PATCH SET ACROSS MANDREL @6613' 2.375 8764 6054 NIP Camco 'D' Nipple NO GO; 2.75" X 2.25" NIPPLE REDUCER SET 2.250 11/19/2002 Gas Lift 8772 6060 SEAL Baker GBH-22 LOCATOR SEAL ASSEMBLY stabbed into 3.5 Csa 3.000 landreVDummy General Notes Valve 5 Date I Note (8711-8712, 2/22/20031 ~O NOT PULL DMYs @ 7947' OR 8711' - GLMs APPARENTLY GETTING WORN & DIFFICULT TO OD:4.750) SEAL. NIP (8764-8765, OD:3.500) PROD. CASING (0-8772, OD:5.500, Wt:15.50) FRAC ~ ~ A-SAND + H (9156-9176) ~ ~ Perf (9156-9176) ~ Perf ~ (9161-9171) H- .'L I-----"- . 1F-19 Well Events Summary . DATE Summary 9/26/06 DRIFTED TBG W/ 10' OF 2" BAILER & TAGGED FILL @ 9277' RKB, IN PROGRESS 9/27/06 DUMMIED GAS LIFT STRING @2483' & 4801' RKB, LOADED I/A W/ DIESEL, SET 2.25" CA-2 BLANKING PLUG @ 8764' RKB, PT I/A TO 1500# HELD, PT TBG TO 1500# HOLDING, IN PROGRESS 9/28/06 MITT & MITIA. PAST, PULLED CA-2 BLANKING PLUG @ 8764' RKB. READY TO PERF 9/29/06 PRE-FRAC PERFORATION --- PERFORATED 9161'-9171' WITH 2.0" HSD 6 SPF, 60 " DEGREE PHASING, 2006 UL TRAPACK HMX CHARGES (API PEN: 4.5", API ENT: 0.39") 10/2/06 BREAKDOWN, DATA FRAC AND A-SAND FRACTURE TREATMENT DESIGNED FOR 158,000# 16/20 W/YF150D. PUMP¡;D 176240 # 16/20 TO COMPLETION 10 PPA ON FORMATION, ADJUSTED PAD FROM 260 BBLS TO 240 BBLS. RIG DOWN FRAC EQUIPMENT. 10/3/06 CLEANED FILL TO 9350' CTM (9370' RKB) W/ N2, SLICK DIESEL, AND 1-1/2# BIOZAN USING 1.75" JETSWIRL NOZZLE (EST. 150' OF RATHOLE). WELL LEFT SHUT IN AND FREEZE PROTECTED TO 2500'+ W/ DIESEL. 10/4/06 TAG FILL @ 9224' RKB (EST 48' OF RATHOLE), GAUGE TUBING TO 2.20". IN PROGRESS 10/5/06 PULL 1" DMY'S FROM 2483' RKB & 4801' RKB, SET 1" GLV @2483' RKB. IN PROGRESS. 10/6/06 SET 1" ORIFICE VALVE @4801' RKB. ***MANDREL IS BELLY UP. USE DE- CENTRALIZER W/ CLOCK@ 12** JOB COMPLETE. ) ConocJPhillips Mike Mooney /9(; -05 ~ ) Wells Group Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 October 22,2004 RE EIVED OCT 2 6 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Alaska Oil & Gas Con$. Comm¡~$!Qn Anchorage Subject: Report of Sundry Well Operations for 1 F-19 (APD # 196-052) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operations on the Kuparuk well 1 F-19. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, If- JI/~ M. Mooney Wells Group Team leader CPAI Drilling and Wells MM/skad SCANNED NOV 0 3 2004 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATION~I~$k~ Oil & . A~thtU~~~ Abandon D Repair Well D Plug Perforations D Stimulate 0 Other D Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Extension D Change Approved Program D Operat. ShutdownD Perforate D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development- 0 Exploratory D 196-0521 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360, Anchorage, Alaska 50-029-22660-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 118' 1 F-19 1. Operations Performed: ) ) EI OCT 2 6 2004 8. Property Designation: ADL 25652, ALK 2578 11. Present Well Condition Summary: 10. Field/Pool(s): Kuparuk River Oil Field 1 Kuparuk Oil Pool Total Depth Effective Depth Casing Structural CONDUCTOR SUR. CASING PROD. CASING LINER Perforation depth: measured 9457' feet true vertical 6585' feet measured 9296' feet true vertical feet Length Size MD 121' 16" 121' 4439' 7-5/8" 4557' 8654' 5-1/2" 8772' 678' 3-1/2" 9450' Plugs (measured) Junk (measured) TVD Burst Collapse 121' 3822' 6060' 6579' Measured depth: 9156'-9176' true vertical depth: 6351'-6367' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 8772' MD. Packers & SSSV (type & measured depth) no packer Cameo 'OS' @ 495' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 9156'-9176' 13. Treatment descriptions including volumes used and final pressure: SEE ATTACHED SUMMARY Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations_X 164 15. Well Class after proposed work: Exploratory D Development 0 Service D 16. Well Status after proposed work: Oil 0 GasD WAGD GINJD WINJ D 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: Contact Printed Name Oil-Bbl SI 146 Representative Daily Average Production or Injection Data Gas-Met Water-Bbl TubinQ Pressure CasinQ Pressure 47 147 WDSPLD Mike Mooney @ 263-4574 ~1~; Form 10-404 Revised 04/2004 Signature Title Kuparuk Wells T earn Leader . . Phone Date /ð ~3 . BFtb'ShfirT~2~ 0 RIG I N A L Submit Original Only ) ~ cOnOCOPhilliPS1~~aSka,J"~ r API: 500292266000 SSSV Type: Nipple Annular Fluid: Reference Log: Last Tag: 9296 Last 8/16/2004 NIP (495-496, 00:3.500) G as Lift andrelNalve 1 (2483-2484, G as Lift andrelNalve 2 (4801-4802, i..- TUBING (0-8772, 00:3.500, 10:2.992) PATCH (6613-6634, 00:2.992) Gas Lift ldrellOummy Valve 3 (6622-6623, 00:4.750) JI~j , E:. Gas Lift ldrel/Oummy Valve 4 (7947-7948, 00:4.750) '¡j ëf Gas Lift ldrel/Oummy Valve 5 (8711-8712, 00:4.750) . NIP (8764-8765, 00:3.500) PROO. CASING (0-8772, 00:5.500, Wt:15.50) Perf (9156-9176) LINER (8772-9450, 00:3.500, Wt:9.30) ) KRU 1 F-19 Well Type: Orig Completion: Last WID: Ref Log Date: TD: PROD 3/23/1996 Angle @ TS: 41 deg ~ 8864 Angle @ TD: 39 deg ~ 9457 Rev Reason: TAG FILL Last Update: 8/21/2004 Max Hole Description Size Top Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 121 121 62.50 H-40 SUR. CASING 7.625 0 4557 3822 29.70 L-80 PROD. CASING 5.500 0 8772 6060 15.50 L-80 LINER 3.500 8772 9450 6579 9.30 L-80 Size Top Thread 3.500 0 ABM-EUE Perforations Summary Interval TVD Zone Status Ft SPF Date Type Comment 9156 - 9176 6351 - 6367 A-4 20 4 5/20/1996 IPERF 2.5" Hollow Case; 180 deg. 54 CCW Orient St MD TVD Man Man Type V Mfr V Type V OD Latch Port TRO Mfr 1 2483 2459 BST AXr 2 4801 3947 BST AXr 3 6622 4849 BST AXr 4 7947 5536 BST AXr 5 8711 6015 BST AXr 1. Top of Permanent Patch @ 6613, wilD 2.375" 2. EXT Pkg 3. EXT Pkg Other (plugs, equip., etc.) - JEWELRY Depth TVD Type 495 495 NIP 6613 4845 PATCH 8764 6054 NIP 8772 6060 SEAL General Notes Date Note 2/22/2003 DO NOT PULL DMYs @ 7947' OR 8711' - GLMs APPARENTLY GETTING WORN & DIFFICULT TO SEAL. GLV OV PATCH DMY DMY Date Run 1420 2/22/2003 0 2/22/2003 0 11/24/2002 0 2/20/2003 0 2/21/2003 (1 ) (2) (3) Vlv Cmnt T-1 T-1 T-1 T-1 T-1 0.156 0.188 0.000 0.000 0.000 1.0 1.0 1.0 1.0 1.0 ID 2.813 2.375 2.250 3.000 Description Cameo 'DS' PATCH SET ACROSS MANDREL ~6613' Cameo '0' Nipple NO GO; 2.75" X 2.25" NIPPLE REDUCER SET 11/19/2002 Baker GBH-22 LOCATOR SEAL ASSEMBLY stabbed into 3.5 Csg ) 1 F-19 Well Events Summary ) Date Summary 08/16/04 RAN GR/CCL FOR DEPTH DETERMINATION -- TAGGED AT 9296', -- ATTEMPTED TO STIMULATE A-4 SAND PERFS BUT ONLY COVERED 9172' TO 9178' BEFORE PST FAILED - RAN BACKUP TOOL AND IT FAILED ALSO 08/20/04 RAN THE 21/8" PST AND STIMULATED THE A-4 PERFS: 91561 - 9176' 03/19/O3 Schlumberger NO. 2705 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Company: Alaska Oil & Gas Cons Corem Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Color CD 2T-27/ c~ .~_ ]~{~¢ TEMPERATURE LOG 01/01/03 1B-12 !~ ]~)~ ~ INJECTION PROFILE 03/04/03 1C-135 c~! -'_~;~<~O INJECTION PROFILE 02/26/03 1D42 II clC ~' 0 ~-iPRODUCTION PROnLE 03/05/03 1F-19 q~,- )?~. ' LEAK DETECTION LOG - 02'08/03 1 H-07/~C:~ ~" LEAK DETECTION LOG 02/15/03 ,, Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ,VAR ?. 5 2005 Aja~ka ~ & Gas Oons. Oorr~i~eien ConocOphillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 7, 2003 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find 10-404 Sundry Notices for ConocoPhillips Alaska, Inc., wells 1F-19 (PTD 196-052) and 1G-I 1 (PTD 183-131). The Sundry Notices regard tubing patches run to fix tubing leaks. Please call JetTy Dethlefs or me at 907-659-7224 if you have any questions. Sincerely, ConocoPhillips Problem Well Supervisor Attachments RECEIVED FEB I ~ 2003 Alaska 0il & GasC--or~s. Cornmismor,' Anchorage STATE OF ALASKA AL ,~ OIL AND GAS CONSERVATION COMMIS.. REPORT OF SUNDRY WELL OPERATIONS · 2'. Name of Operator ' 5. Type of Wall: 6. Datum elevation (DF or KB feet) ConocoPhillips Alaska Inc. Development__X RKB 118 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 665' FNL, 91' FEL, Sec. 19, T11 N, R10E, UM (asp's 539883, 5958861) 1 F-19 At top of producUve interval 9. Permit number / approval number 1938' FSL, 783' FEL, Sec. 17, T11 N, R10E, UM ~ 196-052/ At effective depth 10. APl number ',~ 50-029-22660 At total depth 11. Field / Pool 3172' FNL, 443' FEL, Sec. 17, T11N, R10E, UM (asp's 544785, 5961660) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 9457 feet Plugs (measured) true vertical 6585 feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 121' 16" 232 sxAS ~ 121' 121' SUR. CASING 4439' 7-5/8" 690 sx AS III Lead. 400 sx Class G tail 4557' 3822' PROD. CASING 8654' 5-1/2" 230 sx Class G 8772' 6060' LINER 678' 3-1/2" see above 9450' 6579' Perforation depth: measured 9156-9176' MD true vertical 6351-6367' TVD Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 3-1/2", 9.3#. L-80 Tbg @ 8772' MD. Baker GBH-22 Locater Seal Assembly CAMCO 'DS' @ 495' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure RECEIVED FEB i ? 2003 Alaska Oil & Gas Cons, Cu,~missio[~ Anchurage 14. Prior to well operation Subsequent to operation OiI-Bbl 27O Representative Daily Average Production or Iniection Data Gas-Md Water-Bbl 113 26 Not on line yet Casing Pressure Tubing Pressure 138 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil__ X Gas_ Suspended_ Service _Water Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. MJ Lo velan~ v./ Form 10-404 Rev 06/15/88 · Questions? Call MJ Loveland 659-7224 Date ~'~:> ~ Prepared b~/ MJ Loveland 659-7224 SUBMIT IN DUPLICATE SUNDRY NOTICE 10-404 ConocoPhillips Kuparuk Well 1F-19 Tubing Patch November 24, 2002 ConocoPhillips Alaska, Inc., Kupamk well 1F-19 (PTD # 196-052). Set a 3.5" x 21.5' permanent patch across GLM #3. The top of the patch is 6612.5' and bottom is 6634'. Patch ID is 2.375". PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA PLUS Page: 1 Date: 05/13/98 RUN DATE RECVD 96-052 96-052 96-052 96-052 CBL 7099 ARC 5 ARC 5 L SEPIA ~L SEPIA ~BL 1 04/26/96 05/07/96 1/2 05/07/96 1/2 05/20/96 10-407 ~R~COMPLETION DATE )-/P0 ~,6 / DAILY WELL OPS R ~/15'/~ / TO f/~ 0/~[~/ Are dry ditch samples required? yes <~~And received? Was the well cored? yes ~Analysis & description received? Are well tests required? yes ~_Received? Well is in compliance Initial COMMENTS Y~ State, Alaska Alaska Oil & Gas Conservation Comm. Atten: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Transmittal of Final Prints. Please sign and return copy to: Western Altas Logging Services Pouch 340013 Prudhoe Bay, AK 99734-0013 26-Jan-97 Well Name Services Bluelines Sepia Film DS 1 8-1 5 A PDK/GR/CCL (BORAX) 1 1 0 Received by: t,~ Date Contact Rebecca Lange if you have a question concerning this transmittal at (907) 659-2816 or Fax (907) 659-2602. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 August 29, 1996 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 9950 ! Subject: 1F-19 (Permit No. 96-52) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU IF-19. If there are any questions, please call 263-4622. Sincerely, W. Isaacson Drilling Engineer Kuparuk Drill Site Development WSI/skad RECEIVED AUG ,3 0 1996 Alaska 0il & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION ,.,OMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well OIL ~] GAS E~] SUSPENDED [--'-] ABANDONED [] SERVICE 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 96-52 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22660 4 Location of well at surface ~ C0i.,'iPLi'~';;_~?.] !~' 9 Unit or Lease Name 668' FNL, 91' FEL, Sec. 19, T11 N, R10E, UM ~ _ ~/;A i~ Kuparuk River Unit At Top Producing lnterva, ~-~-~~i !i ~,~ ![ i10 WellNumber 1938'FSL, 783'FEL, Sec. 17, T11N, R10E, UM ! ~--'.~¢~ ! 11 Field and Pool At Total Depth .:.~_. =. .... ~' - _ .~,.-,~. 2103' FSL 442' FEL, Sec. 17, T11N, R10E, UM KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. Rig RKB 41', PAD 77' ADL 25652 ALK 2578 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 15 Water Oepth, if offshore I16 No. of Completions 14-Mar-96 23-Mar-96 20-Ma¥-96 (pen"d) NA feet MSLI 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 120 Depth where SSSV set I 21 Thickness of permafrost 9385' MD & 6529' TVD YES X~ NO ~-]I NA feetMDI =1380'ss APPROX 9457' MD & 6585' TVD 22 Type Electric or Other Logs Run ARCS/GR,GR/CCL/CBT 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT F~CORD 16" 62.5# H-40 SURF. 121' 24" 232 sx AS I 7.625" 29.7# L-80 SURF. 4557' 9.875" 690 sx AS III Lead, 400 sx Class G Tail 5.5" x 3.5" 15.5#/9.3# L-80 SURF. 9450' 6.75" 230 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 (MDI PACKER SET (MDI 3.5" 8772' 9156'-9176'MD 4 spf 6351'- 6367'TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9156'- 9176' total 201.2M# LDC (10M# 20/40 and 191.2M# 12/18) 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 7/26/96I Gas lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 8/15/96 11.80 TEST PERIOD ¢ 10 3 0 8 176I 0 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 144 11 69 24-HOUR RATE I~ 209 0 16 ,,24o 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Subrnit core chips. REC[IVED ORIGINAL Alaska 0il & Gas Cons. Commission Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE -, .. 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. .... Top Kuparuk C 8864' 6128' Bottom Kuparuk C 8947' 6191' Top Kuparuk A 91-08' 6314' Bottom Kuparuk A 9258' 6430' FREEZE PROTECT ANNULUS WITH DIESEL 31. LIST OF ATI'ACHMENTS Directional Survey, Daily Drilling History 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 8/14/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 1 WELL:iF-19 RIG:PARKER 245 WELL ID: AK8469 AFC: AK8469 TYPE: STATE'ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:03/14/96 START COMP: BLOCK: FINAL: WI: 0% SECURITY:0 AFC EST/UL:$ lll0M/ 1330M API NUMBER: 50-029-22660-00 03/15/96 (1) TD: 271' (271) SUPV:RLM DAILY' 03/16/96 (2) TD: 3677' (3406) SUPV:RLM DAILY: 03/17/96 (3) TD: 3940' (263) SUPV:RLM DAILY: 03/18/96 (4) TD: 4568' (628) SUPV:RLM DAILY: 03/19/96 ( 5) TD: 4568' ( 0) S UP V: RLM DAILY: 03/20/96 ( 6) TD: 6827' (2259) SUPV: RLM DAILY: 03/21/96 ( 7) TD: 8568' (1741) SUPV:RLM DAILY: MW: 9.0 PV/YP: 24/30 APIWL: 10.0 DRILLING Move rig to DS 1F-19. Accept rig at 1600 hfs 3/14/96. $117,002 CUM: $117,002 ETD: $0 EFC: $1,227,002 MW: 10.0 PV/YP: 53/35 APIWL: 3.3 CIRCULATE Directional drill 9.875" hole from 271' to 3677' $83,865 CUM: $200,867 ETD: $0 EFC: $1,310,867 MW: 10.1 PV/YP: 48/43 APIWL: 3.9 DRILLING Circulate, pump hi-vis sweep and increase vis from 65 to 80 due to small amount of running PEA gravel. POOH. Pulled to 3212', free. Work pipe and pull slow through tight hole to 2654'. Back ream and work through tight hole to 2392', sticky and packing off. Drill from 3677' to 3862'. Attempt to lower mud temp with large volumes of cold water. No change in temperature. POOH, to 2480' free. Back ream and work through tight hole from 2480' to 1400'. RIH to bottom at 3862', no fill. Drill from 3862' to 3940'. Hole occasionally sloughing large amounts of sand and pea gravel due to high mud temp. $89,926 CUM: $290,793 ETD: $0 EFC: $1,400,793 MW: 10.2 PV/YP: 54/45 APIWL: 3.5 RUNNING CASING Directional drill 9.875" hole from 3940' to 4568'. Held pre-job safety meeting. Run 7-5/8" casing. $74,288 CUM: $365,081 ETD: $0 EFC: $1,475,081 MW: 0.0 PV/YP: 4/ 4 APIWL: 20.0 DRILLING Continue to run 7-5/8" casing to 4557'. Cement casing. CIP at 1042 hrs. 3/18/96. Test BOPE equipment. Tag cement at 4217' to 4323' $184,867 CUM: $549,948 ETD: $0 EFC: $1,659,948 MW: 8.7 PV/YP: 13/11 APIWL: 8.0 DRILLING @ 7350' Drill cement from 4323' to 4448' Test casing to 2000 psi. · Drill cement from 4448', float collar at 4470' cement, float shoe at 4457' and 10' new hole to 4578' Perform FIT , · to 12.5 EMW. Directional drill from 4578' to 6827'. $77,215 CUM: $627,163 ETD: $0 EFC: $1,737,163 MW: 10.9 PV/YP: 16/20 APIWL: 5.6 DRILLING @ 8815' Directional drill 6.75" hole from 6827' to 8568'. $101,661 CUM: $728,824 ETD: $0 EFC: $1,838,824 Date: 8/14/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 2 03/22/96 (8) TD: 9040' (472) SUPV:RLM DAILY: 03/23/96 (9) TD: 9457' (417) SUPV:RLM DAILY: 03/24/96 (10) TD: 9457' ( 0) SUPV: RLM DAILY: MW: 11.0 PV/YP: 22/18 APIWL: 4.6 RUNNING IN HOLE @ 4593' Directional drill 6 75" hole from 8568' to 9040'. Well started taking +/-1~ bpm at 1630 hrs, added additional 2 ppb barofiber fine. CBU. Pump out from 9040' to 8120' (precautionary). The trip out was free. $110,442 CUM: $839,266 ETD: $0 EFC: $1,949,266 MW: 11.0 PV/YP: 22/17 APIWL: 4.8 RUNNING IN HOLE W/CSG @ 4150' Wash from 8444' to 9040'. Directional drill 6.75" hole from 9040' to 9457' After penetrating "A" sand, well began taking +/- 30 bbls. fluid per hour. Added 3 ppb barofiber fine. Pump out to 8764' RIH, free, no fill. Drop single shot survey. Pump out to 8210' (precautionary). POOH. Retrieve survey. $78,099 CUM: $917,365 ETD: $0 EFC: $2,027,365 MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 DRILLING ON 1F-20 @ 270' Held pre-job safety meeting. RIH w/20 jts 3.5" casing. RIH w/5.5" casing to 9450'. Lost mud. Cement casing. CIP @ 1656 hrs. 3/23/96. Freeze protect annulus. Release rig 3/23/96 @ 2400 hrs. $172,854 CUM: $1,090,219 ETD: $0 EFC: $2,200,219 Date: 8/14/96 ARCO ALASKA iNCORPORATED WELL SUMMARY REPORT Page: 3 REMEDIAL AND COMPLETION OPERATIONS WELL:iF-19 RIG:PARKER 245 WELL ID: AK8469 AFC: AK8469 TYPE: STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:03/14/96 START COMP: BLOCK: FINAL: WI: 0% SECURITY:0 AFC EST/UL:$ lll0M/ 1330M API NUMBER: 50-029-22660-00 05/07/96 (11) TD: 9457' PB: 9385' SUPV:DEB DAILY: MOVE EQUIP.-RIG %1 TO RIG MW: 0.0 DOILSW Move rig from 2X pad to IF pad. Transfer tools and equipment from Rig %1 to Rig %2 and prepare to change out rigs. $25,667 CUM: $1,141,553 ETD: $0 EFC: $2,251,553 05/08/96 (12) TD: 9457' PB: 9385' SUPV:DEB DAILY: RIG UP & NU BOPE ND tree. NU 7-1/16" BOP stack. $17,000 CUM: $1,175,553 ETD: MW: 0.0 $0 EFC: $2,285,553 05/09/96 (13) TD: 9457' PB: 9385' SUPV:DEB DAILY: WORK ON HYD CHOKE, PREP T MW: 0.0 Finish NU BOPE. Function test BOPE. Pre-test BOPE to 3500 psi. All other BOPE tests good. Continue rigging up around rig. $17,000 CUM: $1,209,553 ETD: $0 EFC: $2,319,553 05/10/96 (14) TD: 9457' PB: 9385' SUPV:DEB DAILY: RUN 3.5" COMPLETION ASSY MW: 0.0 Accept rig @ 0600 hrs. 5/9/96. Test BOPE. Ail components OK. Test 5.5" casing to 3500 psi for 30 minutes, no loss. Run 3.5" single completion assembly. $31,200 CUM: $1,271,953 ETD: $0 EFC: $2,381,953 05/11/96 (15) TD: 9457' PB: 9385' SUPV:DEB DAILY: RIG RELEASED MW: 0.0 Run 3.5" completion assembly to 2125' Test tubing to 3500 psi for 30 minutes, OK. Test annulus to 3500 psi for 15 minutes, OK. Set BPV. ND stack. NU tree. Test tree & packoff to 250 psi & 5000 psi, OK. Secure well. Release rig @ 0600 5/11/96. $150,999 CUM: $1,573,951 ETD: $0 EFC: $2,683,951 End of WellSummary for Well:AK8469 RECEIVED AU6 3 0 1996 Alaska 011 & Gas Cons. Commission Anchorage ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1F-19(W4-6)) WELL 1F-19 DAI E 05/20/96 DAY 1 JOB SCOPE PERFORATE, PERF SUPPORT DAILY WORK PERFORATE 'A' SAND OPERATION COMPLETE J SUCCESSFUL YES~ YES Initial Tbg Press I Final Tbg Press ! Initial Inner Ann 0 PSI! 100 PSI! 0 PSI JOB NUMBER 0506960858.6 UNIT NUMBER KEY PERSON SUPERVISOR SW~-,IOHN,C;C)N PAI~E Final Inner Ann I Initial Outer Ann ] Final Outer Ann 0 PSII 0 PSI! 0 PSI DALLY SUMMARY iPERFORATED 'A' SAND INTERVAL 9156'-9176' USING 2-1/2" HOLLOW CASE CARRIER W/ALT BH/DP CHARGES, 180 DEG PH, ORIENTED 54 DEG Ccw AND 126 DEG CW F/THE HIGH SIDE , TIME LOG ENTRY 08:00 MIRU SWS. HELD SAFETY MTG. 10:30 11:30 11:5o PT LUB TO 3000#; TEST OK. RIH W/CCL, MPD, 2-1/2" HOLLOW CASE CARRIER W/ALT BH/DP CHARGES, 4 SPF, 180 DEG PR, ORIENTED 54 DEG CCW F/HIGH SIDE AND 126 DEG CW F/HIGH SIDE TO SHOOT 9156'-9176' TiED INTO SLTJ DATED 4/;1~J9~ .... WELL WAS BLED TO'APPROX 400# UNDERBALANCEI~ PRIOR TO 'S~OOTING WELL (W~P- 100~) GUN FIRED; POH. 12:00 12:45 AT SURF W/GUN; ALL SHOTS FIRED. 13:30' RDMO, ' ' ' ' ,, PAG£ NOo (~')::'ANY AE~ ALASI(A. INC. WELL NAM£ 1F-l? LOCATION I I(UPARU~ LOCATION 2 ALAS~ MAGNETIC DECLINATION 27.88 WELL NUMB~ ~ AI(8469 APl WI~uL NO: 50-029-22660 WEll, HEAD LOCATI~: LAT(N/-S) 0.00 D~P(E/-W) O,O0 TIE IN POINT(TIP) MEA,S~ED DEP'It.i 121.00 T'AtIE~ DB:q'H 121o00 INCLINATION 0.00 AZIMUTH LATITUDE(N/-S) 0,00 DP..PARTLI~£(iP../-W) 0,00 AZII~ ~ Rq]TARY TABLE TO TAR~h"'I' IS 59.57 !F-i; ~]E~E¥ CALCULATIONS **~::~******* CIE~UL4R ARC METHOD******** k'~qSURED IHT~.$AL VERTICAL DEPTH D~PTH ft ft f~ 121,00 0.0 121,00 466.15 345.2 ~6.15 837,~ 371,1 837,22 1200.27 ?~.3,1 1200,28 1570.01 ~9.7 1569,98 TARGET ~ATION AZI~TH LATI~JDE SBCTION iNCLN. N/-S f~ dec Eeo f~ 0,00 0.00 0.00 0.00 0,65 0,22 70,32 0,22 2,40 0.38 91.20 0,43 5,25 0,63 83.42 0,64 8,13 0,33 77,28 1.1I D~AR~JRE DISPLACE~NT at AZIMtXrH DLS Z/-W ft ft deg lOOft 0.00 0,® 0,00 0,00 0,62 0,66 70,32 0.06 2,52 2,56 80,26 0,05 5,72 5,75 83.65 0.07 8.78 8,85 82.82 0.08 1851.77 15~39.05 2027.14 2122.31 2217.12 281.8 1651,69 87.3 1'KJ8,76 88.1 2025.9? 95.2 2119.04 ?4.8 2210.23 12.60 1.54 72,44 2.43 t8.35 6.08 64.39 4,78 30.5'5 9.87 59.26 10.65 50.38 I4.19 58.58 20,91 76,2~ 17,54 59,00 34,33 13,19 13,41 79.57 0.43 18.47 19.08 75.50 5,22 ~.17 31.06 69.94 4.38 46.15 50.66 65.62 4,54 ~.31 76.46 63.32 3.53 L-~jO?.50 _'2376,19 2489.62 2582,82 2676.13 ?'2.4 2~7.57 86.7 2378,41 ?3.4 2464,69 ?3.2 2549.67 ?3.3 2633,55 106.33 20.42 60.64 49.40 137.63 21.93 62.21 64.37 173.45 ~.20 61,OB 81.40 211,70 25,28 60,59 100,05 ~2o55 26o&6 61,20 119,~2 94.30 106.46 62,35 3,18 121,81 137.77 62,15 1.85 153.35 173.61 62,04 1,44 !86,76 211,87 61.82 2,24 222,46 252.72 61.67 1,51 2768,82 2857,99 2952,21 3043.98 3137,04 92.7 271~,56 89.2 2792,83 94.2 2872.3? ?I,8 ~47.40 93.1 3020.54 295.70 28.87 61,89 140.48 340.17 31.01 61.10 161.73 3~0.62 33.76 60,78 186,24 443.47 36.59 60.93 211,98 500.98 39.77 59.15 240.73 260,42 2~,89 61.66 2.40 2~,52 340,39 61.63 2,45 343.63 390,85 61.54 2.~ 389.80 443.71 61.46 3.~ 439,61 501,21 61,30 3,~. 3229,84 3320.08 3412.48 3504.78 3593,84 ~,8 30~,55 ?0,2 3156,63 92,4 3221.97 -?2,3 3284,11 89.1 3340,79 561,87 42.26 60,62 271,27 623.32 43,60 61.15 301,17 cq58,62 46,37 59,97 333,28 756,84 48.98 61,52 366.61 8~,47 51.95 61.80 399,21 492,30 562,09 61,14 5~,00 623,55 61.12 1.53 602.86 688.86 61.06 3.14 662,40 757,09 61.04 3.09 722.85 825.76 61.09 3.34 3690,86 3783.63 3971,75 4156.I2 4339.39 ?7,0 3397.81 92.8 3447.69 188.1 3540.41 184.4 3626.95 183.3 3714,31 '-703.89 56.04 61,64 436.40 982.02 58.91 62.86 472,81 1145.43 62.02 62,41 548°04 I308,11 62.00 61.27 624,87 1469.14 61.06 61.15 702.46 791.95 904,23 61.14 4.22 861.I8 982,43 61.23 3.28 1006.51 1146.04 61.43 1.~ 11~.04 1308,84 61.48 0.55 1~1.23 1469,94 61.45 0,5'2 4489,2F 4690,77 4968.9I 5245,68 5520.94 149.9 3787.97 201,5 3889,38 278.1 ~3~o81 ~6.8 4183.90 275,3 4317.04 1599,62 60.06 61.22 765.38 1773.72 59.51 59.44 851.57 2010.09 56,96 62,18 966.94 ~43.31 58.35 64,95 !070.97 2482.35 63.78 67,85 1167.22 1~5,59 1600.46 61,43 1556.87 1774,55 61.32 0.81 1763,24 2010.96 61,26 1,24 1972.61 ~44o58 61.50 0,98 2193.31 2484~55 61.98 2,18 5800,96 6077,59 6349,70 6906.60 280.0 4443,68 276.6 4573.62 272.1 4707.43 284.2 4855.63 272.7 5000.38 2730.80 62,48 62,55 1271.87 ~74,62 61,49 63,02 1383.55 3211,25 59.60 61,70 1493.44 3453.64 57.54 60.12 1611,29 3684.72 58.35 61,26 1724.42 2419,97 2733.84 62,27 1,75 2637.13 2978.04 62.32 0,3? 2847.03 3214,96 62.32 0,81 3058.72 3457.35 62.22 0,87 ~60.46 3688.3? 62,13 0,46 RECEIVED AUG 5 0 1996 Alaska Oil & Gas Cons. Commi~mion Anchorage ir-l: ************* ANADRILL ************** SURV~ CALCJJLA?IONS ***********~* CIRCLrLAR AEC M~THOB******** MF~AS~JR~INTF]WAL VERTICAL DEPTH DB~H ft ft ft 7183.37 276,8 5137.66 74~.35 225.0 5269,48 ~37.17 ~8,8 5415,~ ~I1,85 ~4,7 ~9,59 8198,12 I~,3 56~,72 TARG~ S?A?I~ AZIP~JTH SECTION INCLN. ft deo deo 3¢24.f5 62,19 57.28 4166,13 60.52 58.43 4403.31 56.13 4627,44 53.83 52,04 4773.82 52,91 53.20 T ~TL~ D~'~TL~:~ ~SPL~T a~ ~ZZI~H N/-S ~/-W deQ/ ft ft ft deo lOOft i847,31 3466,89 .S'928.34 61,95 1,87 !775,67 ~71.i8 4169.04 61.71 0,71 2099.77 g73.38 4405,91 61,54 1.57 2227,66. 4058,18 46.29.40 61,24 2,I0 2318,42 4!76,76 4777.24 60.?7 0,70 8378,76 8471,86 8558.(>6 8656.07 8843, I8 180,6 5'794.60 4917.73 52,17 50.73 ~.1 5851.78 4??0,87 52,06 54.91 96,2 5912,98 5064,60 48,~ 51,41 ~8,0 5973,85 5127,70 43,53 54.71 187,1 6112,43 5253,27 40,95 61,28 2406.74 4289,8? 4918,90 60,71 2451,13 4348,40 4991,66 60.59 24~,58 4407,81 5065,25 60,48 2533.82 ~58.53 5128.23 2600.55 45.54.96 5253.73 60.33 1,16 3,54 6,71 2,73 9023.32 9212.93 935"7.64 9457.00 180,1 6249,34 189,6 6395,22 144,7 6507,57 PROJ~ 99,4 6584,91 5370,07 40,15 65,38 2653,12 5490,83 9,26 62,41 2706,38 5581,77 38,89 65,36 2746,53 5643,83 38,89 65.36 2772.53 4669.54 5370,63 60.40 1,54 4778,31 5491,51 60.47 1,10 ~860.20 5582°55 60.53 1.31 4916.89 5644,71 60,58 0,02 ARCO Alaska, Inc. Date: May 13, 1996 Transmittal #: 9688 RETURN TO' ARCO ~ '"~"" /~.,~, irc. Attn.' Juiie Nash Kuparuk Ooerations File Clerk ATO-! ! !9 B P.O. Sox i00360 Anchorage, AK 99510-0360 Transmitted below are the following open hole items. Please acknowledge receipt and return one signed copy of this transmittal. qj'"-I ~ 1 Q-22 q&---~Z, 1F. 19 ,-/r~l ~ 3H-24 (3H-28 ~t6-6 lg '~3H-28 Acknowledged: ARC 5 I O/O9/95 ARC 5 03/22/96 CDR O2/04/96 CDR 02/13/96 4957-8790 4568-9457 50-103-20235-'00 50-103-20236-00 50-103- 20236-00 Date: ,,^,, 20 1996 DISTRIBUTION: Mr. Vernon E. Pringle Jr. DeGIoyler and MacNaughton One Energy Square Dallas, TX 75206 Sharon Allsup-Drake DS Development ATO - 1205 A!aska Oil & Gas Cons. .. Clifton Posey Geology ATO - 1251 ChapmanZuspan NSK Wells Group NSK 69 Larry Grant AOGCC 3001 Porcupine Drive Anchorage, AK 99501 MEMORANDUM TO: THRU: David Jpt~on, Chairma~ BlairWondzeii, '¢'"'~ ' '2., ~,,u P. !. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission DATE: May 10, 1996 FILE NO: AAVJEJDD.DOC FROM' Lou Grimald~,-:--;-'-'~ SUBJECT' Petroleum Inspector BOPE Test Nordic rig ¢2 Arco well ¢1F-19 Kuparuk River Field PTD ¢96-52 Friday, May 10, 1996: i witnessed the initial BOPE test on Nordic rig ¢2 which was completing Arco well ¢1 F-19 in the Prudhoe Bay Field. The rig was ready to test when i arrived. This was the first test for this new rig that has been stacked in Deadhorse. The test once started went well. I observed failures on the HCR valve and check valve isolating the reversing line from the Choke line. The H2S and Methane detectors were tested and although initially they tested out OK the methane detectors panel readout became unstable and will be replaced. The reversing line will be disconnected from the Choke line during the next rig move. This rig should do quite well and seemed to have had much thought during its building. SUMMARY:. I witnessed the initial BOPE test on Nordic rig ¢2. There were three failures. Test time 6 hours. Three failures. Attachments: AAVJEKDD.XLS CC: Mike Zanghi (Kuparuk Drilling Eng.) STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: Test: Initial Set @ X Weekly Other Workover: 'X DATE: Nordic Rig No. 2 PTD # 96-52 Rig Ph.# ARCO Alaska Inc. Rep.: Don Breden 1F-19 Rig Rep.: Lance Johnson Location: Sec. 19 T. 11N R. IOE Meridian Umiat 5/10/96 659-7115 TEST DATA MISC. INSPECTIONS: Location Gen.: Housekeeping: PTD On Location Standing Order Posted BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve ~IUD SYSTEM: Trip Tank Pit Level Indicators Flow Indicator Meth 'Gas Detector H2S Gas Detector P Well Sign P P (Gen) Drl. Rig P P Hazard Sec. P P Quan. Test Press. P/F I 25O/30OO P 500/3500 P 500/3500 P 50O/35OO P 500/3500 P 500/3500 F 500/3500 P 500/3500 F Visual Alarm P P P P P P F P P P FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F 500/3500 500/3500 1 500/3500 P 1 500/3500 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes 16 Test Pressure P/F 500/3500 P 38 500/3500 P I P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure 0 System Pressure Attained 0 Blind Switch Covers: Master: Nitgn. Btl's: Four Bottles 2300 Average 3,000 I P 2,900 P minutes 23 minutes 55 P Remote: Psig. sec. sec. P TEST RESULTS Number of Failures: 3 ,Test Time: 6,0 Hours, Number of valves tested 22 Repair or Replacement of Failed Equipment will be made within N/A days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspectOr within 12 hours please cOntact the P. I. Supervisor at 279-1433 I REMARKS: Initial test for well and rig. Methane detectors functioned but panel display was unstable and was replaced."' UpPer and lower Kelly will be tested when kelly is assembled and picked up.'7-1CR valve had slight leak, Repair and retest. Check valve on reversing line leaked, this valve will be isolated from clmke line/manifold after this well. ~- Distribution: orig-Well File c- Oper./Rig c - patabase c - Trip Rpt File c- Inspector STATE WITNESS REQI. JlRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Louis R. Grirnaldi FI-021L (Rev. 12/94) AAVJEJDD.XLS GeoQuest 500 W. InternatiOnal Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 1O173 Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 5/6/96 Field: Kuparuk (Open Hole) Well Job # Log Description Date BL RF Sepia DIR MWD 3H-24 ,..'r I,, - G l,-- 3H-28 3H-28 ~ 9534O 96099 96O73 96087 96087 96087 ARC5 ARC5 CDl't CDFi/CDN 951009 960322 960204 960213 96O213 960213 1 ,'"'" LIS Tape SIGNED- Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. [)ATE: ARCO Alaska, inc. Date' April 23, 1996 Transmittal #: 9673 RETURN TO: ARCO Alaska, Inc. Attn.: Julie Nash Kuparuk Operations File Clerk ATO-1119B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following Cased Hole items. receipt and return one signed copy of this transmittal. %-o,~;z. 1F.19 q~%t ~"~ 1Q-21 '~ ¢l,-f. ol Q-22A ~-'../?/4 2X- 17 ~..-e~ ¢ 3H-24 Receipt Acknowledge: DISTRIBUTION: · Cement Bond Log SLTJ-GR/CCL Cement Bond Log SLTJ-GR/CCL Cement Bond Log SLTJ-GR/CCL Cement Bond Log SLTJ~GR/CCL Cement Bond Log SLTJ-GR/CCL 04/12/96 04/14/96 04/14/96 04/11/96 04/14/96 Date' Sharon AIIsup-Drake DS Development ATO-1205 Larry Grant (+sepia) AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Please acknowledge 6682-9356 9155-10318 8172-9383 6000-7644 10910-11912 Chapman/Zuspan NSK Wells Group NSK69 TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907)279-1433 FAX: (907) 276-7542 March 7, 1996 Michael Zan'~ Drill Site Develop Supv ARCO Alask,% Inc. P O Box 100360 Anchorage, AK 995 I0-0360 Kupamk River Unit 1F-19 ARCO Alaska, Inc. Permit No: 96-52 Sar. Loc. 668'FNL, 91'FEL, Sec. 19, TI1N, R10E, UM Btmhole Loc. 2256'FSL, 380'FEL, Sec. 17, T1 IN, R10E, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Comm/ssion petroleum field inspector on the North Slope pager at 659-3607. BY ORDER OF THE COMMISSION dlf/Enclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o incl. ~TATE OF ~ ALASKA OIL AND GAS CONSERVATION COMMI~o,ON PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill D lb Type of Well Exploratory E] Stratigraphic Test BI Development Oil X Re-Entry D Deepen [~ Service D OevelopmentGas D Single Zone X Multiple Zone BI 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 77' feet Kuparuk River Field 3. Address 6. Properly Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25652, ALK 2578 4. Location of well at surface 7. Unit or property Name 1 1. Type Bond (see 2o AAC 25.025) 668' FNL, 91' FEL, Sec. 19, T11N, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET) 8. Well number Number 2144' FSL, 571' FEL, Sec. 17, T11N, R10E, UM 1F-19 #U-630610 At total depth 9. Approximate spud date Amount 2256' FSL, 380' FEL, Sec. 17, T11N, R10E, UM 3/1 1/96 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in properly 15. Proposed depth (MD and TVD) properly line 1 F-1 6 9619' MD 380 @ TD feet 75.6'@ 1200' feet 2480 6618' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 1 800' feet Maximum hole angle 60.6° Maximumsudace 2233 psig At total depth (TVD) 3400 pslg 18. Casing program Settin~l Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' +_200 CF 9.875" 7.625" 29.7# L-80 LTC 4407' 41' 41' 4448' 3772' 690 Sx Arcticset III & 400 Sx Class G 6.75" 5.5" 15.5# L-80 LTCMOE 8895' 41' 41' 8936' 6096' 230 SxClassG 6.75" 3.5" 9.3# L-80 EUESrdM 683' 8936' 6096' 961 9' 661 8' Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Intermediate Production Liner r; ~ ~', r3 0 "~- ';':" Perforation depth: measured true vertical ~;,.!,;:.i.ii'.'.,? ;..'i¢ii ~i~ :.';'-"'L; ~';.' ,;':.. ;i;' 20. Attachments Filing fee X Property plat D BOPSketch X Diverter Sketch X '" Ddlling program X Drilling fluid program X Time vs depth plot BI Refraction analysis I--I Seabed report D 20 AAC 25.050 requirements X 21. I hereby cedify ti]bt the foregoing is true and correct to the best of my knowledge Signed T~le Drill Site Develop. Supv, Date \_~/., } Commission Use Only Permit Number - l iAl~ number ~ ~ ~ Approval date ..~ ..~ I See cover letter for I 0-o.z?- 2. z I J~I other requirements Conditions of approval Samples required ri Yes ~ No Mud log required BI Yes !~ No Hydrogen sulfide measures [~ Yes BI No Directional survey required ~ Yes D No Required working pressure for BOPE D 2M ~ 3M BI 5M ri 1OM BI 15M Other: ,~,~,,,~,,,,~,~ ~t¢.~od~. ~.~,~'¢~¢~('~ ~ D vir Johnston by order of Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplicate · , , , o o , , . 10. 11. 12. 13. 14. 15. 16. 17. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD KRU 1F-19 Move in and rig up Parker #245. Install diverter system. Drill 9-7/8" hole to 7-5/8" surface casing point (4,448')according to directional plan. Run and cement 7-5/8" casing. Install and test BOPE to 3000 psi. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 6-3/4" hole to total depth (9,619') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 5-1/2" x 3-1/2" tapered casing string with polished seal bore as part of XO. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) ND BOPE. NU tubinghead & either full opening valve (if logging planned) or master valve and upper tree assembly (if no logging planned). Note: As a dedicated producer, no cased hole cement bond logs will be run unless there are problems with the cement job. Secure well and release rig. Move in and rig up Nordic #1. Install and test BOPE. Pressure test 5-1/2" x 3-1/2" casing to 3500 psi. Run completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig in preparation for perforating. DRILLING FLUID PROGRAM Well KRU 1F-19 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 15-40 10-12 9.5-10 _+10% Drill out to weight up 8.4-9.6 5-15 5-.8 30-40 2-4 4-8 8-10 9.5-10 4-7% Weight up to TD 11.1 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators General Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 2,233 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest existing well to 1F-19 is 1F-16. As designed, the minimum distance between the two wells would be 75.6' @ 1200'. Drilling Area Risks: Risks in the 1F-19 drilling area include lost circulation and high pressures in the Kuparuk formation. Lost circulation above the Kuparuk will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. 5-1/2" casing will be topset above the Kuparuk and either Nordic Rig #1 or a coiled tubing unit will drill out a 4-3/4" hole, and run a 3-1/2" liner to TD if lost circulation cannot be controlled with LCM and reduction of circulating pressure alone. Efforts to reduce Kuparuk geopressure at the target location and careful analysis of pressure data from offset wells show that a mud weight of 11.1 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 7-5/8" casing shoe will be tested to an equivalent mud weight of 12.5 ppg upon drilling out of the surface casing. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. ANNULAR PUMPING OPERATIONS WELL KRU 1F-19 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. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 1F-19 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, the annulus will later be sealed with cement from the surface shoe to the base of the permafrost, with Arctic pack fluid or diesel from the base of the permafrost to the surface, if the surface shoe is within 200' TVD of the top of the hydrocarbons. Alternatively, if the hydrocarbons are far below the shoe then sufficient cement volume will be pumped during the production cement job to cover the formation. It is requested that 1F-19 be permitted for annular pumping occurring as a result of the drilling project on DS 1F, 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 1F 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 --- 3850 psi 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 7.625 29.7 L-80 3 LTC 4790 4072 6890 5 8 $.___Z7 ~.500 15.5 L-80 3 LTC-M 4990 4242 7000 5950 Fluids to be disposed of in subject annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (g) (1) & (2). ~ ......... ~: ~'"~:.--~ '~i":'~ i'-.-.~,? ARCO ALASKA, Inc. Pad 1F 19 slot #19 Kuparuk River Unit North Slope, Alaska CLEARANCE REPORT by Baker Hughes [NTEQ Your ref : 19 Version #5 Our ref : prop1465 License : Date printed : 22-Feb-96 Date created : 29-Nov-95 Last revised : 22-Feb-96 Field is centred on nTO 16 18.576,w150 5 56.536 Structure is centred on nTO 18 1.316,w149 40 34.63 Slot location is nTO 17 54.746,w149 40 37.283 Slot Grid coordinates are N 5958859.116, E 539881.982 Slot local coordinates are 66~.00 S 91.00 W Reference North is True North Main calculation performed with 3-D Minin~Distance method Object we[[peth PGMS <O-8715'>,,1,Pad 1F PGM$ <O-8085'>,,2,Pad 1F PGMS <O-8002'>,,4,Pad 1F PGM$ <O-7710'>,,5,Pad 1F GMS <O-98~7'>,,6,Pad 1F PMS$ <O-7681'>v,7,Pad 1F PGMS <O-7492'>,,8,Pad 1F PC~lS <O-7600'>,,9,Pad 1F PGMS <O-7680'>,,lOvPad 1F PGMS <O-8787'>,,11,Pad 1F PGMS <O-6840'>,,12,Pad 1F PGMS <O-8235'>,,13,Pad 1F PGMS <O-8160'>,,14,Pad 1F PGMS <O-68~2'>,,15,Pad 1F PGMS <O-9175m>,,16,Pad 1F PGM$ <O-6712'>,,3,Pad 1F 18 Version #7,,18,Pad 1F 20 Version #6,,20,Pad 1F 17 Version ~5,,17,Pad 1F Closest approach with 3-D minim[zn distance method Last revised Distance M.D. Diverging frown M.D. 4-Aug-92 361.1 1600.0 1600.0 4-Aug-92 657.5 1000.0 1000.0 4-Aug-92 879.3 100.0 5320.0 4-Aug-92 208.3 2450.0 3775.0 4-Aug-92 399.0 1600.0 4180.0 4-Aug-92 673.6 1200.0 1200.0 4-Aug-92 794.5 100.0 1850.0 4-Aug-92 390.4 800.0 8507.5 4-Aug-92 415.3 100.0 800.0 4-Aug-92 440.7 400.0 9420.0 4-Aug-92 363.2 2125.0 2125.0 4-Aug-92 282.2 600.0 600.0 4-Aug-92 189.9 6480.0 6480.0 4-Aug-92 162.5 1468.0 2125.0 4-Aug-92 75.6 1200.0 1200.0 4-Aug-92 768.9 1500.0 1825.0 20-Feb-96 385.5 600.0 600.0 21-Feb-96 14.1 300.0 9600.0 20-Feb-96 282.6 1800.0 1800.0 ARCO ALASKA, inc. Creot~d by : ..;o,~ For: D PETRASHi iOote plaited : 22--Feb-95 :P!ol: Reference is 19 Version ~5. i Coord}no[es ore {n fee~ mfe~nce sial ~19. T~e Ve~col ~pths ore r~f~r~n~ RKB (Po~er ~245). ~ 400 _ 0 o C'4 0 _ 400 800 __j 1200_ ('-' 1600_ -t---- CL - 2000_ _ 24-00~ 0 2800 _ 3200_ 5600_ - 4000_ I 4800_ V - 5200_ Structure : Pad 1F Well : 19 5600_ _ 6000_ 6400_ 6800_ Field : Kuporuk River Unit Location : North Slope, Alaska' tN 59.64 DEC, E 5563' (TO TARGET) Scale 1- 250.00 East > 500 0 500 1000 1500 2000 2500 5000 3500 4000 4500 5000 5500 TD LOCATION: ~ h3000 2256' FSL. 380' FEL ~ 2 RKB ELEYATION: 118' SEC. 17. T11N, RIOE ~¢¢~ _2500 ../' % _ ~500 / TARGET LOCATION: //~ 2144' FSL, 571' FEL B/ PERMAFROST ~D=1468 /~ ~ ~ %; SEC. i7. T11N, RIOE xo~ W~=l~OO ~D=~aoo ~=o ~ - % ~ ~=~ss % ~ ~ TMD=9276 - e.oo ~ _ ¢ [ ~ ~ o~ ~ 12.00 ~ e % ~ST 4800 ESTIMATED ~2.00 T/ W S~ SNDS ~=3084 TMD=3208 DEP=496 ~RIOE 8.~ ~4.00 ~0.00 EOC ~D=3464 TMD=3820 DEP=973 B/ WEST SAK SNDS ~0=5572 TMD=4040 DEP=1 ]64 7 5/8" CSG PT ~D=5772 TMD=4448 DEP=~519 COLVILLE ~VD=4016 TMD=4945 DEP=1955 MAXIMUM ANGLE 60.61 DEG 8/ COLVILLE WD=5158 1MD=725~ DEP~ BEGIN~GLE DROP ~=f1520IMD=8010 DEP=~623 ~ ~o.oo 56.00 DRoP 2 DEG / ~00' x 52,00 HRZ MiONO}NI WD=595~ IMD=8705 DE~=5182 ~ =8.00 ~q~" ~ ~/~ u - ~ ~. dK-1 MARKER WD=6096 TMD=8956 0EP=5.54.5 l/ KUPARUK (EOD) B~0=6~75 IMD=904] DEN=54)2 '%, 4~.o0 Y/ UN]TC WD=6178 ~MD=9045 DEP=5415 T/ UNiT 8 WD=6240 IM0=9126 DE~=5467 TARGET - T/ UNIT A TVD=6355 TMD=9976 DEP=5563 T/ UNIT A4 WD=6584 i Ii !i I I I i I ~ ~ i ! I I I I ; I I I i I ! I J I I [ i i i 400 0 400 800 1200 1600 2000 2400 2800 5200 3600 4000 4400 ':800 5200 5600 6000 Scoie i ' 200.00 Verfical Section on .59.64 azimufh wifh reference 0.00 N, 0.00 E from slof #19 A I I Z J_,ooo 0 -- _ 500 ~'- ARCO ALASKA, Inc. o O Structure : Pad 1F Well : 19 created by : ;o~.~s For: D PETRASH:. .Dote plotted : 22--Feb--9§ : Plot Reference is 19 Ve~ion ~5. Field : Kuporuk River Unit Location : NorthSlope,Alaska : C~rdM~les are in feet ~ference slo~ ~lg. ;T~e Ve~col ~pths ore r~f~r~n~{ RKB (Po~er ~245).~ Scol 00 East > 40 0 40 ~0 120 160 200 2~ 280 320 360 400 ~4U 480 520 550 600 600 ~ I I~ I I 1 I I I { t I J [ i i I J I I I I I I I i I I I I I I I J _ 600 560 _. / 560 - / 520 _ ~2 ~ 520 ~ / 900 , 15o0 480 j ~ 480 i ' 440 / .~" , , ~- ," 440 / . ~ 13oo 400 360 / ~ _ 360 ~0o ~4,oo ~ / ,~ / . , ,. ~ %_ ~ soo - / ~ "" / - i ~ N /2300 'N ~ 40 ', ~ ~ 700 / / .. 900 ~ "x-x . 410 0 ~ ] iI i I I ! t I t I [ I I i i f I I i [ ', I t I ' i I I I ~ I 40 0 80 120 i 60 200 240 280 ]20 ~60 400 440 ~0 520 560 600 Scoie! ' 20.00 La S A I I 7 O ARCO ALASKA, in'-, i I Created by : jon~ For: D PETRASH Structure : Pad 1F Well : 19 Field : Kuporuk River Unit Location : North Slope, Alaska i iOote plotted : 22--Feb--96 P!ot Reference is 19 Version Ccordinotes ore in feet reference slot ~lg. ore referenc~ RKB (Porker ~245). True Vertical Depths ~ East --> 600 700 800 900 i000 !!00 1200 !500 1400 ]500 1600 1700 ]800 !900 2000 2100 2200 1800 1700~ 1600t ~soo~ q //.3500 / /}~oo / / / / ,/ / 2OO 800 © !00 .. "5 _1700 _1600 _ _1500 _1400 1300 //41 O0 /'' _ 1300 12o0J / / /../%^ _~200 _ oo aaa J /3~o _ ~oo i / - ~oo j / _ ~oo /3~0/ 0 ~~ ~oo 400 ~oo /~ ~oo / 200 - - 100 .. _ 0 0 0 ', i I I ~ t I i I ~ t I $ i I t I I I i I i i ~ I I I i ', I ~ I 600 700 800 900 1000 !100 1200 1300 1400 !500 ~600 1700 1800 1900 2000 2100 2200 ~o~,~ ~-~o.oo Emsf A I I Z 0 20II KUPARUK RIVER U~.. r DIVERTER SCHEMATIC 6 i4 3 2 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. 20" - 2000 PSI ANNULAR PREVENTER. DKP 11/9/94 L_ 7 6 13 5/8" 5000 F 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. I BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2. CHEC~ 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. INCRF_/LSE PRESSURE TO 3000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE UNE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7.TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. 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 BO'I-I'OM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BAC~OFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 3 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI FOR 3 MINUTES. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRIllING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. VBRS WILL ACC, OMODATE 3-1/2" TO 5-1/2" OR 5" TO 7" PIPE ODS AS APPROPRIATE. 1. 16"- 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8"- 5000 PSI PIPE RAMS 5. 13-5/8"- 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 _IST COMPANY /~,~__ INIT CLASS ./"-'c~,) ~'/. GEOL AREA PROGRAM: exp [] de~ redrll [] serv [] wellbore seg [] / ~e attached .................. ~er appropriate ............... ~11 name and number .............. ~ted in a defined pool ............. ~ted proper distance from drlg unit boundary.. ated proper distance from other wells ..... ~t acreage available in drilling unit ..... led, is wellbore plat included ........ only affected party .............. has appropriate bond in force ......... an be issued without conservation order .... an be issued without administrative approval.. it be approved before 15-day wait ....... Y Y .Y .Y .Y Y Y .Y .Y Y .Y Y REMARKS r string provided ............... ~Y N :asing protects all known USDWs ........ ~Y N adequate to circulate on conductor & surf csg. ~Y N adequate to tie-in long string to surf csg . . . Y N cover all known productive horizons ....... ¥ "N esigns adequate for C, T, B & permafrost .... ~ N tankage or reserve pit ............. ~Y N drill, has a 10-403 for abndnmnt been approved. ~ wellbore separation proposed. ~ N ter required, is it adequate. .'.'.'.'.'.'.'.'.'%Jw N fluid program schematic & equip list adequate .,~ N equate ..................... .~ N Isa rating adequate; test to ~OOO psig. Y~ N .nifold complies w/API RP-53 (May 84) ...... (Y2~' ~ N 1 occur without operation shutdown ....... ~ N ince of H2S gas probable ............ ~ N '.an be issued w/o hydrogen sulfide measures .... Y N/<.z_ :sented on potential overpressure zones ..... Y R' /~ analysis of shallow gas zones .......... ~//N /~, ~; :ondition survey (if off-shore) ........ ~ N name/phone for weekly progress reports .... /. Y N [exploratory only] ~ ENGINEERING: COMMISSION: JDH ~ JDN ~ . ,~7, , ~~ TAB '~' /, ~ Z O 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 simp!ify finding information, informati;3n of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER * * . ****************************** * ............................ . * ....... SCHLUMBERGER ....... * . ............................ * ****************************** COMPANY NAME : ARCO ALASKA, INC. WELL NAME : iF - 19 FIELD NAME : KUPARUK BOROUGH ' NORT~ SLOPE STATE : ALASKA API NUMBER : 50-029-22660-00 REFERENCE NO : 96099 · LIS T~pe Verification Listing Schlumberger Alaska Computing Center 30-APR-1996 1'~ ~ ~2 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 96/04/30 ORIGIN : FLIC REEL NAME : 96099 CONTINUATION # : PREVIOUS REEL : COB94ENT : ARCO ALASKA INC., KUPARUK 1F-19, API #50-029-22660-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 96/04/30 ORIGIN . FLIC TAPE NAME : 96099 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC., KUPARUK 1F-19, API #50-029-22660-00 TAPE HEADER KUPARUK MWD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION BIT RUN 1 96099 KADRMAS MORRISON SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING IF - 19 500292266000 ARCO ALASKA, INC. SCHLUMBERGER WELL SERVICES 30-APR-96 BIT RUN 2 96099 KADRMAS MORRISON BIT RUN 3 ......... 19 lin IOE 668 91 118. O0 118. O0 76.60 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.750 7.625 4557.0 LIS T~pe Verification Listing Schlumberger Alaska Computing Center 30-APR-1996 11 ~ ~2 3RD STRING PRODUCTION STRING Well drilled 18-MAR through 22-MAR-96 with ARC5 only. All data was collected in two bit runs. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 96/04/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED FIERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SU~ff~ARY LDWG TOOL CODE $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (NZEASUREDDEPTH) START DEPTH STOP DEPTH 4479.0 9457.0 BASELINE DEPTH 88888.0 9353.0 9255.0 9237 5 9204 0 9185 0 9155 5 9093 0 9081 5 9066 5 9035.0 8986.5 8944.5 8910.0 8868.5 8857.5 8835.0 8823.5 8815.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... MWD 88889.0 9354.0 9256.0 9237.5 9204.0 9185.0 9156.0 9093.0 9080.5 9066.5 9036.5 8986.5 8945.5 8912.0 8870.O 8858.5 8836.0 8824.5 8816.0 LIS T~pe Verification Listing Schlumberger Alaska Computing Center 30-APR-1996 11~2 PAGE: 8764.0 8764.5 8742.5 8743.5 8622.0 8623.0 8604.0 8605.0 8594.5 8595.0 8586.5 8587.5 8517.0 8518.5 8501.0 8501.5 8490.0 8490.5 8470.5 8471.5 8440.0 8440.5 8426.5 8428.0 8411.5 8412.5 8391.0 8392.0 8369.5 8370.0 8338.0 8338.5 8294.5 8295.5 8230.5 8231.5 8105.0 8106.0 8096.5 8097.0 8066.5 8067.0 8011.5 8012.0 7996.5 7996.5 7953.5 7954.0 7926.0 7926.5 7836.0 7835.5 7809.0 7809.5 7715.5 7716.0 7702.5 7702.5 7615.5 7615.5 7601.5 7601.5 7568.5 7569.0 7491.5 7494.0 7449.0 7451.0 7438.0 7439.5 7418.5 7420.5 7387.0 7389.0 7309.5 7311.0 7294.5 7296.0 7275.5 7277.0 7220.0 7221.5 7165.0 7166.0 7118.5 7119.5 7060.0 7061.5 6979.0 6980.5 6922.0 6923.5 6796.0 6797.5 6737.0 6738.0 4560.0 4560.0 $ MERGED DATA SOURCE LDWG TOOL CODE .............. BIT RUN NO. M~RGE TOP MERGE BASE 1 4479.0 9040.0 LIS T~pe Verification Listing Schlumberger Alaska Computing Center 30-APR-1996 11 ~ ~2 PAGE: 2 9040.0 9457.0 R~VARKS: The depth adjustments shown above reflect the MWD GR to the CBT GR logged by SWS. Ail other MWD curves were carried with the GR. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 40 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 25 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME 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 O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD F/HR O0 000 O0 0 1 1 1 4 68 0000000000 FET MWD HR O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI O0 000 O0 0 1 1 1 4 68 0000000000 RPXXMWD OHM~ O0 000 O0 0 1 1 1 4 68 0000000000 RPX MWD Ot{~ff4 O0 000 O0 0 1 1 1 4 68 0000000000 RPS MWD OH~I O0 000 O0 0 1 1 1 4 68 0000000000 RPM MWD OHIqM O0 000 O0 0 1 1 1 4 68 0000000000 RPD MWD Otff4M O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CBT GAPI O0 000 O0 0 1 1 1 4 68 0000000000 · LIS T~pe Ve~=fication Listing Schlumberger Alaska Computing Center 30-APR-1996 11:02 PAGE: ** DATA ** DEPT. 9457.000 ROP.MWD 123.750 FET.MWD RPXX.MWD 2.340 RPX. MWD 2.525 RPS.MWD RPD.MWD 2.872 GRCH. CBT -999.250 DEPT. 9000. 000 ROP.MWD 180. 000 FET.MWD RPXX.MWD 4. 858 RPX.MWD 5. 500 RPS.MWD RPD.MWD 6. 665 GRCH. CBT 41. 844 DEPT. 8000. 000 ROP.MWD 132. 000 FET.MWD RPXX.MWD 2. 042 RPX. MWD 2. 262 RPS.MWD RPD.MWD 2. 561 GRCH. CBT 70. 625 DEPT. 7000.000 ROP.MWD RPXX. MWD 2.264 RPX.MWD RPD.MWD 2.772 GRCH. CBT 94.286 FET.MWD 2. 468 RPS.MWD 67. 813 DEPT. 6000.000 ROP.MWD 180.000 FET.MWD RPXX.MWD 3.514 RPX.MWD 3.782 RPS.MWD RPD.MWD 4.094 GRCH. CBT -999.250 DEPT. 5000.000 ROP.MWD 165.000 FET.MWD RPXX.MWD 4.374 RPX.MWD 4.922 RPS.MWD RPD.MWD 5.648 GRCH. CBT -999.250 DEPT. 4479.000 ROP.MWD 180.000 FET.MWD RPXX.MWD 62.461 RPX.MWD 348.003 RPS.MWD RPD.MWD 1000.000 GRCH. CBT -999.250 0.219 2.553 6. 803 5. 803 0.589 2. 324 1. 392 2.578 O. 365 3. 914 0.416 5.207 0.000 1000.000 GR. MWD RPM. MWD GR. MWD RPM. MWD GR. MWD RPM. MWD GR. MWD RPM. MWD GR. MWD RPM.MWD GR. MWD RPM.MWD GR. MWD RPM. MWD 87. 008 2. 610 59. 605 6. 068 96. 555 2.363 90. 408 2. 645 101. 848 3. 975 85.138 5.366 8.805 1000.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAFiE : EDIT .00i SERVICE : FLIC VERSION : O01CO1 DATE : 96/04/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~E : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/04/30 M_AXREC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS T~pe Verification Listing Schlumberger Alaska Computing Center 30-APR-1996 11: 02 PAGE: FILE H~ER FILE NLrMBER 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: O. 5000 FILE S~Y VENDOR TOOL CODE START DEPTH MWD 4479.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (I~40RY or REAL-TIldE): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 9040.0 22 -MAR-96 5.5C 5.5 MEMORY 9457.0 4479.0 9040.0 75 41.0 60.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ARC5 RESIST./GR $ TOOL NUMBER ARCS-ENP1 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : 6. 750 4557.0 BOREHOLE CONDITIONS MUD TYPE: FRESH MUD DENSITY (LB/G): 11. O0 MUD VISCOSITY (S) : 44.0 MUD PH: 9.0 MUD CHLORIDES (PPM) : FLUID LOSS (C3): 5.8 RESISTIVITY (OH~) AT TEMPERATURE (DEGF) : MUD AT I4EASURED TEMPERATURE (MT): 2. 760 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): 2.580 MUD CAKE AT (MT): 72.0 72.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): · LIS T~pe Verification Listing Schlumberger Alaska Computing Center 30-APR-1996 11:02 PAGE: TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 20000 REM_ARKS: ************* RUN1 ************** DRILLED INTERVAL 4568' - 9040' GR TO BIT: 62.44', RES TO BIT: 55.53' ************* RUN2 ************** DRILLED INTERVAL 9040' - 9457' GR TO BIT: 47.95', RES TO BIT: 43.04' WELL TD'D 1440 22-MAR-96 DEVIATION AT TD 38.89 DEG $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 66 66 73 66 66 73 65 0 0 36 1 0.5 FT 28 1 2 3 4 5 6 7 8 68 9 65 11 66 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME 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 O0 000 O0 0 2 1 1 4 68 0000000000 ROP LW1 F/HR O0 000 O0 0 2 1 1 4 68 0000000000 FET LW1 HR O0 000 O0 0 2 1 1 4 68 0000000000 GR LW1 GAPI O0 000 O0 0 2 1 1 4 68 0000000000 RPXXLW1 OH~ O0 000 O0 0 2 1 1 4 68 0000000000 RPX LW1 OHMM O0 000 O0 0 2 1 1 4 68 0000000000 RPS LW1 OHM~ O0 000 O0 0 2 1 1 4 68 0000000000 RPM LW1 Ot~4M O0 000 O0 0 2 1 1 4 68 0000000000 LIS T~pe Ve~£~ication Listing Schlumberger Alaska Computing Center 30-APR-1996 11:02 PAGE: NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) RPD LW1 0t~94 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 9039.500 ROP.LW1 6.758 FET. LW1 2.309 GR.LW1 RPX~.LW1 1.314 RPX.LWl 1.394 RPS.LW1 1.430 RPM. LW1 RPD . LW1 1.530 DEPT. 9000. 000 ROP. LW1 56. 571 FET. LWl 2. 309 GR. LW1 RPXX. LW1 1.314 RPX.LW1 1.394 RPS.LW1 1.430 RPM. LW1 RPD . LW1 1.530 DEPT. 8000. 000 ROP. LW1 132. 000 FET. LW1 O. 589 GR. LW1 RPXX. LW1 1.917 RPX.LW1 2.105 RPS.LW1 2.115 RPM. LW1 RPD . LW1 2.151 DEPT. 7000. 000 ROP. LW1 99. 000 FET. LW1 1 . 386 GR. LW1 RPXX.LW1 2.316 RPX. LW1 2.494 RPS.LW1 2.570 RPM. LW1 RPD. LW1 2. 763 DEPT. 6000. 000 ROP.LW1 180. 000 FET. LWl O. 367 GR. LW1 RPXX. LW1 3. 459 RPX. LW1 3. 764 RPS. LW1 3. 920 RPM. LW1 RPD. LW1 4.102 DEPT. 5000. 000 ROP. LW1 165. 000 FET. LW1 O. 417 GR. LW1 RPXX. LW1 4. 355 RPX. LW1 4. 935 RPS. LW1 5. 232 RPM. LW1 RPD. LW1 5. 647 DEPT. 4479. 000 ROP. LWl 180. 000 FET. LW1 O. 000 GR. LW1 RPXX. LW1 62.461 RPX. LW1 348.003 RPS.LW1 1000.000 RPM. LW1 RPD. LW1 1000. 000 62. 664 1. 459 62. 664 1. 459 97. 634 2. 073 95. 589 2. 623 101. 847 3. 985 84.821 5.379 8.791 1000.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/04/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE LIS T~pe Ve~£ication Listing Schlumberger Alaska Computing Center 30-APR-1996 11:02 PAGE: **** FILE HEADER **** FILE NAM~ : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 96/04/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : 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: O. 5000 FILE SO~E~RY VE2VDOR TOOL CODE START DEPTH STOP DEPTH 8945.0 9457.0 LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWN-HOLE SOFTWARE VERSION: DATA TYPE (FIEMORY 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 ARC5 RESIST./GR $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) '. BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : 22-MAR-96 5.5C 5.5 MEMORY 9457.0 8945.0 9457.0 80 38.9 41.0 TOOL NUMBER ARC5 - ENP1 6. 750 4557.0 FRESH 11. O0 44.0 9.0 LIS T~pe Ve~=£ication Listing Schlumberger Alaska Computing Center 30-APR-1996 11:02 PAGE: 10 FLUID LOSS (C3): 5.8 RESISTIVITY (0H~94) AT TEMPERATURE (DEGF): MUD AT M~ASURED TEMPERATURE (MT): 2. 760 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): 2.580 MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) .. TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: ************* RUN1 ************** DRILLED INTERVAL 4568' - 9040' GR TO BIT: 62.44', RES TO BIT: 55.53' ************* RUN2 ************** DRILLED INTERVAL 9040' - 9457' GR TO BIT: 47.95', RES TO BIT: 43.04' WELL TD'D 1440 22-MAR-96 DEVIATION AT TD 38.89 DEG $ LIS FORMAT DATA 20000 72.0 72.0 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 36 4 66 1 $ 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 28 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS TaPe Ve~=£ication Listing Schlumberger Alaska Computing Center 30-APR-1996 11:02 PAGE: 11 ** SET TYPE - CHAN ** NA~E 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 O0 000 O0 0 3 1 1 4 68 0000000000 ROP LW2 F/HR O0 000 O0 0 3 1 1 4 68 0000000000 FET LW2 HR O0 000 O0 0 3 1 1 4 68 0000000000 GR LW2 GAPI O0 000 O0 0 3 1 1 4 68 0000000000 RPXX LW2 OH~ff4 O0 000 O0 0 3 1 1 4 68 0000000000 RPX LW2 OH~M O0 000 O0 0 3 1 1 4 68 0000000000 RPS LW2 OH~k4 O0 000 O0 0 3 1 1 4 68 0000000000 RPM LW2 OH~4 O0 000 O0 0 3 1 1 4 68 0000000000 RPD LW2 Otff4M O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 9456.500 ROP.LW2 123.750 FET.LW2 0.219 GR.LW2 RPXX. LW2 2.340 RPX. LW2 2. 525 RPS. LW2 2. 553 RPM. LW2 RPD. LW2 2. 872 DEPT. 9000. 000 ROP. LW2 180. 000 FET. LW2 6. 806 GR. LW2 RPXX.LW2 4.533 RPX.LW2 5.154 RPS.LW2 5.476 RPM.LW2 RPD. LW2 6.103 DEPT. 8944.500 ROP.LW2 180. 000 FET.LW2 O. 000 GR.LW2 RPXX. LW2 68. 735 RPX. LW2 1000. 000 RPS.LW2 1000. 000 RPM.LW2 RPD. LW2 1000. 000 76. 070 2. 610 60. 026 5. 694 4. 271 1000. 000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 96/04/30 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 96/04/30 ORIGIN : FLIC TAPE NAME : 96099 CONTINUATION # : 1 PREVIOUS TAPE : CO~94ENT : ARCO ALASKA INC., KUPARUK 1F-19, API #50-029-22660-00 LIS TApe Ve~£ication Listing Schlumberger Alaska Computing Center 30-APR-1996 11:02 PAGE: 12 **** REEL TRAILER **** SERVICE NA~E : EDIT DATE : 96/04/30 ORIGIN : FLIC REEL NA~E : 96099 CONTINUATION # : PREVIOUS REEL COf~ZiENT : ARCO ALASKA INC., KUPARUK 1F-19, API #50-029-22660-00