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Home My WebLink About184-1761. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Tubing patch Development Exploratory 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 8390 feet N/A feet true vertical 6286 feet 8175 feet Effective Depth measured 8134 feet 7654 & 7957 feet true vertical 6107 feet 5752 & 5980 feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3.5 J-55 7987' 6001' Packers and SSSV (type, measured and true vertical depth) Packer Baker FHL 7654' 5752 Packer Baker FB-1 7657' 5980' SSSV Baker FVL 1900' 1773' 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: N/A 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: Authorized Name and Digital Signature with Date: Contact Name: Dusty Freeborn Contact Email:N2549@conocophillips.com Authorized Title: Well Integrity Specialist Contact Phone: (907)265-6218 - - - - measured TVD 3674 Burst Collapse - - Production 8330 Casing 62678362 3674 Plugs Junk measured Length 67 3638 103Conductor Surface 16 9.625 Size 103 7 N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL 0025645 Kuparuk River Field/ Kuparuk River Oil Pool ConocoPhillips Alaska, Inc. KRU 2X-15 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 184-176 50-029-21199-00 P.O. Box 100360, Anchorage, Alaska 995103. Address: N/A N/AN/A N/AN/A N/A 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) N/A Gas-Mcf MD N/A measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure N/A Water-BblOil-Bbl 7770'-7830', 7850'-7870', 8056'-8059', 8070'-8098', 8115'-8144' feet 5841'-5886', 8901'-5916', 6052'-6054', 6062'-6082', 6094-6114' feet N/A N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. p k ft t Fra O s 184 6. A G L PG , h Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Dusty Freeborn DN: OU=AK WELLS, O=ConocoPhillips, CN=Dusty Freeborn, E=dusty.freeborn@conocophillips.com Reason: I am the author of this document Location: Eagle River, Alaska Date: 2023.10.24 14:35:59-08'00' Foxit PDF Editor Version: 12.1.2 Dusty Freeborn By Grace Christianson at 3:27 pm, Oct 24, 2023 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 24, 2023 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski, Enclosed please find the 10-404 from ConocoPhillips Alaska, Inc. for the retrievable tubing patch re-set across a known tubing leak in producer KRU 2X-15 (PTD 184-176) to allow access to the well bore below the tubing patch. Please contact me at 659-7224 if you have any questions. Sincerely, Dusty Freeborn Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Digitally signed by Dusty Freeborn DN: OU=AK WELLS, O= ConocoPhillips, CN=Dusty Freeborn, E =dusty.freeborn@conocophillips.com Reason: I am the author of this document Location: Eagle River, Alaska Date: 2023.10.24 14:36:35-08'00' Foxit PDF Editor Version: 12.1.2 Dusty Freeborn Event Summary Executive Summary Pull and reset tubing patch over known tubing leak at 7599' to allow access to well bore below tubing patch. Date 09/24/23 RAN 3 1/2 SLIP STOP HOLE FINDER GOOD TBG TEST @ 5930' RKB (ABOVE OV @ 5946' RKB), PULLED OV @ 5946' RKB REPLACED IN KIND, MIT TBG FAILED (SUSPECT TEST TOOL), PULLED 3 1/2 TTS TEST TOOL @ 7579' RKB, RAN NEW 3 1/2 TTS TEST TOOL TO UPPER 2.72" P2P @ 7579' RKB MITT 2500 (PASS), CMIT TBG x IA 2500 (PASS). READY FOR E-LINE. 09/22/23 SET 3 1/2 TTS TEST TOOL IN LOWER 2.72" P2P @ 7609' RKB, PULLED 1" EXT PACKING DV @ 7594' RKB. IN PROGRESS. 09/19/23 ATTEMPTED TO RECOVER ELEMENT PIECES (UNSUCCESSFUL), PULLED LOWER PATCH ASSEMBLY @ 7610' RKB, BRUSH & FLUSH PATCH SETTING AREA FROM 7550' - 7650' RKB. JOB IN PROGRESS 09/18/23 PULLED UPPER PATCH ASSEMBLY @ 7583' RKB (PKR MISSING ELEMENT), RECOVERED PIECES OF PATCH ELEMENT. JOB IN PROGRESS 09/15/23 BRUSH & FLUSHED PATCH @ 7583' RKB, ATTEMPT TO DRIFT THRU PATCH @ 7583 'RKB (UNABLE), SET 2.77'' AVA CATCHER ON TOP OF PATCH @ 7583' RKB, PULLED & RESET ST #1 @ 2081' RKB W/1'' GLV(5/32''PORT,1226 TRO) BK LATCH, PULLED 2.77'' AVA CATCHER @ 7583 'RKB. IN PROGRESS Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 8,134.0 2X-15 9/12/2023 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set new patch, Replaced OV 2X-15 9/24/2023 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: WRP ELEMENT LEFT IN HOLE 3/10/2015 hipshkf NOTE: View Schematic w/ Alaska Schematic9.0 12/28/2010 ninam NOTE: Discovered Tbg Leak @ 7731' (GLM #7) 8/16/1996 WV5.3 Conversio n Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 36.0 103.0 103.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 35.6 3,673.9 2,980.7 36.00 J-55 BTC PRODUCTION 7 6.28 32.6 8,362.4 6,267.0 26.00 J-55 BTC Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 30.5 Set Depth 7,986.7 Set Depth 6,001.4 String Ma 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE 8RD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 30.5 30.5 0.04 HANGER 8.000 CIW TUBING HANGER 3.500 1,900.1 1,773.0 42.05 SAFETY VLV 5.937 BAKER FVL SAFETY VALVE (LOCKED OUT 10/29/92) 2.810 2,081.6 1,906.0 43.25 GAS LIFT 5.968 MMH FMHO 2.867 4,298.4 3,395.5 47.71 GAS LIFT 5.312 MMH FMHO 2.867 5,946.9 4,526.9 46.56 GAS LIFT 5.312 MMH FMHO 2.867 7,082.0 5,327.7 43.15 GAS LIFT 5.312 MMH FMHO 2.867 7,594.0 5,706.5 40.89 GAS LIFT 5.312 MMH FMHO 2.867 7,640.4 5,741.7 40.47 PBR 5.000 BAKER PBR 3.000 7,654.0 5,752.1 40.35 PACKER 5.968 BAKER FHL RETRIEVABLE PACKER 2.937 7,737.5 5,815.9 40.35 BLAST RINGS 4.500 BLAST RINGS (3) 2.992 7,956.0 5,979.1 43.05 SEAL ASSY 4.500 BAKER LOCATOR SEAL ASSEMBLY 3.000 7,956.8 5,979.7 43.06 PACKER 5.875 BAKER FB-1 PERMANENT PACKER 4.000 7,959.3 5,981.5 43.09 SBE 5.000 BAKER SEAL BORE EXTENSION 3.000 7,974.4 5,992.5 43.26 NIPPLE 4.540 CAMCO D NIPPLE NO GO 2.750 7,985.9 6,000.8 43.39 WLEG 4.570 BAKER WIRELINE RE-ENTRY GUIDE, ELMD TTL @ 7979' ON 9/11/00 SWS IPROF 3.015 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 7,579.6 5,695.6 41.02 PACKER - PATCH - UPR Set 2.72" PIIP Upper Patch Assembly (Includes Upper PKR, Spacer Pipe, and Anchor Latch) (OAL 29.31') TTS CPP3 5231 9/23/2023 1.625 7,583.2 5,698.4 40.98 ANCHOR LATCH ON SPACER PIPE Spacer pipe and Anchor Latch are part of Upper Patch Assembly with Upper PIIP PKR TTS CPAL 35207 9/23/2023 1.600 7,608.6 5,717.6 40.75 PACKER - PATCH - LWR 3-1/2" PIIP PACKER MID- ELEMENT AT 7611' RKB, OAL 4.01' TTS PIIP CPP3 5124 9/22/2023 1.625 7,911.0 5,946.1 42.54 PATCH 21.5' Merla Tbg Patch 11/28/1993 2.375 7,974.4 5,992.5 43.26 NIPPLE REDUCER AVA NIPPLE REDUCER 11/23/1993 2.250 8,175.0 6,136.2 45.22 FISH 1" DMY Lost in rathole 2/3/1994 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,081.6 1,906.0 43.25 1 GAS LIFT GLV BK 1 1,226.0 9/13/2023 12:00 0.156 4,298.4 3,395.5 47.71 2 GAS LIFT GLV BK 1 1,278.0 10/17/2011 5:30 0.188 5,946.9 4,526.9 46.56 3 GAS LIFT OV BK 1 9/24/2023 7:00 0.250 7,082.0 5,327.7 43.15 4 GAS LIFT DMY BK 1 0.0 4/13/1997 11:00 0.000 7,594.0 5,706.5 40.89 5 GAS LIFT OPEN BK 1 9/22/2023 11:00 7,692.5 5,781.5 40.02 6 PROD DMY BK 1 0.0 9/5/2010 Close d 0.000 7,730.9 5,810.9 40.28 7 PROD DMY BK 1 9/20/2023 7,917.7 5,951.0 42.62 8 PROD PATCH 0 1 0.0 11/28/1993 Close d 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,770.0 7,830.0 5,840.6 5,885.9 C-1, C-2, C-3, C- 4, 2X-15 12/8/1984 12.0 IPERF 120 deg. phasing 7,850.0 7,870.0 5,900.8 5,915.7 C-2, C-1, 2X-15 12/8/1984 12.0 IPERF 120 deg. phasing 2X-15, 9/25/2023 4:26:50 PM Vertical schematic (actual) PRODUCTION; 32.6-8,362.4 FISH; 8,175.0 IPERF; 8,115.0-8,144.0 RPERF; 8,115.0-8,144.0 IPERF; 8,070.0-8,098.0 APERF; 8,056.0-8,059.0 NIPPLE REDUCER; 7,974.4 PACKER; 7,956.8 PATCH; 7,911.0 PRODUCTION; 7,917.7 IPERF; 7,850.0-7,870.0 IPERF; 7,770.0-7,830.0 PRODUCTION; 7,730.9 PRODUCTION; 7,692.5 PACKER; 7,654.0 PACKER - PATCH - LWR; 7,608.5 GAS LIFT; 7,594.0 ANCHOR LATCH ON SPACER PIPE; 7,583.2 PACKER - PATCH - UPR; 7,579.5 GAS LIFT; 7,082.0 GAS LIFT; 5,946.9 GAS LIFT; 4,298.4 SURFACE; 35.6-3,673.9 GAS LIFT; 2,081.6 SAFETY VLV; 1,900.1 CONDUCTOR; 36.0-103.0 KUP PROD KB-Grd (ft) 38.80 RR Date 10/25/198 4 Other Elev 2X-15 ... TD Act Btm (ftKB) 8,390.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292119900 Wellbore Status PROD Max Angle & MD Incl (°) 51.48 MD (ftKB) 2,800.00 WELLNAME WELLBORE2X-15 Annotation Last WO: End DateH2S (ppm) 120 Date 10/29/2014 Comment SSSV: LOCKED OUT Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,056.0 8,059.0 6,051.5 6,053.7 A-5, 2X-15 3/13/2011 6.0 APERF HMX Millenium DP, 60 degree phase 8,070.0 8,098.0 6,061.6 6,081.6 A-4, 2X-15 12/8/1984 4.0 IPERF 120 deg. phasing 8,115.0 8,144.0 6,093.7 6,114.3 A-3, 2X-15 11/22/1993 4.0 RPERF 120 deg. phasing 8,115.0 8,144.0 6,093.7 6,114.3 A-3, 2X-15 12/8/1984 4.0 IPERF 120 deg. phasing 2X-15, 9/25/2023 4:26:50 PM Vertical schematic (actual) PRODUCTION; 32.6-8,362.4 FISH; 8,175.0 IPERF; 8,115.0-8,144.0 RPERF; 8,115.0-8,144.0 IPERF; 8,070.0-8,098.0 APERF; 8,056.0-8,059.0 NIPPLE REDUCER; 7,974.4 PACKER; 7,956.8 PATCH; 7,911.0 PRODUCTION; 7,917.7 IPERF; 7,850.0-7,870.0 IPERF; 7,770.0-7,830.0 PRODUCTION; 7,730.9 PRODUCTION; 7,692.5 PACKER; 7,654.0 PACKER - PATCH - LWR; 7,608.5 GAS LIFT; 7,594.0 ANCHOR LATCH ON SPACER PIPE; 7,583.2 PACKER - PATCH - UPR; 7,579.5 GAS LIFT; 7,082.0 GAS LIFT; 5,946.9 GAS LIFT; 4,298.4 SURFACE; 35.6-3,673.9 GAS LIFT; 2,081.6 SAFETY VLV; 1,900.1 CONDUCTOR; 36.0-103.0 KUP PROD 2X-15 ... WELLNAME WELLBORE2X-15 WELL NAME API #SERVICE ORDER # FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPEDATE LOGGEDCOLOR PRINTS CDsCD5-1950103207600000 CRU WLSetting RecordFINAL FIELD3-Aug-21CD5-1950103207600000 CRU WLSetting RecordFINAL FIELD11-Aug-21CD5-9650103208110000 CRU WLPERFFINAL FIELD21-Jul-21CD2-31050103208260000 CRU WLDCSTFINAL FIELD16-Sep-21CD2-31050103208260000 CRU WLUSITFINAL FIELD24-Aug-21CD2-31050103208260000 CRU WLUSITFINAL FIELD25-Aug-21CD5-3150103208280000 CRU WLPERFFINAL FIELD27-May-21CD1-01A50103202990100 CRU WLRSTFINAL FIELD12-Sep-21MT7-0650103208310000 GMTU WLCORROSIONFINAL FIELD3-Oct-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD14-Sep-21MT6-0850103207720000 GMTU WLPSRFINAL FIELD22-Oct-21MT7-0650103208310000 GMTU WLMECH CUTTERFINAL FIELD2-Sep-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD12-Dec-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD16-Dec-21MT7--0150103208320000 GMTU WLSCMTFINAL FIELD15-Nov-21MT7-0650103208310000 GMTU WLUSITFINAL FIELD19-Feb-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD29-Mar-21Lookout 150103203590000 GMTU WLRSTFINAL FIELD2-Apr-21Delivery Receipt______ďďǇĞůů_____X_______________________________________Print Name Signature DatePlease return via courier or sign/scan and email a copy to Schlumberger.A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted SLB Auditor-Originated:PTS - PRINT CENTER600 E 57th Pl - Ste AAnchorage, AK 99518Delivered to:AOGCCATTN: Natural Resources Technician333 W. 7th Ave., Suite 100Anchorage, AK 99501-3539Transmittal Date:20-Dec-21Transmittal #:________________Signature12/21/2021Wd͗ϭϴϰϭϳϲϬͲ^Ğƚ͗ϯϲϭϳϲJRBy Abby Bell at 1:43 pm, Dec 21, 2021 1D-0350029204080000 KRU WLIPROFFINAL FIELD29-Aug-211F-0750029208300000 KRU WLGLSFINAL FIELD13-Oct-212W-0950029212350000 KRU WLSCMTFINAL FIELD18-Nov-212W-0950029212350000 KRU WLSCMTFINAL FIELD22-Sep-212U-1350029212610000 KRU WLPPROFFINAL FIELD16-Oct-213N-0650029215380000 KRU WLPPROFFINAL FIELD31-Oct-211Y-1750029223680000 KRU WLPPROFFINAL FIELD25-Jul-211Q-20A50029225890100 KRU WLSBHPSFINAL FIELD29-Jul-213S-24A50103204560100 KRU WLUSITFINAL FIELD25-Nov-212N-318A50103203430100 KRU WLSCMTFINAL FIELD12-Nov-211D-0350029204080000 KRU WLIPROFFINAL FIELD27-Mar-211D-0550029204170000 KRU WLSCMTFINAL FIELD8-Oct-211D-0250029204290000 KRU WLIPROFFINAL FIELD2-Apr-211A-0550029206270000 KRU WLLDLFINAL FIELD1-May-211B-1050029206560000 KRU WLWHIPSTOCKFINAL FIELD25-Sep-211F-0350029208530000 KRU WLPERFFINAL FIELD19-Oct-211Y-0650029209580000 KRU WLPPROFFINAL FIELD1-Nov-212D-0850029211580000 KRU WLGLSFINAL FIELD18-Jul-212D-0450029211760000 KRU WLBISNFINAL FIELD20-Nov-212D-0450029211760000 KRU WLSCMTFINAL FIELD10-Oct-212X-1550029211990000 KRU WLPPROFFINAL FIELD17-Oct-211Q-0950029212090000 KRU WLIPROFFINAL FIELD17-Nov-212E-1450029212140000 KRU WLSHBPFINAL FIELD30-Oct-212W-0950029212350000 KRU WLBISNFINAL FIELD19-Nov-211Q-0250029212480000 KRU WLIPROFFINAL FIELD29-Apr-212W-1450029212530000 KRU WLIPROFFINAL FIELD1-May-211Q-1550029213080000 KRU WLIPROFFINAL FIELD28-Apr-211R-0850029213330000 KRU WLIPROFFINAL FIELD3-May-211R-1350029213850000 KRU WLIPROFFINAL FIELD27-Jun-213F-0250029214470000 KRU WLWHIPSTOCKFINAL FIELD14-Nov-213F-1450029215000000 KRU WLLDLFINAL FIELD30-May-213M-0550029217060000 KRU WLCHEM CUTFINAL FIELD28-Oct-213M-0550029217060000 KRU WLSTRINGSHOTFINAL FIELD27-Oct-21 • STATE OF ALASKA ALA. .A OIL AND GAS CONSERVATION COMIJ ._5ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed Abandon r Repair w ell 17 Rug Perforations r Perforate r Other r Set tubing patch Alter Casing r Pull Tubing r Stimulate-Frac r Waiver r Time Extension r Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name. 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development J' Exploratory r 184-176 3 Address: 6 API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service r 50-029-21199-00 7 Property Designation(Lease Number): 8.Well Name and Number: ADL0025645 KRU 2X-15 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: R Total Depth measured 8390 feet Plugs(measured) None R E C E I V E D true vertical 6286 feet Junk(measured) None MAR 24 2015 Effective Depth measured 0 feet Packer(measured) 7654, 7957 //��^^ //'�� true vertical 0 feet (true vertical) 5752, 5980 AOG VC Casing Length Size MD TVD Burst Collapse CONDUCTOR 67 16 103 103 0 0 SURFACE 3638 9 5/8 3674 3674 0 0 PRODUCTION 8330 7 8362 6267 0 0 Perforation depth: Measured depth: 7770'-7830', 7850'-7870', 8056-8059', 8070'-8098', 8115'-8144' True Vertical Depth: 5841'-5886', 8901'-5916', 6052'-6054',6062'-6082',6094-6114' Tubing(size,grade,MD,and ND) 3.5,J-55, 7986 MD, 6001 TVD PACKER-2.74"UPPER WFT WIDEPAK PACKER @ 7583 MD and 5698 ND PATCH-SPACER PIPE @ 7588 MD and 5702 TVD PACKER-2.74"LOWER WFT WIDEPAK PACKER @ 7610 MD and 5719 ND Packers&SSSV(type,MD,and TVD) PACKER-BAKER FHL RETRIEVABLE PACKER @ 7654 MD and 5752 ND PACKER-BAKER FB-1 PERMANENT PACKER @ 7957 MD and 5980 ND SAFETY VLV-BAKER FVL SAFETY VALVE(LOCKED OUT 10/29/92)@ 1900 MD and 1773 ND 12.Stimulation or cement squeeze summary:N/A SCANNED Intervals treated(measured):N/A £ 'I Treatment descriptions including volumes used and final pressure:N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation N/A N/A N/A N/A _ N/A Subsequent to operation N/A N/A N/A N/A N/A 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service E Stratigraphic r 16.Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations GSTOR r WIND r WAG r GINJ r SUSP r SPLUG r 17 I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt N/A Contact Dusty Freeborn/Jan Byrne Email N1617@conocophillips.com Printed Name Dust Fr Title Problem Wells Supervisor Signature Phone:659-7126 Date 10) ?1.14( 15- 17-7-/- 4/67115- .---- RBDMO- APR - 6 2015 Form 10-404 Revised 10/2012 r+1/ Y�4 ' Submit Original Only ~--' • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 19th day of March 2015 Ms. Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Ms. Foerster Enclosed please find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. well KRU 2X-15 PTD 184-176 tubing patch. Please call Jan Byrne or myself if you have any questions. Sincerely, dIi/ Dusty Freeborn/Jan Byrne Problem Wells Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659-7126 Cell phone: (907) 943-0450 2X-15 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 11/03/14 Failed TIFL 01/08/15 Tubing leak confirmed at 7594' 02/13/15 Lower patch assembly set and passed CMIT-TxIA 02/26/15 Upper patch assembly set. Test delayed due to weather 03/06/15 Upper patch assembly passed MIT-T 2X-15 DESCRIPTION OF WORK COMPLETED SUMMARY • F KUP PROD 2X-15 ConocoPhillips ; Well Attributes Max Angle&MD TD Alaska,Itl'; Wellbore APIIOWI Field Name Wellbore Status ncl('I MD(fIKB) Act Btm((MB) Cr.vvrit7aep. 500292119900 KUPARUK RIVER UNIT PROD 51.48 2,800.00 8,390.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(R) -Rig Release Date 2x.15,3/1012015 1:28:25 PM -SSSV:LOCKED OUT 120 10/29/2014 Last WO: 38.80 10/25/1984 ..................Vertical schematic(actual) Annotation Depth(RKB) End Date Annotation Last Mod By End Date _.._ ...._.. Last Tag:SLM 8,131.0 9/9/2014 Rev Reason:PULL WRP,SET PATCH,H2S, hipshkf 3/10/2015 -41 ADD NOTE HANGER;305 • ,ig Casing Strings Casing Description OD(in) ID(in) Top(RKB) Set Depth(RKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread ,.....u� ' �� V C si gUCTOR 16 15.062 3B) 1B) 103.0 62(50 Gr40ad TopTDED Casing Description OD(in) ID(in) Top(RKB) Set Depth(ttKB) Set Depth(ND)...WULen Il...Grade lop Thread SURFACE 9 5/8 8.921 35.6 3,673.9 2,980.7 36.00 J-55 BTC Casing Description OD OM ID(in) Top(ftKB) Set Depth(ttKB) Set Depth(ND)... WBLen(I...Grade Top Thread PRODUCTION 7 6.276 32.6 8,362.4 6,267.0 26.00 J-55 BTC Tubing Strings Tubing Description 'String Ma,..'ID(in) Top(ttKB) (Set Depth(ft../Set Depth(ND)(...IWt(Ib/ft) 'Grade 'Top Connection �"CONDUCTOR;36.0-103.0•' - TUBING 3 1/2 2.9921 30.5 7,986.7 6,001.4 9.30 J-55 EUE 8RD Completion Details Nominal ID SAFETY VLV;1,900.1 III Top(RKB) Top(TVD)(ttKB) Top Incl(1 Item Des Corn (in) 30.5 30.5 0.04 HANGER CIW TUBING HANGER 3.500 - 1,900.1 1,773.0 42.05 SAFETY VLV BAKER FVL SAFETY VALVE(LOCKED OUT 10/29/92) 2.810 GAS LIFT:2.081 6 - 7,640.4 5,741.7 40.47 PBR BAKER PBR 3.000 - 7,654.0 5,752.1 40.35 PACKER BAKER FHL RETRIEVABLE PACKER 2.937 7,737.5 5,815.9 40.35 BLAST RINGS BLAST RINGS(3) 2.992 I7,956.0 5,979.1 43.05 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 3.000 SURFACE;35.63,673.9 7,956.8 5,979.7 43.06 PACKER BAKER FB-1 PERMANENT PACKER 4.000 GAS LIFT;4296.4 7,959.3 5,981.5 43.09 SBE BAKER SEAL BORE EXTENSION 3.000 7,974.4 5,992.5 43.26 NIPPLE CAMCO D NIPPLE NO GO 2.750 GAS LIFT;5,946.9 7,985.9 6,000.8 43.39 WLEG 'BAKER WIRELINE RE-ENTRY GUIDE,ELMD TTL @ 3.015 7979'ON 9/11/00 SWS IPROF GAS LIFT;7,082.0 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(RKB) (RKB) (°) Des Coin Run Date ID(in) PACKER;7,583.0 7,583.0 5,698.2 40.99 PACKER 2.74"UPPER WFT WIDEPAK PACKER 2/26/2015 pil 7,588.0 5,702.0 40.94 PATCH SPACER PIPE 2/26/2015 GAS LIFT;7,590.0 7,610.0 5,718.7 40.74 PACKER 2.74"LOWER WFT WIDEPAK PACKER 2/13/2015 PATCH;7,588.0 7,911.0 5,946.1 42.54 PATCH 21.5'Meda Tbg Patch 11/28/1993 2.375 PACKER;7.610.0 l:a!! 7,974.4 5,992.5 43.26 NIPPLE AVA NIPPLE REDUCER 11/23/1993 2.250 REDUCER 8,175.0 6,136.2 45.22 FISH 1"DMY Lost in rathole 2/3/1994 0.000 PBR;7.6404 ,� Perforations&Slots ' PACKER;7,654.0 1111'! Shot Dens PillTop (ND) Btm(ND) (shots/! PRODUCTION;7,692.5611 Top(RKB) Btm(ftK8) (ttKB) (RKB) Zone Date tl Type Com 7,770.0 7,830.0 5,840.6 5,885.9 C-1,C-2,C-3, 12/8/1984 12.0 IPERF 120 deg.phasing • C-4,2X-15 PRODUCTION;7,730.97,850.0' 7,870.0 5,900.8 5,915.7 C-2,C-1,2X- '12/8/1984 12.0 IPERF 120 deg.phasing 15 'PERF;7,7790-7,830.0- alts 8,056.0 8,059.0 6,051.5 6,053.7 A-5,2X-15 3/13/2011 6.0 APERFHMX Millenium DP,60 degree phase • • 8,070.0 8,098.0 6,061.6 6,081.6 A-4,2X-15 12/8/1984 ' 4.0 (PERF '120 deg.phasing 8,115.0 8,144.0 6,093.7 6,114.3 A-3,2X-15 128/1984 4.0 IPERF 120 deg.phasing (PERF;7,850.07,670.0- 8,115.0 8,144.0 6,093.7 6,114.3 A-3,2X-15 11/22/1993 4.0 RPERF 120 deg.phasing Mandrel Inserts st ati PRODUCTION;7,917.71 on Nop(ND) Valve Latch Port Size TRO Run PATCH;7,917.0 'gig Top(RKB) (ftK8) Make Model OD(In) Sery Type Type (In) (psi) Run Date Com 1 2,081.6 1,906.0 MMH FMHO 1 GAS LIFT GLV BK 0.156 1,226.0 10/17/2011 12:00 2 4,298.4 3,395.5'MMH FMHO 1 GAS LIFT GLV BK 0.188 1,278.0 10/17/2011 5:30 SEAL ASSY;7,958.0 3 5,946.9 4,526.9 MMH FMHO 1 GAS LIFT OV BK 0.250 0.0 7/23/2012 7:00 PACKER;7956.6 _ 4 7,082.0 5,327.7 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 4/13/1997 11:00 SBE;7,969.3 II5 7,594.0 5,706.5 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 1/8/2014 EM. a Pkg. 11:00 • NIPPLE;7,974.4 6 7,692.5 5,781.5 MMH FMHO 1 PROD DMY BK 0.000 0.0 9/5/2010 Close • • NIPPLE REDUCER;7,974.41 .IIS d • 7 7,730.9 5,810.9 MMH FMHO 1 PROD HFCV BK 0.000 0.0 10/13/2011 ••• 8 7,917.7 5,951.0 MMH FMHO 1 PROD PATC 0 0.000 0.0 11/28/1993 Close WLEG;7,985.9 H d Notes:General&Safety End Date Annotation APERF 9056.0-8,059.0--. 8/16/1996 NOTE:Discovered Tbg Leak @ 7731'(GLM#7) 12/28/2010 NOTE:View Schematic w/Alaska Schematic9.0 3/10/2015 NOTE:WRP ELEMENT LEFT IN HOLE (PERF;8,070.08,098.0 (PERF;9115.0-9144.0 RPERF;8,115.08,144.0 FISH;8,175.0 PRODUCTION;32.69362.4 • RECEIVED FEB 13 2015 WELL LOG TRANSMITTAL AOGCC To: Alaska Oil and Gas Conservation Comm. February 4, 2015 Attn.: Makana Bender 25 IA 0 2- 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 DATA LOGGED 2.I% /2015 M K.BENDER RE: Multi Finger Caliper(MFC) : 2X-15 Run Date: 1/20/2015 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 2X-15 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-21199-00 SCANNE© jl��a Y�� 1J 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' ' / .-E%�ti' ?reject Well History File' Cov( e XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Well History File Identifier Organizing (done) RESCAN DIGITAL DATA n Color items: Diskettes, No. [3 Grayscale items: Poor Quality Originals: Other: ~ NOTES: Other, No/Type BY: B~Y BREN VINCENT SHERYL MARIA LOWELl. Project Proofing : BY: BEVERLY, BREN VIN~ SHERYL MARIA LOWELL Sca~ningPreparation '_.~ x 30=., ~ + OVERSIZED (Scannable) Maps: Other items scannable by large scanner OVERSIZED (Non-Scannable) Logs of various kinds Other DATE: '7~ ~)-~/O ~"' /S/ DATE: '7/~'~'/O~'/S/ BY: BEVERLY ~ VINCENT SHERYL MARIA LOWELL Production Scanning · Stage 1 PAGE COUNT FROM SCANNED FILE' ' /// PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: Stage 2 ~TAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: ' YES (SCANNING IS COMPLETE AT THIS POINT UNLES~ SPECIAL ATI'ENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QU,~JTY, ~Y$C,I~..E OR COLOR J l ReScanned (individual page [special attention] scanning completed) I~' NO NO RESCANNED BY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ General' Notes or Comments about this file: Quality Checked {done) 10/25/02Rev3NOTScan ned.wpd 7 STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM.SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon Re air w ell Starter head r p Ru g Perforations r Perforate (— Ot her p Pull Tubing repair Alter Casing r g r Stimulate - Frac r Waiver r Time Extension �'" Change Approved Program r Operat. Shutdow n r Stimulate - Other r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development p Exploratory r - 184 - 176 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic r Service r 5- 002 - 92119 -90 DO 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0025645 ' 2X -15 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): — N/A Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 8390 feet Plugs (measured) none true vertical 6286 feet Junk (measured) none Effective Depth measured 0 feet Packer (measured) 7654, 7956, 7957 true vertical 0 feet (true vertucal) 5752, 5979, 5980 Casing Length Size MD TVD Burst Collapse CONDUCTOR 67 16 103 103 0 0 SURFACE 3638 12 3674 2981 0 0 PRODUCTION 8330 7 8362 6267 0 0 o 0 0 0 0 0 0 0 0 Perforation depth: Measured depth: 7770'- 7830', 7850'- 7870', 8056'- 8059', 8070'- 8098', 8115' -8144' RECEIVED True Vertical Depth: 5841'- 5886', 5901'- 5916', 6051'- 6054', 6062' 6082', 6094' - 6114' AUG O n 6 2012 Tubing (size, grade, MD, and TVD) 3.5, J -55, 7986 MD, 6001 TVD AOGCC Packers & SSSV (type, MD, and TVD) PACKER - BAKER FHL RETRIEVABLE PACKER @ 7654 MD and 5752 TVD SEAL ASSY - BAKER LOCATOR SEAL ASSEMBLY @ 7956 MD and 5979 TVD PACKER - BAKER FB -1 PERMANENT PACKER @ 7957 MD and 5980 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): n/a 5LANNE +) A U G 1 3 2 012 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation N/A N/A N/A N/A N/A Subsequent to operation N/A N/A N/A N/A N/A 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run N/A Exploratory r Development rI Service r Stratigraphic r 16. Well Status after work: — oil rI Gas r WDSPL r Daily Report of Well Operations N/A GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Perry Klein Prin ame Title Wells Supervisor Signs re . Phone: 659 -7728 Date 08/05/12 '(i‘'. ', �c4 /L Form 10 -404 Revised 11/2011 RBDAAS AUG 0 8 1012 i bmi Original Only • • ConocoPh i l l i ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 August 5, 2012 Mr. Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Seamount Enclosed please find the 10 -404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. well 2X -15 PTD 184 -176 surface casing starter head repair. Please call Perry Klein at 659 -7728 if you have any questions. ly, Perry Klein ConocoPhillips Wells Supervisor II • • 2X -15 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 07 /21 /12JSET THE WRP AT DEPTH 7670' AND PULL OUT OF HOLE WITH THE ELINE 07/25/12 Initial T /I /O= 500/0/0. MIT -T (passed). Pressured up to 2500 PSI and started 30 min monitor.15 Min - 2400/0/0 30 Min - 2400/0/0 Bled Tubing to 0 Psi. Final T /I /O= 0/0/0 08/02/12 Cooperheat was reinstalled on wellhead and temperature was brought up to 450 -500 *. Welded braidenhead to complete repair. Shut in and rigged down N2 purge. T /I/O= s1150/0/0. 08/04/12 Post BH repair MITOA. (Passed) Initial T /I /O= si150 /0 /0.Pressured OA up to 1800 psi with 1.5 bbls of diesel for one hour test. Starting T /I/O= si1 5 010/1 8 0 0. 15 min T/I/O= si150/0/1730. 30 min T/I/O= si150/0/1700. 45 min T/I/O= si150/0/1695. 60 min T/I/O= si150/0/1695. Bled OA back to 0 psi. Final T/I/O= si150/0/0. I I I I I � I 1 • ht by .., . This pho y iz ti is copyright , 'Hips Alaska, Inc. Conoco 1 0ConocoPpil ..,• Alaska. Inc and , • b . , written consent of . ' 44 publi e wi out express . th 4,1 . , cannot be released or p ' i p • . . ' 4 k ConocoPhillips Alaska_ - ...,, . ,. . . . . _ ,N..,,..., - sk .., • , 't• 4- .c.i . - - , ..... .. - ... - . . - . .., .,„ . .4. .04i. .0.46 16. ..0 ,fre .04p 0000. . 00.‘ 00. 00 • 404..44 Pe . light, - . 410 .10 . . -.% * * --40* m‘ It 0 . 4, ' .04 04 ,44 .., 04.4 . l e. i p 44 _ - • . , 4 4. i - '• ." 0 ,4*.t. , . , ... . . ..e ' *"' It Ir . * A b At""i• A * : i f . + .4111r .:40( 41' ©COnttcoPhillips Alaska, Inc This photols copyright by ConocoPhillips Alaska, Inc. and cannot be released or ,. published without express written consent of ConocoPhillips Alaska , iii ,g : I ,. ,, . v . .. .. .4 .1,„.... , . i +. f :, } KI t; + • Mt r Zit. Y� INA Ate. 1 ' .:..-1/4.:i.: • Kt am .- -.---lirilliql2r11111,!ri:--* *.-- -- r STATE OF ALAS ALASKA* AND GAS CONSERVATION COMMIS. ' REPORT OF SUNDRY W OPERATIONS 1. Operations Performed: Abandon r Repair well r Rug Perf orations r Stimulate J"` Other '""' Alter Casing r Pull Tubing r Fbrforate New Pool r Waiver E Time Extension Change Approved Program r Operat. Shutdown r Perforate Re -enter Suspended Well 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r ' 184 -176 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic `" Service 50- 029 - 21199 -00" 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25645 • • 2X -15 9. Field /Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 8390 feet Plugs (measured) None true vertical 6286 feet Junk (measured) 8175 Effective Depth measured 8281' feet Packer (measured) 7654, 7957 true vertical 6209 feet (true vertucal) 5752, 5980 Casing Length Size MD ND Burst Collapse CONDUCTOR 67 16 103 103 SURFACE 3638 9 -5/8" 3674 2981 EN PRODUCTION 8330 7 8362 6267 RECtE 2 60 tells' C° Perforation depth: Measured depth: 7770'- 7830', 7850' 7870', 056-8059' 8070'- 8096, 8115' -8144' S C. True Vertical Depth: 5841'- 5886', 5901'- 5916', 6051'- 6054', 6062'- 6082', 6094' -6114' � 20 APR I fi f Tubing (size, grade, MD, and ND) 3.5, J -55, 7986 MD, 6001 TVD Packers & SSSV (type, MD, and ND) PACKER - BAKER FHL RETRIEVABLE PACKER @ 7654 MD and 5752 TVD PACKER - BAKER FB -1 PERMANENT PACKER @ 7957 MD and 5980 ND SAFETY VLV - BAKER FVL SAFETY VALVE @ 1900 MD and 1773 ND 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 184 1611 2725 -- 201 Subsequent to operation 175 1095 2434 -- 199 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development 17 • Service r Stratigraphic 15. Well Status after work: • Oil Gas r WDSPL Daily Report of Well Operations XXXX GSTOR r WIND r WAG r GINJ r SUSP r SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt none Contact John Peirce @ 265 -6471 Printed Name John Peirce Title Wells Engineer Signature A ,,. — Phone: 265 -6471 Date 4 f j j / 1 f Form 10-404 Revised 10/2010 RBD>11AS APR 2 20 1 4141 1 4. 1 Submit Original Only 2X -15 Well Work Summary DATE SUMMARY • 2/16/11 DRIFT TBG 10' 2" BAILER TO TAG 148' SLM. COMPLETE. 2/20/11 C SAND SCALE SQUEEZE. FP FLOWLINE WITH 20 BBLS DIESEL. PUMP 50 BBLS SW PRE FLUSH. PUMPED 23 BBLS OF SEAWATER PRE -FLUSH CONTAINING 80 GALLONS OF WAW -5206. PUMPED 123 BBLS OF SEAWATER CONTAINING 780 GALLONS OF SCW -4004. PUMP OVERDISPLACEMENT 310 BBLS OF SW FOLLED BY 50 BBLS DIESEL. 3/13/11 PERFORATED 8056' -8059' WITH 2" MILLENNIUM II HMX CHARGES, 6 SPF, 60 DEG PHASING. WELL TURNED OVER TO DSO. I , KUP • 2X -15 Conoco b lh1 a 9 Well Attributes Max Angle & MD TD W''p Wellbore AP WWI Feld Name Well Status Inc! ( °) MD (568) Act Btm (ftKB) A{�.51t13' 500292119900 KUPARUK RIVER UNIT PROD 51.48 2,800 00 8,390 0 Comment H2S (ppm) Date _ An t t n End Data K8 Grd (ft) Rig Release Date wen cone x - 1 y,53;on299 , - - SSSV LOCKED OUT 1 135 rate Last WO 1 __ I 38.80 10/25/1984 .9.- ..-.2.....,5,4.1 __ - - _ -_ S1r.�jyy�l Annotation Depth (ftKB) End Date Annotation Last Mod ... E d Date Last Tag: SLM I 8,148 0 2/16/2011 Rev Reason ADD PERFS Imosbor 3/18/2011 Casco Strm • s HANGER, 30 Casing Description String O .. String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) .. String Wt... String String Top Thrd _ CONDUCTOR 16 15.062 36.0 103.0 103.0 62.50 H WELDED Casing Description String 0.. _ String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd „ r . SURFACE 9 5/8 8.921 35.6 3,673.9 2,980.6 36.00 J -55 BTC __. Casing Descdpt'IOn String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... Siring Wt... String ... String Top Thrd f PRODUCTION 7 6.151 32.6 8,362.4 6,267.0 26.00 _ 3 -55 BTC Tubing Strings Tubing Description String 0 I String ID Top (ftKB) Set Depth (t.. . Set Depth (ND) _- String WI... I String ._ String Top Thrd TUBING 31/2 i 2 -992 305 7,986.7 6,001 4 9.30 3 -55 EUE 8RD CONDUCTOR, - ' Completion Details 38 -103 Top Depth (ND) Top Inc! Nomi... Top (ftKB) (ft68) C) Item Description Comment ID(in) SAFETY VLV, r 30.5 30.5 -0.02 HANGER CIW 1 UB(NG HANGER 3.500 1'906 1,900.1 1,773.0 42.05 SAFETY VLV BAKER FVL SAFETY VALVE (LOCKED OUT 10/29/92) 2.810 ark 7,640.4 5,741.1 39.31 PBR BAKER PBR 3.000 AEI GAS LIFT, __ 7,654.0 5,751.7 39.46 PACKER BAKER FHL RETRIEVABLE PACKER 3.000 2 ,062 - 7,737.5 5,815.5 40.14 BLAST RINGS 'BLAST RINGS 2.992 7,956.0 5,978.9 43.05 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 3.000 '1 , 7,956.8 5,979.5 43.06 PACKER BAKER FB -1 PERMANENT PACKER 4.000 7,959.3 5,981.4 43.09 SBE BAKER SEAL BORE EXTENSION 3.000 SURFACE, - L 7,974A 5,992.5 43.26 NIPPLE CAMCO D NIPPLE NO GO 2.750 36 - - 7,985.9 6,000.8 43.39 WLEG BAKER WIRELINE RE - ENTRY GUIDE 3.015 GAS LIFT. _ -_ T ._ _ -_ 4 e-1- tither In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth GAS LIFT, (TVD) Top Intl 5,947 Top (ftKB) (ftKB) (°I Descd•Nan Comment Run Date ID(in) 7,911.0 5,946.0 42.54 PATCH 21.5' Merle Tbg Patch 11/28/1993 2.375 GAS LIFT, 7,974.4 5,992.5 43.26 NIPPLE AVA NIPPLE REDUCER 11/23/1993 2.250 F IL 7,082 REDUCER GAS LIFT _ 1 1,11 t ' 8,175.0 6,136.2 45.22'E ISH 1•' DMY Lost In rathole 2/3/1994 - IP Perforations & Slots IF Shot Top (TVD) Btm (TVD) Dens P8R, 7,640 - - - - -- Top (ftKB) Bin (ftKB) (ftKB) (ftKB) Zone Date (sh ... Type Comment 7,770.0 7,830.0 5,840.5 5,885.6 C - 1, C - 2, C 12/8/1984 12.0 IPERF 120 deg. phasing PACKER. 7.854 -- a. _.• .. C 2X - 1 7,850.0 7,870.0 5,900.7 5,915.7 C - 2, C - 1, 2X - 15 12/8/1984 12.0 IPERF 720 deg. phasing PRODUCTION, _.... , 7.893 8,056.0 8,059.0 6,051.4 6,053.6 A-5, 2X -15 3/13/2011 6.0 APERF HMX Millenium DP, 60 degree phase 8,070.0 8,098.0 6,061.5 6,081.6 A4, 2X -15 12/8/1984 4.0 IPERF 120 deg. phasing PRODUCT7,73ION1 ,_ _ 8,115.0 8,144.0 6,093.7 6,114.2 A -3, 2X -15 12/8/1984 4.0 IPERF 120 deg. phasing 8,115.0 8,144.0 6,093.7 6,114.2 A -3, 2X -15 11/22/1993 4.0 RPERF 120 deg. phasing 7,77aie30 Notes: General & Safety I i End Date Annotation 1 i 8/16/1996 NOTE: Discovered Tbg Leak / 7731' (GLM #7) IPERF. 12/28/2010 NOTE: View Schematic w/ Alaska Schematic9.0 7,850 -7.870 - (L' --'1l H PRODUCTION, 7,918 PATCH, 7,911 d, SEAL ASSY, . Y y 7,956 PACKER, 7,957 _ .._ -_ `.1 - : SBE, 7,959- 11. .- ilit NIPPLE, 7,974 NIPPLE REDUCER, - 7,974 • WLEG, 7,986 I APERF, ;,._ Mandrel Details B -8.059 - - - -._. - -- -_ Pod ' Top Depth Top (TVD) Intl OD Valve Latch Size TRO Run °° Stn Top (ftKB) (ftKB) (°) Make Model (in) __. Sera TYM Type (in) (psi) Run Date Can... IPERF, - 1 2,081.6 1,906.0 43.01 MMH FMHO 1 GAS LIFT GLV BK 0.188 1,255.0 6/15/2002 8,070 - 8,098 ' 2 4,298.4 3,395.5 47.71 MMH FMHO 1 GAS LIFT OV BK 0.250 0.0 6/16/2002 RPERF, 8.115 - 8,144 3 5,946.9 4,526.9 46.56 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 4/13/1997 IPERF, 8,115 ... -- 4 7,082.0 5,327.7 43.17 MMH FMHO 1 GAS LIFT DMY 8K 0.000 0.0 4/13/1997 5 7,594.0 5,706.5 40.89 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 4/13/1997 FISH, 8,175 -- -: 6 7,692.5 5,781.5 39.87 MMH FMHO 1 PROD DMY BK 0.000 0.0 9/5/2010 Closed 7 7,730.9 5,810.4 40.05 MMH FMHO 1 PROD DMY BK 0.000 0.0 9/5/2010 Closed 8 7,917.7 5,950.9 42.62 MMH FMHO 1 PROD PATCH 0 0.000 0.0 11/28/1993 Closed PRODUCTION, 33 8,362 TD, 8,390 • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. March 14, 2011 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforating Record: 2X -15 Run Date: 3/13/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2X -15 Digital Data in LAS format, Digital Log Image fi1G. _ 1 CD Rom 50- 029 - 21199 -00 MAR 0 20 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. 1 - j_ii Anchorage, Alaska 99518 Office: 907 - 273 -3527 �.0 6 g5.--- Fax: 907 - 273 -3535 klinton.wood halhb x Date: 5 : '`'' Signed: 0_ n ., ; . n ' `mi l tas • A~~,, onocoPh i I I i ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 4, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~` Avenue, Suite 100 Anchorage, AK 99501 lg~-t7~ ~..~c - i s Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped November 25, 2008 and the corrosion inhibitor/sealant was pumped December 3, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, ,~ , ~ ,~ Perry Kl ' ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field 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 2X-10 184-163 14' 1.75 29" 11/25/2008 9.77 12/3/2008 2X-13 184-174 7' 1.15 23" 11/25/2008 3.83 12/3/2008 2X-14 184-175 17' 3.40 28" 11/25/2008 6.80 12/3/2008 2X-15 184-176 24" NA 24" NA 3.25 12/3/2008 2X-16 184-172 7' 0.95 21" 11/25/2008 3.40 12/3/2008 J ~% %' N~ /,/ Schlumerger NO. 4775 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~~~~N~~ JLIL 2 2008 Well Job # Log Description Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 07/10/08 2W-04 12061711 INJECTION PROFILE ja 06/24/08 1 1 1L-20A 10215099 PRODUCTION PROFILE ~(SU '~ 06/26/08 1 1 1 G-05 12080389 LDL ~p 06/27/08 1 1 36-10 12061714 INJECTION PROFILE °I' - ~ / '- 06/27/08 1 1 2L-327 12061715 SBHP SURVEY "' (3 06/28/08 1 1 1J-109 12080390 SBHP SURVEY / ( 06/28/08 1 1 2N-323 12061716 SBHP SURVEY 1 'fir =- ~ 06/28/08 1 1 2X-15 12080392 SBHP SURVEY ( 06/29!08 1 1 2N-303 12061717 SBHP SURVEY 06/29/08 1 1 2L-309 12061718 SBHP SURVEY /' 06/29/08 1 1 2X-14 12080391 SBHP SURVEY 06/29/08 1 1 2X-11 12080393 SBHP SURVEY C(- s 06/29/08 1 1 1G-09 12080401 INJECTION PROFILE U -~'! ~~ 07/05/08 1 1 2H-05 12080396 SBHP SURVEY c .~.~ 06/30/08 1 1 2H-12 12080395 SBHP SURVEY b~ 06/30/08 1 1 2H-11 12080394 SBHP SURVEY "- - / 06/30/08 1 1 1 D-07 12080398 SBHP SURVEY -. i 07/02/08 1 1 2N-341 12061720 SBHP SURVEY ..- p 06/30/08 1 1 3C-15 11982441 USIT / 07/04/08 1 1 2W-10 11982445 INJECTION PROFILE `6 - (p 07/08!08 1 1 1 L-19 12061724 PRODUCTION PROFILE ~ p -6 07/10/08 1 1 2W-02 11982446 INJECTION PROFILE - ,5 07/09/08 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. /"j `?' ,., .,J ~~~~~ ~:~~~~~ ~~~ ~~ °~ 2008 NO. 4707 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk 05/15/08 C `~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Weil Job # 1 F-12 11996623 PRODUCTION PROFILE -- ` / ~ 05/01/08 1 1 3J-11 11996624 PRODUCTION PROFILE - C~Gf 05/02/08 1 1 3K-102 11963094 MEM PROD PROFILE a0'~ - ~ 05/09/08 1 1 iJ-152 11996632 GLS ( C 05/09/08 1 1 1 E-166 11994665 GLS - 05/11 /08 1 1 1 E-168 11994665 GLS _ 05/10/08 1 1 i H-01 11996626 PRODUCTION PROFILE W/FSI J (o / M 05/10/08 1 1 2X-15 11996634 PRODUCTION PROFILE W/FSI - ~ 05/12/08 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. a~ +"I ~ ,ftii4 ir~~~ r Log Description Date BL Color CD • Schlumbergep RECEIVED NO. 3638 Schlumberger -DCS f ,\ ~ ¡ 0 9 2006 2525 Gambell Street, Suite 400 fJ i~ ! \~ Company: Anchorage, AK 99503-2838 A TTN: Beth ~)aska Oii ':1 Gas Gens. Commission Ançhc1age Field: Well Job # Log Description Date BL 2D-02 N/A SHUT IN BOTTOM PRESSURE 12/03/05 1 1A-07 N/A INJECTION PROFILE 12/06/05 1 1 H-21 11166748 PROD PROFILE W/DEFT 12/26/05 1 2X-12A 11166749 PROD PROFILE W/DEFT 12/27/05 1 2U-08 11166750 PROD PROFILE WIDEFT 12/28/05 1 2X-13 11144057 GLS 12/25/05 1 2V-11 11166736 PROD PROFILE W/DEFT 12/16/05 1 30-09 11166737 LDL 12/17/05 1 3S-21 11166738 INJECTION PROFILE 12/18/05 1 3F-17 11144054 PROD PROFILE W/DEFT 12/22/05 1 2X-15IM-17{1J 11144058 PROD PROFILE WIDEFT 12/26/05 1 30-09 11144055 LDL 12/23/05 1 2V-01 11144056 INJECTION PROFILE 12/24/05 1 SIGNED&dLlOOO1-¡ ~ÇANNED JAN :!·1 211uB DATE: Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 12/30/05 Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Kuparuk Color '-" CD ,-" '~1 ? r [¡_ð I : ~EI i i I )! I " :J L..:.:::!I ') :'-F"-1 'l' if ') i i i i I i Lb r~\ lil~ FRANK H. MURKOWSKI, GOVERNOR AlASKA OIL AND GAS CONSERVATION COMMISSION November 9, 2005 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279·1433 FAX (907) 276-7542 Mr. Paul Dubuisson Kuparuk Field Manager ConocoPhillips Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 0( ,I\. \0 \0 \ct rf Dear Mr. Dubuisson: The Alaska Oil and Gas Conservation Commission ("Commission") performed an inspection of your well safety valve system (SYS) at Kuparuk River Unit 2X ("KRU 2X") pad on October 7, 2005. Attached is a copy of the Inspection Report. Regulatìon at 20 AAC 25.265 in conjunction with Conservation Order 348 requires all wells in the Kuparuk River field to be equipped with a Commission approved fail-safe automatic surface SYS capable of preventing uncontrolled flow by shutting off flow at the wellhead and shutting down any artificial lift system where an overpressure of equipment may occur. If installed, a subsurface safety valve must be maintained in working order and is subject to performance testing as part of the SYS. An SYS component failure rate of 11.1 percent was identified during the above-noted inspection. Commission test interval requirements provide that the testing frequency will be increased when a failure rate exceeds 10 percent. Eftèctive October 7, 2005 and until an acceptable level of performance is achieved, the safety valve systems associated with wells located on KRU 2X must be tested every 90 days. When testing is scheduled, you must notify the Commission Field Inspector (907-659-2714) at least 24 hours in advance to provide an opportunity to witness the SYS test. Sincerely, , " '-y LJ ',,-U¡¡,ißiD, 1\&(1" James B. Regg , Petroleum Inspection Supervisor Attachment cc: AOGCC Inspectors ~{;ANNED NO\! 1 tr 2005 Safety Valve & Well Pressures Test Report Reviewed By: Pol. Suprv Comm Pad: KRU_2X Insp Dt 10/7/2005 Inspected by John Spaulding Interval 90 Days InspNo svsJS051007213641 Related Insp: Field Name KUPARUK RIVER Operator CONOCOPHILLJPS ALASKA INC Operator Rep Noble Reason 180-Day Src: Inspector w~iiDiÙ;;-- - - r=-·-~- _-~~!~/;;¿s==- _ __[SS~l~~~~~~~~~J?!L~iYe~~.1'y~_I~-!f~/¡P!~~~f$~-_,"".', r-G~s¡ifd~~~~.r==-_~~=C~hf'~~E;~' c~~==~-f1 Well Permit Separ Set LIP Test Test Test Date SI Oil, W AG,GINJ, Inner Outer Tubing Number Number PSI PSI Trip Code Code Code GAS,CYCLE, SI PSI PSI PSI YeslNo Yes/No 2X-09 1841620 96 70 60 "-p- ----4 ---- r---I-OIL--r120ò·ul-gOO----200---- - "Ye~-- T"-No·-------- 2X-IO 1841630 96 70 60 P P --"-- r -~6rL--1·1I5Õ-r--60{)u_--15Ó --- -"ie~-- r N~"- -- - - -- -- ---"----- ----" ~"-, -" "--,- - --- T- ---- ---/-- - -----¡- "-------- ----- ----"- -"----- "m_____ 2X-1I 1841640 96 70 70 ___P___P _ __1__ -.L- I-O.!..L~. ___ ~1~50_-,__1_~~_ 120_"__ Yes _______'(es"____ 2X-13 1841740 96 70 55 P Pi' I-OIL 1050 700 ISO Yes No 2X-14 1841750 96 70 50 P P ¡ I -OIL 1300 930 180 Yes I No ._"--, --""" ----- "-" --------- j-" "--"-- ---- -- -------- - "---"------------""--"---1-- 2X-IS 1841760 96 70 IO I P I -OIL 1000 900 200 Yes I No "u"__ ---"-----"------- --"--- "____U -"'-~.- "---" -~ -- ---I" 2X-J6 1841720 I 9ó 70 60 P P I-OIL 1350 1000 200 Yes i No 2X-17 "ï95Iiíü-- 96 I 70 65 P ----p---- "---- --I-OÏL------ïÛOü-- 600" ---iÓÖ---'--ý~-1----No---"--- ---"- iX - I 8- -- - -195 1600 _~6 -l_?f_~- 60-=---}~~~~fU-- -=--~=--=-~J ~~I~()ïL_~ _ -122-5~__20~--- - ?OÒ~~:-~- ~~s__~nT~.B~----[~-_=-~ __=____ __~=__-_n~_ j ------ -------- ;' "-- retested tripped at 65psi ok - ---- - ------ --------------~---- Comments Performance ------~--- -- ----- 2-12a wing Icaked -unable to test, requested repairs prior to testing again Wells Components 9 18 ------ ----------- ______u.. __~._""__n_"__1 Failures Failure Rate I ___~" "_____ __U_:.LL~__ L_ ___ ----- -- - --- ( o p y Wednesday, November 09, 2005 ) ) . ~~A,~E :} ~:!Æ~:~fÆ / AI,ASIiA. OIL AND GAS / CONSERVATION COMHISSION / October 25,2004 &1"~~J.tirt'~ fi~t>'''. ...Iit FRANK H. MURKOWSKI, GOVERNOR 333 W. 7fH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Mike Wheatall Operations Manager ConocoPhillips Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 Dear Mr. Wheatall: The Alaska Oil and Gas Conservation Commission ("Commission") performed an inspection of your well safety valve system (SVS) at~'H-~{~~iR:iverl.Jllit2X("KRU 2X") pad on October 15, 2004. Attached is a copy of the Inspection Report. Regulation at 20 AAC 25.265 requires all wells to be equipped with a Commission approved fail-safe automatic surface SVS capable of preventing uncontrolled flow by shutting off flow at the wellhead and shutting down any artificial lift system where an overpressure of equipment may occur. If installed, a subsurface safety valve must be maintained in working order and is subject to performance testing as part of the SVS. An SVS component failure rate of 12.5 percent was identified during the above-noted inspection. Commission policy, as outlined in a letter dated November 14, 1995, states that the testing frequency will be increased when a failure rate exceeds 10 percent. The AOGCC-AOGA Safety Valve System Task Force report issued June 13, 2003, supported retention of the 10% failure threshold. Also noted during the Commission's inspection were unsupported flow piping and pilots on KRU 2X pad, specifically Wells 2X-03 and 2X-09. These were not included in the failure rate calculation but clearly are deficiencies in the SVS that must be corrected. Effective October 15, 2004, and until an acceptable level of performance is achieved, the safety valve systems associated with wells located on KRU 2X must be tested every 90 days. When testing is sched ed, you must notify the Commission Field Inspector at 907-659-2714 to provide ~ortu' 0 witness the SVS test. (' IÍ Smcerely, Ø~¿/ o~ Daniel T. Seamount, Jr. Commissioner Attach. copy by emai1: Bob Fleckenstein; AOGCC Inspectors SCANNED NOV 04 ?nO<1 Safety Valve & Well Pressures Test Report Reviewed By: P.I. Suprv~ \D-ZSl°4- Comm Pad: KRU_2X Insp Dt 10/15/200 Inspected by Jeff Jones Interval 90 Days InspNo svsJJ041019163228 Field Name KUP ARUK RIVER Operator CONOCOPHILLIPS ALASKA INC Operator Rep Bob Noble Related Insp: Reason 180-Day Src: Inspector Well Permit Separ Set UP Test Test Test Number Number PSI PSI Trip Code Code Code 2X-03 1831090 I 2700 I 2000 1900 I P I P I 2X-08 1831140 2700 2000 1750 P P 2X-09 1841620 98 70 50 P P 2X-I0 1841630 98 70 60 P P 2X-ll 1841640 98 70 65 P 4 2X-12A 1951760 98 70 65 P P 2X-13 1841740 98 70 44 3 P 2X-14 1841750 98 70 75 P P 2X-IS 1841760 98 70 55 P 7 2X-16 1841720 98 70 52 P P 2X-17 1951710 98 70 50 P P 2X-18 1951600 98 70 55 P P Comments Outer PSI Tubing PSI YeslNo YeslNo Date SI Oil,WAG,GINJ, Inner GAS,CYCLE, SI PSI W AGIN Flow piping & pilot not supported properly; loose & wobbly. W AGIN I-OIL Flow piping & pilot not supported properly; loose & wobbly. ~ I-OIL I-OIL I-OIL I-OIL I-OIL I-OIL I-OIL I-OIL I-OIL 900 No Yes IA x OA communication wing valve leaks. 175 750 wing & pit valves leak. The SSV on well2X-ll failed the pressure test & will require repair. The pilot on weIl2X-13 tripped low & was cycled & passed a re-test. Both the wing and pit valves leaked on we1l2X-15 and the SSV could not be tested. I inspected 12 well houses. Performance Wells Components Failures Failure Rate 12 24 3 12.5% Monday, October 25, 2004 ~ MEMORANDUM TO: Julie Heusser, Commissioner THRU: Tom Maunder, P. I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission FROM: Chuck Scheve; SUBJECT: Petroleum Inspector DATE: January 25, 2001 Safety Valve Tests Kuparuk River Unit 2X Pad Thursday, January 25, 2001: I traveled to the Kuparuk River Field. and witnessed the 90-day retest of the safety valve systems on 2X Pad. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 12 wells and 24 components With one failure observed. The Surface Safety Valve on Well 2X,14 had a slow leak when pressure tested. This valve was serviced and I witnessed a successful retest on 1-26-01. Earnie Barndt conducted the testing today he demonstrated good test procedure and was a pleasure to work with All the wellhouses entered'at this location were clean and all related equipment appeared to be in good condition. Summary: I witnessed the 90-day SVS testing at 2X Pad in the Kuparuk River Field. ' - ,~...~~k'~ ~.~: ~, '~~ ..k.-~ k,%~ \,x~~ KRU 2X Pad, 12 wells, 24 components, 1 failure 4.1% failure rate 15 wellhouse inspections Attachment: SVS KRU 2X Pad 1-25-01 CS X Unclassified Confidential (Unclassified if doc. Removed) SVS KRU 2X Pad 1-25-01 CS.doc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Operator Rep: Eamie Barndt AOGCC Rep:,, Chuck Schev, e Submitted By: Chuck Scheve Date: Field/Unit/Pad: Kupanflc / KRU / 2X Pad Separator psi: LPS 99 HPS 1/25/01 ........... , ', ,i, 'i .... '~' :' '' "" i":, ' "' : ":, Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GRqJ, Number Number ,.. psi PSI Trip Co, de. Code Code Passed GASor, CYCLE 2X-01 1830840, 2X-02 '18~31030, 3750 2000 lS00 P 'P .... WAG ,2X-03 1831090 '2X-04 1831180 3750 2000 ' 2000 P P WAG 12X-05 1~3'1070 ................... 2x-06 18311 oo 2x-07 " 183'~1130 '3750 '5000 .... 200'0 P ' ' P ...... WAG 2X-08 1831140 2X-09 1841620 99 60 60 P P OIL 2X- 10 1841630 2X-11 I,, 1841640 99 ,.., 60, ,. 50 P P 0IL 2,X-12A , 1,,9,,5,1,7,60 ,,. 99:, 60 ,, ,55 "P i. , P .I .... OIL 2X-13 1841740 99 60 55 'P P OIL 2~-14 ,, '18'41750 ,99 ' ,60 .., 55 P 4, "',. ,1,/26/01 0IL 2x-15 , 1'84'1760" ' 99 60 55 P P OIL 2X-16 '184172o ' ' 9~J ' ~6o ' "~5 P '" P ........ 0IL 2X-17 19~1710 99 .... 60 "' 60' ' P '" P ' ' OIL 2X-18 '19'~16oo '99 ' 60 ~" 60 ...... p" p " ..... 0IL 2x-19 . .1951750 Wells: Remarks: 12' Components: 24 Failures: ,1 Failure Rate: 4.17% EIg0 oar Surface Safety on well 2X-14 had very slow leak when press_ute tested, valve to be serviced and retested by,operator. RIF 1/16/01 Page 1 ofl SVS KRU 2XPad 1-25-01 CS.xls MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Dan Seamount, Commissioner DATE: July 22, 2000 THRU: Blair Wondzell, ~ SUBJECT: P. I. Supervisor ~["t(~,o John H Spauldingt~, t~,-- .~. Petroleum Inspector FROM: SVS Tests Pads 1E & 2X Kuparuk River Unit Kuparuk River Field July 22, 2000: I traveled to Philips Alaska Inc.'s Kuparuk Field to witness the SVS Tests on 1E and 2X pads. The AOGCC form is attached for reference. As noted on the test reports a minimal amount of failures were observed (1 on each pad). Ernie Barndt the PAl representative and his helper did an excellent job of testing. SUMMARY: I witnessed the SVS tests on: PAl, KRU, 1E & lX 1E - 8 wells, 16 components, 1 failure, 9 % failure rate, 12 well house insp. 2X ~ 10 wells. 20.compnents, 1 failure, 5% failure rate, 12 well house insp. Attachment: Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Alaska Inc Operator Rep: E. Barndt AOGCC Rep: John H. Spaulding Submitted By: John H. Spauld Date: Field/Unit/Pad: Kupamk~upan~ R. U./1 Separator psi: LPS 91 HPS 7/22/00 Well Permit Separ Set L? Test Test Test oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code GASorCYCLE 1E-02 1800500 91 70 65 P P OIL 1E-03 1800560 SI 1E-05 1800580 1E-06 1800780 SI 1E-07 1800800 91 60 55 P P OIL 1 E- 10 1820360 1E-11 1820510 1E-12 1820600 SI 1 E- 14 1820790 1 E- 18 1830160 91 60 46 P P OIL 1E-19 1830170 1E-20 1830050 91 60 48 P P OIL 1E-21 1830020 1 E-23 1821840 1E-24A 1971870 91 70 70 P P OIL 1 E-26 1821660 SI 1E-28 1821580 SI 1 E-29 1821540 SI 1E-31 1971380 91 70 70 P P OIL 1E-33 1971510 1E-34 1971660 91 70 70 P P OIL 1E-36 1982130 91 70 70 P P OIL Wells: 8 Components: 16 1 Failure Rate: 9.0% [-3 90 my Remarks: 8/7/00 Page 1 of 1 svs kupamk km 1 e 7-22-00js.xls Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Alaska Inc Operator Rep: E. Barndt AOGCC Rep: John H. SDaulding Submitted By: John Spaulding Date: Field/Unit/Pad: KupanflUKupamk R./2X Separator psi: LPS 96 HPS 22-Jul Well Permit Separ Set L/P Test Test Test Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code GAS or CYCLE 2X-01 1830840 2X-02 1831030 2X-03 1831090 2×-04 1831180 3000 2000 2000 P P WAG 2X-05 1831070 3000 2000 2000 P 4 WAG 2X-06 1831100 3000 2000 2000 P P WAG 2X-07 1831130 3500 2000 2000 P P WAG 2X-08 1831140 2X-09 1841620 96 70 60 P P OIL 2X-10 1841630 96 701 65 P P OIL 2X-11 1841640 96 60 60 P P OIL 2X-12A 1951760 2X-13 1841740 2X-14 1841750 2X'15 1841760 96 70 70 P P OIL 2X-16 1841720 2X-17 1951710 96 60 50 P P OIL 2X-18 1951600 96 60 50 P P OIL 2X-19 1951750 Wells: 10 20 Failures: 1 Failure Rate: 5.0% [] 90 Day Remarks: 8/15/00 Page 1 of 1 svs kuparuk kru 2x 7-22-00js.xls ARCO Alaska, Inc. Kuparuk Operations Post Office Box 196105 Anchorage, Alaska 99519-6105 Telephone 907 659 2821 November 8, 1997 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission' 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in duplicate is a Report of Sundry Well Operations (Form 10-404) on the following Kuparuk well. Form Well Action 10-404 2X-15 Repair well If you have any questions, please call me at 659-7210. Sincerely, ~y Bl~ck Attachments Well Files (attach only) File: FTR 121897 (w/o attach) RECEIV£I) ARCO Alaska. Inc. is a Subsidiary of Atlantic Richfield Company S~/-~ STATE OF ALASKA ~' ALA OIL AND GAS CONSERVATION COMMIS~5~uN REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Pull tubing Operation Shutdown ~ Alter casing __ 5. Type of Well: Development Exploratory Stratigraphic 99510 Service 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK Stimulate __ Plugging __ Perforate __ Repair well X Other X 4. Location of well at surface 1109' FSL, 238' FEL, Sec. 4, T11N, At top of productive interval 1274' FNL, 1430' FEL, Sec. 10, Tll At effective depth 1401' FNL, 1227' FEL, Sec. 10, Tll At total depth 1506' FNL, 1066' FEL~ Sec. 10, Tll 12. Present well condition summary Total Depth: measured true vertical Effective depth' measured true vertical R9E, UM N, R9E, UM N, R9E, UM N, R9E~ UM 8390' 6285 8281' 6209' feet feet feet feet Plugs (measured) Junk (measured) 6. Datum elevation (DF or KB) _112' RKB, 77' PAD 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2X-15 9. Permitnumber/approval_/~r /7~:~ ~ / 94-065 10. APl number 5o-029-21 1 99 11. Field/Pool Kuparuk River Oil Pool Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented 73' 3644' 8332' 1 6" 230 Sx AS II 9-5/8" 850SXCS III & 575 Sx CS II 7" 555 Sx Class G 250 SX CS I measured 8070'-8098', true vertical 5740'-5886', 8115'-8144', 4 SPF, 120° phasing Measured depth True vertical depth 103' 103' 3674 2981' 8362' 6265' 5901 '-5915', 6061'-6083', 6094'-6114' Tubing (size, grade, and measured depth) 3.5", 9.3 #/ft, J-55 set at 7987' MD Packers and SSSV (type and measured depth) Baker "FHL" @ 7654', Baker'"FB-l" @ 7957'; Baker "FVL" 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure SSSV @ 1900' 14. RECEIVED i NOV 14 997 Representative Daily Average Production or Iniection i:~t~!~V#mt~eb~,~,-i~.,~'.-~ Oil-Bbl Gas-Md Water-Bbl Casing Pressurc~C~ng Pressure Prior to well operation 7 8 4 1 8 8 6 3378 1346 171 Subsequent to operation 15. Attachments Copies of Logs and Surveys run__ Daily Report of Well Operations 940 1610 4005 1400 175 16. Status of well classification as: Water Injector__ Oil X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~lned ~\~(--~)--~,~)~.~C.,.¥..~'~ Title Wells Supervisor Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE REPORT OF SUNDRY WELL OPERATIONS KUPARUK WELL 2X-15 10/97 Kuparuk Well 2X-15 is an oil producer in the Kuparuk River Field. On 4/12/97, during a routine SSV test, the state inspector and the ARCO engineering technician discovered that the well had become mechanically unstable at the surface. The well was immediately shut in. Subsequent diagnostics showed that the well had 7" packoff communication and likely 7" casing movement. Discussions with the AOGCC led to an initial action plan of stabilizing the 9-5/8" conductor (via welding) and the potential of replacing the 7" packoff(s): See attached letter dated 5/28/97. Further diagnostics and discussions between ARCO and the AOGCC led to an intermediate plan, that if successful, would negate the 5/28/97 plan. These discussions led to a Sundry Application dated 8/13/97 (AOGCC Approval No. 397-141) outlining the plan. See attached Application for Sundry dated 8/13/97. The well was brought on line allowing it to heat up and stabilize. On 9/14/97, with the help of AOGCC inspector Lou Grimaldi, the work plan was implemented. Hard cement in the 16"x 9-5/8" annulus was encountered at approximately 48' by running small diameter pipe. Seven (7) barrels of Dowell Class "G" was pumped in the 16"x 9-5/8" annulus via the small pipe. Good cement returns were observed. In addition to cementing, the wellhead manufacturer (Cooper Cameron) was able to plastic pack and test (per their guidelines) the 7" upper packoff. This sealed the 7"x 9-5/8" leak. See attached KRU Well Service Report dated 9/14/97. Monitoring of the well stability and annulus pressures began that day (once per 12 hour shift). The well remained stabilized and pressure tight throughout the 30 day monitoring period. The 7" annulus was pressure tested to 1400 psi midway through the monitoring period with no noticeable difference on the 9- 5/8". To date the well is in stable condition. See attached 2X-15 monitoring report (from 9/14/97 through 10/21/97). Based on the above work and the subsequent monitoring, ARCO is satisfied that the well has been repaired and no further remedial work is required at this time. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Mr. Blair Wondzell Alaska Oil And Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 (907) 276-7542 (fax) Re: KRU Well 2X-15 Repair Overview Mr. Wondzell May 28, 1997 -.~ 1997 6as .Co~s..g_o~mmiS~. ~horags I appreciate the time spent last Friday to discuss plans for repairing KRU well 2X-15. As discussed, ARCO has a plan to move forward with these repairs. The repairs will eliminate future casing movement by securing in place both the 9-5/8" surface casing and the 7" production string. Last time we met, Mark Fissell, Bill Isaacson and I gave a brief overview of ARCO Alaska's plan to stabilize.the 9-5/8" surface casing. As you may recall, the plan involved moving the 9-5/8" back to the position where it was at the time the problem was discovered and then securing / stabilizing the casing via the base plate / gusset design presented. This approach has been discussed with the wellhead manufacture (Cameron) and is believed to be the best method to stabilize the wellhead and 9-5/8" casing. Clamps were discussed, however, due to the type of wellhead in place, there is no way to attach the clamp without significant welding on the wellhead. ARCO wishes to limit the welding on the wellhead (as recommended by Cameron) and therefore feel more comfortable with the base plate / gusset approach, which isolates welding to the mandrel hanger and 16" conductor. Base plates / gussets have been used successfully by ARCO in West Texas and the Gulf Coast in similar circumstances. Along with attaching the base plate / gusset, the 16" x 9-5/8" annulus will be cemented as far down as possible with 1" tubing. Once the 9-5/8" casing and wellhead have been secured, the 7" production casing will be speared, picked up, and re-set to verify proper weight is set on the slips. The weight to be set on the 7" casing slips will be that weight required to keep the 7" casing in tension under all future operating conditions. At that time the upper and lower 7" packoff will also be replaced to repair any wellhead communication problems between the 7" and 9-5/8" casings. ARCO does no;,,intend to back off the 7" casing for several reasons. Most importantly, pressure integrity of the 3-1/2" x annulus has been confirmed and doing anything to change this, especially on a well with plans for future gas lift, is not prudent. Secondly, once backed-off and the top of cement behind the 9- 5/8" is identified, perforating the 9-5/8" to bring cement to surface is not recommended due to loss of integrity on the 7" x 9-5/8" annulus and possible leak path to the surface. By accomplishing what is outlined above, ARCO believes both the structural concerns and the 7" x 9- 5/8" wellhead communication can be eliminated in a safe and effective manner. Detailed plans are underway but have not been finalized nor have project start dates been confirmed. Should you have comments, questions, or concerns, please feel free to contact me or my alternate (Gar Jordan) at 659- 7210. Thanks again. Sincerely, Randy Black Kuparuk Wells Supervisor ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldComp,-my STATE OF ALASKA ;( ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS ;1. -.De of Reauest: Abandon Suspend Operation Shutdown Re-enter suspended wed Alter casmg __ Change approved Droaram Repmr well X - Plugging Pull tubing ... "---I 5. Type of Well: Development Exploratory Strahgrapmc 99510 Serwce 2. '~ame of Operator ARCO Alaska, Inc. 3. -,' ddress P. O. Box 100360, Anchorage, AK ,.t. ',_3ca~on of well at surface 1109' FSL, 238' FEL, Sec. 4, T11N, R9E, UM At top of productive interval 1274' FNL, 1430' FEL, Sec. 10, T11N, R9E, UM Time extension Stimulate Variance ___ Perforate __ Other 6. Datum eieva[lon (DF or _112' RKB, 77' PAD 7. Unit or Properly name Kuparuk River Unit feet 8. Well numoer 2Xo15 9. Perm~ number 10. APl number 50-02g-2 1 1 gg .&t effective depth 1401' FNL, 1227' FEL, Sec. 10, T11N, R9E, UM At total depth 1506' FNL, 1066' FEL, Sec. 10. T11N, R9E, UM 12. Present wed condition summary Total Depth: measured true vertical 8390 6285 feet feet 11. Field/Pool Kuparuk River Field/Pool Plugs (measured) None Effective depth' measured 8 2 8 1 true vertical 6 2 0 9 feet feet Junk (measured) Top of 162' Vann Gun @ 7597' Casing Length Structural Conductor 7 3 Surface 3 6 4 4 Intermediate Production 8 3 3 2 Liner Perforation depth: measured Size Cemented 1 6" 230 Sx AS II 9-5/8" -850 Sx CS III & 575 Sx CS II 7" 555 Sx Class G 250 Sx CSI Measured depth True vertical depth 103' 103' 3674' 2981' 3" 'DUPLiCATE 8070'-8098', 8115'-8141', 4 SPF, 120 Decj phasing & 7770'-7830', RECEIVrD 6094'-6114' NOV 14 1997 7850'-7870', 12 SPF, 120 Deg phasing true vertical 5740'-5886', 5901 '-591 5', 6061 '-6083', Tubing (size. grade, and measured depth) 3.5", 9.3#/ft, J-55 set at 7987' MD Packers and SSSV (type and measured depth) Baker "FHL" @ 7654' Baker "FB-I" @ 7957" Baker "FVL" SSSV @ 1900' ~l~0il&GasOor~s. 13. Attachments Description summary of proposal X Detailed operation program __ BOP sk~J~""'..._'~'' Repair Well 14. Estimated date for commencing operation August 1997 16. If proposal was verbally approved Blair Wondzell Name of approver 7/1 1/97 Date approved 15. Status of well classification as: Oil X Gas Suspended Service Water Injector 17. I he__fy that the foregoing is true and correct to the best of my knowledge. Signed~/'~'//"'*'~.m'~. C~I~.~ ~,)~.1~.¢~ , Title Wells Supervisor ' J FOR COMMISSION USE ONLY Date: 8/13~97 Conditions of approval: Notify Commission so 'representative may witness Plug integrity _ BOP ati e IAppr°v "~-~' -' J~'l Mechanical Integ~ Su~quent form re~ 10- ~ o ~ // Approved b~/ order of the Commission ' Date Form 10-403 Rev 06/15/88 ~ "~ -"' ~M'IT'INA'RIPLIOATE ,, APPLICATION FOR SUNDRY APPROVAL KUPARUK WELL 2X-15 7/97 Kuparuk Well 2X-15 is a producer in the Kuparuk River Field. On 4/12/97. during a routine SSV test. the state inspector and the ARCO engineering technician discovered that the well had become mechanically unstable at the surface. The well was immediately shut in and has remained shut in. Further diagnostics showed that the well had 7" packoff communication and likely 7" casing movement. The weld at the conductor had been broken due to what we believe was thermally related 7" casing movement. Discussions since the incident led to an agreed upon action plan calling for stabilization of the 9-5/8" conductor and the replacement of the 7" packoff(s). See attached letter dated 5/28/97. ARCO proposes that an intermediate step be taken that might eliminate the need for all or a portion of the work described in the 5/28/97 letter. The plan, as discussed verbally between Blair Wondz~lii and Randy Black on 7/-t 1/97, calls for the following steps' · Bring the well on line. Establish production rates at the same levels as before shutting the well in on 4/12/97. · Cement the 16" x 9-5/8" annulus as far down as possible with 1" tubing. · Re test the 7" packoffs under.production. If unable to test, attempt to re engergize packoffs per manufactuer's and ARCO's regular practices. · Observe well for 7" pressure integrity and mechanical stability for 30 days while maintaining the previously established production rates. If the above steps are successful further work would not be necessary. Should the 7" packoffs be unable to maintain pressure, some or all of the actions outlined in the 5/28/97 letter would then commence. ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT '~' K1(2X-15(W4-6)) WELL JOB SCOPE JOB NUMBER 2X-15 WELL HEAD MAINT: TEST, REPAIR 0914971558.2 DATE DAILY WORK UNIT NUMBER 09/14/97 CEMENTED 16" X 9-5/8" ANNULUS & PLASTIC PACKED 7" PACKOFF DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 1 (~ Yes O NoI (~) Yes C) No DS-GRAY BLACK FIELD AFC~ CC,~ DALLY COST ACCUM COST ~ig~ ESTIMATE KAWWRK 23ODS28XL $8,639 $8,639 Initial Tb.cl Press Final Tb.cl Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 300 PSI 300 PSI 0 PSI 0 PSII 0 PSII 0 PSI DALLY SUMMARY CEMENTED 16" X 9-5/8" ANNULUS W/7 BBLS NEAT CLASS "G" CEMENT. PLASTIC PACKED 7" UPPER PACKOFF. WITNESSED APPROVED BY LCD GRIMALDI (AOGCC). PER AGREEMENT W/STATE WILL BE MONITORED FOR 30 DAYS. TIME 08:00 LOG ENTRY RU & CUT SLOTS IN 16" CONDUCTOR & RUN +/- 35' PVC (3/4") IN 16 X 10" ANNULUS (9/13/97). MIRU DS CEMENTING (GRAY & CREW) & CAMERON (HARBOR). RU & PUMP PVC TO +/- 48' (VERY HARD CEMENT, UNABLE TO WASH FURTHER). RU & PUMP 7 BBLS NEAT CLASS "G" CEMENT (15.8 PPG, 1.15 CU FT/SK). ENSURE GOOD RETURNS AT SURFACE. CENTER WELLHEAD IN CONDUCTOR. RD DS. RU & TEST TBG HGR TO 5000 PSI (GOOD TEST). RU TO TEST 7" VOIDS. ABLE TO PLASTIC PACK UPPER PACKOFF (2 STICKS). LOWER PACKOFF WILL NOT TEST. SHOULD ISOLATE 7" X 9-5/8" FROM 7" GASLIFT. WITNESSED & APPROVED BY LCD GRIMALDI (AOGCC INSPECTOR). MONITOR FOR 30 DAYS PER AGREEMENT WITH STATE. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL APC $2,150.00 $2,150.00 CAMERON $460.00 $460.00 DOWELL $6,029.00 '...$6,029.00 TOTAL FIELD ESTIMATE $8,639.00 $8,639.00 ,,, ..................................... 1 ..... -.._ 2X-15 TEST Manual_Readings -_ - .__ _KD-~S _R__ea~d!n~s Date Time 7" Csg 9-5/8" Csg_ Flowing Flowing Comments ( Wellhead Stability, Other) Press Press __T_bg _T_emp Tbg Pres_s psig ...... psig ...... F_F .... p_s!_g .............__ 9/13/97 0 0 7', and 10" bled to approx 0~ .... 9/14/97 1300 1~ --- 10- 1~6 ..... ;152 9-5/8"X 16"annulus cemented w/7bbls cement, plastic packed-~.ppe_r _7!"l~aC'l~_0ff_-_~ 100 10 10 136 .152 9/15/97 1100 ~ 10 136 ............ 154 £'i-ft Gas riser rigged up, 7" ~:e~Ures to 250~-_-- -_~__~-_-__ '___-'. ' 100 250 10 135 140 -- 9/16/97 1200 250 10 135 148 2130 25~ - 10 1:~ ~ 9i~-?~97- 930 250 1~ 136'- ....... .i,~ ......... 2~-30 250 10 1~ 160 9i:i~8/97 930 '~,~ 10 135 180 2130 25~ '~ 135 162 9Jl- 9/97~ 930 250 1~ 135 158 2130 250 10 135 161 9~20/97- 9~ 250 10 --~6~- - ~60 ....... 2130 250 1(~ 137 154 9/21/97 1020 250 ~ 1~ .... i,~ 2000 25~ 10 136 -15'J 9/22/97 1300 250 10 136 156 1145 25~ ----1-~ .... ~§~ ' ~5~ 9/23/97 2~30 25~' 10 136 153 1015 250 10 136 170 9/24/97 10~0 25~ 10 136 ....... ~6~ 2030 250 10 136 166 9/25/97 1030 25~ 1~ 136 165 2~30 2,~ 10 -~3~ 9/26/97 ' 1030 250 25 136 157 203~ ~50 25 -~3-~ ....... 9/27/97 1030 250 2,~ 136 .... ~ ~ 2030 250 25 136 152 9/28/97 1300 2,~ ....... 2-~ ...... i§~,.- -' 1~:~ ............ .............. _~ . '__ - - i'~ __'ii. _ .~__ .~.~-. - __ - i'._ i . ._ 100 250 25 136 159 9/29i9~---- 1300 25~ ___25 132 .... ~? ........................... ~--_ ...... .__~--~-~_--Ji___ ~-i. ---_i .... . --~6~d 240 ..... '~ ....... ~6 154 9/30/97 1500 240 25 136 155 · 300 240 25 136 155 10/1/97 94~ 240 2~ 136 155 100 24b 2,~ 136- ~,~ 1012/97 90~ 240 ~5, 136 155 _ . . 401~ 240 25 136 155 10/3/97 1300 1400 40 136 158 Pressured up 7" annulus to 1400~. Good PT 100 1400 40 136 158 Wellhouse Cat Heater turned on due to li__ff,qas strin~ being dummied o___ff 10/4/97 1800 1410 50 136 158 -- 400 1400 50 136 158 Page 1 JAL 2x-15 log book.xls _J 2X-'15 TEST Manual Readings _ .. _K?___G_S ~ _e _a_d ! _n_ g_ _s -Daie -' Tim~- ...... ~;~ Csg_. 9-5/8" Cs_g_ ._ Flowin~ _Flowi_n_g ................ Comments _( _W.__e!lhe__ad_ S~t-ab_i!!t~, _O_ ! _h_ _e _r )_ ___ Pres__s ...... Press .... Tbg Temp T_bg _P_re__ss_ .................. psig .... psig ....... IF p_s!_g 1015197 1230 1400 40 136 158 ............................ ..... 830 1400 40 136 158 .................................... -i0/6i97 1730 1400 40 ;136 - i57 - 5,~0. 1400 40 136 157 .......... __ 10/7/97 1800 1400 40 136 155 _ . 800 1400 40 136 155 ......................................... .......................... 10/8/97 1530 1400 40 136 156 ............................. 400 ' 1400 46 136 - ~ ~ ................ 10~9~97 1330 1400 40 136 155 ............................. 3oo 1400 40 l§b- -- .................... 10110197' 1330 1410 50 i3~ .... ............. _. 300 1410 40 136 159 ........... ....... 10/11/97 1130 1410 40 136 160 ........................................ 233d 1400 40 'J36 160 ................ ........................................... 10112197 123~' -- 1410 4~ 136 160 ............... ............ 203~ 1400 40 136 160 ........ .............................. 10/13/97 800 1410 40 'J36 157 ...................... 3oo 1410 4o ....... ~ ..... ~i~? ........ _ _ __ ......... i0/14/97- ......... il--~5 ...... :~400 .......... 40 ...... 136 156 - ..... ............. ~i400 ...... 4b - 136 1~6 ............ ........................... ...... ¥0/~ 5i9'~ - i-40-d 140o ........ ~ ...... i3~ - i~,~ ......... . ..... .......... _.. ............................... 1400 40 136 155 .... .... i0/16/97 ....... ;173'0 ...... 'J40~ ......... 4b - - - i3i~ ';158 ......... · 2100 1410 ............ 46 -- - 'j36 168 ......... . .......... ......................... ......... 10117197 1300 1410 40 136 159 ......... 2100 1410 46 ~3~ -- ........... ................... 10118197 1415 1410 40~ 136 160 _ _ -'---14~b 40 ........... ,~36,_ '160 ....... 10i19/97 .... .1400 1410 40 136 163 2100 1410 40 ........... ~36 i67 ........... ....... 10120i97 12300 1410 4~ 136 165 ..... .......... 2100 1410 40 136 157 ..... ................. 10/21/97 1000 1410 40 136 163 , Page 2 JAL 2x-15 log book.xls · MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Joh~ DATE: Chairman-V"- September 15, 1997 THRU' Blair Wondzell, ~J'~ FILE NO: P. I. Supervisor FROM: Lou Grimaldi, ''j ~ ~,-~o~ SUBJECT: Petroleum Inspector OB9JINEE.DOC Top Job Cement Plug Arco Well #2X-15 Prudhoe Bay Field PTD #84.:.,~/~94-065 Saturday, September 13, 1997; I traveled to well 2X-15 in the CPF-2 side of ARCO's Kuparuk river field to witness repairs on this well~ 9 5/8' X 13 3/8" annulus. I met Randy Black (ARCO rep.) at the site this morning and discussed the procedure that he was to use in a attempt to stabilize the 9 5/8" casing and wellhead. 3/4" CPVC tubing was brought up and they started to run this into the annular space. At approximately 35' the tubing stopped and we could not push it in any further. The tubing was withdrawn and what appeared to be clabbered mud and cement was stuck in the end. This was cleaned out and the tubing was rerun at a different angle with the same results. It was decided to bring a pump truck out the next morning and try to wash down inside the casing while pushing the pipe. Sunday, September 14, 1997; I returned this morning and a pump truck was rigged up to pump down the 3/4" pipe. A 2 bbl/min, rate was established and the 9 5/8" X 13 3/8" was washed down to approximately 48'. The pipe seemed to be fetching up solid and we could not go any deeper. The annular space was circulated for thirty minutes and cleaned up until the returns were clear. Seven barrels of 15 PPG. class "G" were pumped and returns to surface were constant. The wellhead was secured with chain style come-alongs and wood blocks. SUMMARY: I witnessed the repairs to ARCO's well 2X-15 in the Kuparuk river field. Attachments: NONE. ARco Alaska, Inc. · Kuparuk Qperations Post Office Box 196105 Anchorage, Alaska 99519-6105 Telephone 907 659 2821 August 13, 1997 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in triplicate is an Application for Sundry Approval (Form 10-403) on the following Kuparuk well. Well Action 2X- 15 Repair Well If you have any questions, please call me at 659-7226. Sincerely, Jeff Kewin' Wells Superintendent Kuparuk Production Engineering Attachments Well Files (attach only) File: FTR022098 (w/o attach) ORIGINAL ARCO Alaska. Inc. is a Subsidiary of Atlantic Richfield Company AL/-~SKA OIL AND GAS CONSERVATION COMM~;SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon__ Suspend__ Operation Shutdown __ Re-enter suspended well__ Alter casing __ Repair well X Plugging m Time extension Stimulate Change approved program__ Pull tubing __ Variance Perforate __ Other __ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development X ARCO Alaska, Inc. Exploratory 112' RKB, 77' PAD feet 3. Address Stratigraphic __ 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Service _ Kuparuk River Unit 4. Location of well at surface 8. Well number 1109' FSL, 238' FEL, Sec. 4, T11N, R9E, UM 2X-15 At top of productive interval 9. Permit number 1274' FNL, 1430' FEL, Sec. 10, T11N, R9E, UM 84-167 / 94-065 At effective depth 10. APl number 1401' FNL, 1227' FEL, Sec. 10, T11N, R9E, UM 5o-029-21 1 99 At total depth 11. Field/Pool 1506' FNL, 1066' EEL, Sec. 10, T11N, R9E, UM Kuparuk River Field/Pool 12. Present we~ condition summary Total Depth: measured 8390 feet Plugs (measured) None true vertical 6285 feet Effective depth: measured 8281 feet Junk (measured) Top of 162' Vann Gun @ 7597' true vertical 6209 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 7 3' 1 6" 230 Sx AS II 103' 103' Surface 3644' 9-5/8" 850 Sx CS III & 3674' 2981' Intermediate 575 Sx CS II Production 8332' 7" 555 Sx Class G 8362' 6265' Liner 250 Sx CSI Perforation depth: measured 7850'-7870', 12 SPF, 120 Deg phasing ~\ ~ '~' ~ , r true vertical 5740'-5886', 5901'-5915', 6061'-6083', 6094'-6114' '~:i~'!I~ii'.; "I 8 1997 Tubing (size, grade, and measured depth) 3.5", 9.3#/ft, J-55 set at 7987' MD /~aska 0JJ & Gas ~;~,r~s, Packers and SSSV (type and measured depth) Baker "FHL" @ 7654', Baker "FB-I" @ 7957'; Baker "FVL" SSSV @ 1900' , 13. Attachments Description summary of proposal X Detailed operation program __ BOP sketch__ Repair Well 14. Estimated date for commencing operation 15. Status of well classification as: August 1997 Oil x O ,i NAL 16. If proposal was verbally approved Blair Wondzell 7/1 1/97 Name of approver Date approved Service Water Injector 17. I he__fy that the foregoing is true and correct to the best of my knowledge. Si~ned ~)~. t,.I,~...~ Title Wells Supervisor Date: 8/13/97 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IApEr~val N__.~o. Plug integrity BOP Test Location clearance~ I --~c¥,-~ Mechanical Integrity Test Subsequent form require 10- Approved by order of the Commission01'i(J'"8'l S'?rl~(J ~ Commissioner Date 0~] ~ IOpL~l Form 10-403 Rev 06/15/88 DS.¥IQ ~. ,~u~u~,,,,,, SUBMIT'~N T~:{I ATE Approved Copy Re, turned APPLICATION FOR SUNDRY APPROVAL KUPARUK WELL 2X-15 7/97 Kuparuk Well 2X-15 is a producer in the Kuparuk River Field. On 4/12/97, during a routine SSV test, the state inspector and the ARCO engineering technician discovered that the well had become mechanically unstable at the surface. The well was immediately shut in and has remained shut in. Further diagnostics showed that the well had 7" packoff communication and likely 7" casing movement. The weld at the conductor had been broken due to what we believe was thermally related 7" casing movement. Discussions since the incident led to an agreed upon action plan calling for stabilization of the 9-5/8" conductor and the replacement of the 7" packoff(s). See attached letter dated 5/28/97. ARCO proposes that an intermediate step be taken that might eliminate the need for all or a portion of the work described in the 5/28/97 letter. The plan, as discussed verbally between Blair Wondz~ll and Randy Black on 7/11/97, calls for the following steps: · Bring the well on line. Establish production rates at the same levels as before shutting the well in on 4/12/97. · Cement the 16"x 9-5/8" annulus as far down as possible with 1" tubing.' · Re test the 7" packoffs under production. If unable to test, attempt to, re engergize packoffs per manufactuer's and ARCO's regular practices. · Observe well for 7" pressure integrity and mechanical stability for 30 ' days while maintaining the previously established production rates. If the above steps are successful further work would not be necessary. Should the 7" packoffs be unable to maintain pressure, some or all of the actions outlined in the 5/28/97 letter would then commence. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 28, 1997 Mr. Blair Wondzell Alaska Oil And Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 (907) 276-7542 (fax) Re: KRU Well 2X-15 Repair Overview Mr. Wondzell I appreciate the time spent last Friday to discuss plans for repairing KRU' well 2X-15. As discussed, ARCO has a plan to move forward with these repairs. The repairs will eliminate future casing movement by securing in place both the 9-5/8" surface casing and the 7" production string. Last time we met, Mark Fissell, Bill Isaacson and I gave a brief overview of ARCO Alaska's plan to stabilize the 9-5/8" surface casing. As you may recall, the pi.an involved moving ,th.e .9.-.5/8" b..ack to !he position where it was at the time the problem was discovered and then securing / s[aDi~izing [ne casing via the base plate / gusset design presented. 'Ehis approach has been discussed with the wellhead. manufacture (Cameron) and is believed to be the best method to stabilize the wellhead and 9-5/8" casing. Clamps were discussed, however, due to the type of wellhead in place, there is no way to~ attach the clamp without significant welding on the wellhead. ARCO wishes to limit the welding on the wellhead (as recommended by Cameron) and therefore feel more comfortable with the base plate / gusset approach, which isolates welding to the mandrel hanger and 16" conductor. Base plates / gussets have been used successfully by ARCO in West Texas a?,,d the Gulf Coast in similar circumstances. Along with attaching the base plate / gusset, the 16" x 9-5/8 annulus will be cemented as far down a_~s ~ossible with 1" tubing. Once the 9-5/8" casing and wellhead have been secured, the 7" production casing will be speared, picked up, and re-set to verify proper weight is set on the slips. The weight to be set on the 7" casing slips will be that weight required to keep the 7" casing in tension under all future operating conditions. At that time the upper and lower 7" packoff will also be replaced to repair any wellhead communication problems between the 7" and 9-5/8" casings. ARCO does not intend to back off the 7" casing for several reasons. Most importantly, p.r. essure int.e, gr!!~/ of the 3-1/2" x 7" annulus has been confirmed and doing anything to change this, especim~y on a we~ w~[n pla,n,s for future gas lift, is not prudent.,, Secondly, once backed-off and the top of cement behind the 9- 5/8 is identified,,, perforating the 9-5/8 to bring cement to surface is not recommended due to loss of integrity on the 7 x 9-5/8" annulus and possible leak path to the surface. By accomplishing what is outlined above, ARCO believes both the structural concerns and the 7" x 9- 5/8" wellhead communication can be eliminated in a safe and effective manner. Detailed plans are underway but have not been finalized nor have project start dates been confirmed. Should you have comments, questions, or concerns, please feel free to contact me or my alternate (Gar Jordan) at 659- 7210. Thanks again. Sincerely, Randy Black Kuparuk Wells Supervisor ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. ~( Post Oifice Bo× 100360 Anchoi'age, Alaska 99510-0360 Telephone 907 278 1215 May 31, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston' Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL 2X-03 2X-15 ACTION Other (Inj Valve) Repair Well (K Valve) If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering Attachments (original + one) Well Files (atch only) FTR053196 (w/o arch) AR3B-6003-93 242-2603 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate Plugging Pull tubing ~ Alter casing Repair well X Perforate Other 2. Name of Operator ARCO Alaska, In(;. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 1109' FSL, 238' FEL, Sec. 4, T11N, R9E, UM At top of productive interval 1274' FNL, 1430' FEL, Sec. 10, T11N, RgE, UM At effective depth 1401' FNL, 1227' FEL, Sec. 10, T11N, R9E, UM At total depth 1506' FNL, 1066' FEL, Sec. 10, T11N, RgE, UM 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical 8390' 6285 8281' 6209' feet Plugs (measured) feet feet Junk (measured) feet 6. Datum elevation (DF or KB) ~'/I 112' RKB, 77' PAD feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2X-15 9. Permit_.~umbedapproval numb_er, 10. APl number 50-029-21199 11. Field/Pool Kuparuk River Oil Pool Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth 230 Sx AS II 1 0 3' 850 Sx CS III & 3674 575 Sx CS II 555 Sx Class G 8 3 6 2' 250 SX CS I 73' 1 6" 3644' 9-5/8" 8332' 7" measured 8070'-8098', 8115'-8141', 4 SPF, 120° phasing 7770'-7830', 7850'-7870', 12 SPF, 120° phasing true vertical 5740'-5886', 5901'-5915', 6061'-6083', 6094'-6114' Tubing (size, grade, and measured depth) 3.5", 9.3 #/ft, J-55 set at 7987' MD Packers and SSSV (type and measured depth) Baker "FHL" @ 7654'~ Baker "FB-I" @ 7957'; Baker "FVL" 13. Stimulation or cement squeeze summary SSSV @ 1900' Trueve~icaldepth 103' 2981' 6265' Intervals treated (measured) -3 1994 Treatment description including volumes used and final pressure Alaska 0[t & Gas Cons. Commissi )n Anchorage 14. Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 9 2 1 6 6 4 3 4 1 I 0 0 1 9 8 Subsequent to operation 3 5 4 1 7 2 1 7 4 1 2 0 0 3 0 3 15. Attachments 116, Status of well classification as: Copies of Logs and Surveys run __ I Water Injector __ Daily Report of Well Operations ~ I Oil ~ Gas __ Suspended . Service ~ · · qi~lnedV ~~?~)//~~~~ Title Senior Petroleum En~lineer Date ~ '~/~ ~ ~ ~orm 10-404 Rev 06/15/88 ' SUBMIT IN DUPLICATE q ~ ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT WELL DATE TIME DESCRIPTION OF WORK CONTRACTOR/KEY PERSON OPERATION AT REPORT TIME [~COMPLETE [] INCOMPLETE LOG ENTRY FIELD EST: $ 17¢~ AFC/CC ACCUMULATED COST PAGE 1 OF ~, Lo~. RECEIVED JUN '"3 1994 At2.ska lift & Gas (;oils. I.;OlfllrllSSJol't Anchorage I--1 CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather ITemp. Chill Factor I Visibility Report °F °F miles AR3B-7031 IWind Vel. knots 298-3486 ARCO Alaska, Inc. [ Post Office Box 100360 , Anchorage, Alaska 99510-0360 , Telephone 907 276 1215 March 4, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in triplicate are multiple Applications for Sundry Approval on the following Kuparuk wells. Well Action. 2A-09 Variance 2X-15 Repair Well If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering Attachments Anchorage AR3B-6003-93 242-2603 i STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS,b,ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend__ Alter casing __ Repair well ~ Plugging_ Change approved program __ Pull tubing m 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 1109' FSL, 238' FEL, Sec. 4, T11N, R9E, UM Operation Shutdown __ Re-enter suspended well __ Time extension Stimulate Variance _ Perforate ~ Other 6. Datum elevation (DF or KB) 112' RKB. 77' PAD 7. Unit or Property name Kuparuk River Unit 8. Well number 2X-15 At top of productive interval 1274' FNL, 1430' FEL, Sec. 10, T11N, At effective depth 1401' FNL, 1227' FEL, Sec. 10, T11N, At total depth 1506' FNL~ 1066' FEL~ Sec. 10~ T11N~ 12. Present well condition summary Total Depth: measured 83 true vertical 62 Effective depth: measured 82 true vertical 62 R9E, UM R9E, UM R9E~ UM 9 0' feet 85 feet 81 ' feet 09' feet Plugs (measured) Junk (measured) 9. Permit number/approval number 84-1-6'7' I =~F(.¢ 10. APl number 50-029-211 99 11. Field/Pool Kuparuk River Oil Po0i' 13, Casing Length Structural Conductor 7 3' Surface 3 6 4 4' Intermediate Production 8332' Liner Perforation depth: measured 8070'-8098', 7770'-7830', true vertical 5740'-5886', Tubing (size, grade, and measured depth) Size Cemented 1 6" 230 Sx AS II 9-5/8" 850 Sx CS III & 575 Sx CS II 7" 555 Sx Class G 250 SX CS I Measureddepth Trueverticaldepth 103' 103' 3674 2981' 8362' 6265' 8115'-8141', 4 SPF, 120° phasing 7850'-7870', 12 SPF, 120° phasing 5901 '-591 5', 6061 '-6083', 6094'-6114' 3.5", 9.3 #/ft, J-55 set at 7987' MD Packers and SSSV (type and measured depth) Baker "FHL" @ 7654', Baker "FB-I" @ 7957'; Baker "FVL" SSSV @ 1900' Attachments Description summary of proposal X Detailed operation program -_ RECEIVEI -9 1994 .... ~,~ uu & Gas Cons. CoEII ,Anchorage BOP sketch 14. Estimated date for commencing operation 2/25/94 Oil X 16. If proposal was verbally approved Blair Wondzell ¢~.. 2/25/94 Name of appro~er Date approved 17. , her..~)c~ ~t/~ng Signed 15. Status of well classification as: Gas Service is true and correct to the best of my knowledge. Suspended Title Senior En~lineer FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness IApproval No. Plug integrity BOP Test _ Location clearance __ I ~' ~'- Mechanical Integrity Test _ Subsequent form require. 10- ,, Approved by order of the Commission Form 10-403 Rev 06/15/88 Original Signed 8y David W .bh...st0n Commissioner Approved Dopy Returned SUBMIT IN TRIPLICATE issio Application for Sundry Approval Kuparuk Well 2X-15 Install K Valve 2/25/94 Kuparuk Well 2X-15 was re-fracture_ St~~i~d on 2/5/94. Followin , · · treatment, the wireline retrieva~,,,,-"'-~24',','-.'-'__t ....... g the sbmulatlon u~/ooov woJJla no[ rurlciion festin Indicates .control ?n.e. ,s plugged. Attempt.s~t¢Fclear the Ii/ne have been un~'u ..... '. 'g !-" the. · ' ' ~,u,. ,T IS proposed To repair me well by installing/aK Valve in/~he sssv profile. The valv ' , . This proposal received verbal approval from Blair Wondzell on 2/25/94. RECEIVED ^.task~. 0ii & Gas Cor~s. C0rr~missio~, Anchorage ARCO Alaska, Inc. J Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 4, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION 8~- L¢~ 1H-06 Stimulate ~z--t%cx::) 1 H- 17 Stimulate $2q- i'~{¢ 2X-15 Stimulate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering Attachments (original + one) Well Files (atch only) FTR030496 (w/o atch) RECEIVED ~n~:,.orage AR3B-6003-93 242-2603 i STATE OF ALASKA 'rL ALASKA OIL AND GAS CONSERVATION COMMI iON REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown ~ Stimulate ~ Plugging __ Pull tubing __ Alter casing Repair well Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service '4. Location of well at surface 1109' FSL, 238' FEL, Sec. 4, TllN, R9E, UM At top of productive interval 1274' FNL, 1430' FEL, Sec. 10, T11N, R9E, UM At effective depth 1401' FNL, 1227' FEL, Sec. 10, T11N, R9E, UM At total depth 1506' FNL, 1066' FEL, Sec. 10, T11N R9E 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical 8 3 9 0' feet Plugs (measured) 6 2 8 5 feet 8 2 81 ' feet Junk (measured) 6 2 0 9' feet 6. Datum elevation (DF or KB) 11;~' RKB, 77' PAD 7. Unit or Property name Kuparuk River Unit 8. Well number 2X-15 9. Permit number/appro 10. APl number 11. Field/Pool River Oil Pool 13. Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 7 3' 1 6" 230 Sx AS II 1 0 3' 1 0 3' Surface 3644' 9-5/8" 850 Sx CS III & 3674 2981' Intermediate 575 Sx CS II Production 8 3 3 2' 7" 555 Sx Class G 8 3 6 2' 6 2 6 5' Liner 250 SX CS I Perforation depth: measured 8070'-8098', 8115'-8141', 4 SPF, 120° phasing 120° phasing 8115'-8144', 4 SPF, 180° phasing 7770'-7830', 7850'-7870', 12 SPF, true vertical 5740'-5886', 5901 '-591 5', 6061 '-6083', 6094'-6114' Tubing (size, grade, and measured depth) 3.5", 9.3 #/ft, J-55 set at 7987' MD Packers and SSSV (type and measured depth) Baker "FHL" @ 7654', Baker "FB-I" @ 7957'; Baker "FVL" SSSV @ 1900' Stimulation or cement squeeze summary Re-fracture Stimulated A4 and A3 Sands with 273000 pounds of 16/20 and 12/18 pounds of Carbolite Intervals treated (measured) 8070'-8098' and 8115' 8144' MD Treatment description including volumes used and final pressure 2516 BBLS Gelled Seawater, 273220 lbs proppant, final treating pressure = 5600 psi ECE]VEr 14. Prior to well operation Subsequent to operation 1 5. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure 0 0 0 1100 psi 208 psi 378 186 394 820 psi 208psi 16. Status of well classification as: Water Injector Oil __X Gas Suspended__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '~~/~/ ~~"* Title Senior Operations Engineer I~nrm ln_~nz~ ~,,,/ nci/l,~/cin Date .ql IRIs/lIT Ikl 1'311131 I~ATI= ARCO Alaska, Inci Subsidiary of Atlantic Richfield Company WELL IPBDT 2. X- 15 8~81 CONTRACTOR REMARKS FIELD- DISTRICT- STATE OPERATION AT REPORT TIME JOB C.,OMPL ET'~' WELL SERVICE REPOR'I -cA'" SA/gD R~.F,RAO---'-- 6~0o- i/IO ,4,1/£/./FRJ~C E~P'7:. ~-Ub ~ AC ?/..u~bS, P£oP. ,S/~FETY MTG. //50 F'~'/~. P/,~As. Pu,~P ~.tot W'~ J:~WU 7'~ , W4R~ UP ~EE ~V~7~ ~ ~='7'. '7"F_S'r l../~E5 $0o0 P,S~ . 5300 Pa t . PSi, ~¢:. pt~B PUMP ON ANN, DuE. 'TO R ITIN& t_F_AK, 13z4. P,,14P 340B~L. P~E. PAb '~ I0 BaL- ~ I ~t't~ Z914o. /EBP~ , 5'8'O0.~aX, 351~,eU F/UA-L) ..T. ST.? ~.zz4 ?~l. 1515 PMP 340 ¢~ DATA F~AC '~ /0 a~L ~ I ~'~ ~o/4o. /5 8PM , ..~,~1~ ~-x ). 5587 ps/ F/X/Ac.., .TST..P 2~78 p..s~. C^LC. FL~m EFF ~ +-.. 55'~o. D~E~U~ PAD ~NCR -"Y65-O'ro 9oO ~L... PMP 900 ¢BL PAl) ¢__, ;7 ¢eM. 54::,ZO e.¢~ ~X ~, 5588 ~'.~l 1744.. PMP FR/~C.. ~N ?__.to 14P/,A ,s'f'Ar...,Eb, 54DO-4800PSI, /SrvS~/zt3?M. Zo/4.o 'rt4tScf I~ 2. PPA ,.STA6E~ 16/2,0 FLNSB EARt. Y PUlE TO tNCRE/t-$/AJG I~ESS. AFT'E~ D~,oPPIN4 RATE ~ ~ '7 '/4. ~PM, /~T 57 y2.. BIDL I, NTZ) FLNSH~ .~HNg' DoWN ~ 1-O HI61-~ pl~. $000 FLm.~N LINES ~ E~P'T, R b ¢/"8AC ~ SmPPCr/'~ E..c2.P'T. /...o51" RNBB~ O~P oFF 7~EE' 55oo "to iooo pst ~ 5 / z . cc: q987_.60 ~sT: 45o7685 * MAINIAI~ 3~-3~ P~l o~ 7" AN~ ND P~OBL~. o LA~ tN ZPPA ~T~E E~c~IC ~Ni~/~Q ~pt~. LOJT PMP ~ FO~ ~ Z MIN, WRE~ ~A~ IN~ R~NRN~ 5AND VOL. ~TALI~ OV~TA~D BT APP~K. ~K. ~ANNALLY C~K'd ~A~/Nq VOL. t~ BIN6~ MANNALLY d~OL~ ~AMP. AF~ ES~A~tNG wH~E MAR '-9 ~" A, iasfca OiJ & Gas Cc.,r,:.:~ ,.,ummission i--] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather Temp. Chill Factor Visibility Wind Vel. Report °F °F miles knotsI Signed REMARKS OONTINUED: ,, ~ DESCRIPTION DAILY ACCUM. TOTAL CAMCO OTIS SCHLUMBERGER DRESSER-ATLAS DOWELL HALLIBURTON ARCTIC COIL TUBING FRACMASTER ,,, · B. J. HUGHES Roustabouts Diesel Methanol Supervision Pre-Job Safety Meeting AFE LIL ~t ~ 6o~ ~t ~ ~oo0 ARCO Alaska, Inc. ,~os'I Offic9 Bc~"' 30360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 17, 1993 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION '-"'~' .... ~ 1F-02 Perforate ~.~q..-. i73 1L-01 Perforate ~.--l':;:'k" 2X-1 3 Perforate ~:-1%, 2X-1 5 Perforate //3A-03 Stimulate ,~5"~ "-. 3A-03 Perforate ~%-~.'5~ 3A-1 0 Perforate if you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering ARCO Alaska, Inc. Is a Subsidiary of AtlanticRIchfleldCompany I STATE OF ALASKA ~ A[' .,~A OIL AND GAS CONSERVATION COMI{I jION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown __ Stimulate Plugging Pull tubing ~ Alter casing Repair well Perforate X Other 2. Name of Operator ARCO Al~t~ka, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 1109' FSL, 238' FEL, Sec. 4, T11N, R9E, UM At top of productive interval 1274' FNL, 1430' FEL, Sec. 10, T11N, R9E, UM At effective depth 1401' FNL, 1227' FEL, Sec. 10, T11N, R9E, UM At total depth 1506' FNL, 1066' FEL, Sec. 10, T11N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical 8390' 6285 8281' 6209' feet feet feet feet Plugs (measured) Junk (measured) 6. Datum elevation (DF o.r,,,~) 112' RKB, 77' PAD'"'~-,)~,, feet 7. Unit or Property name '~...<'") Kuparuk River Unit ., 8. Well number .'~ 2X-1 5 9. Permit number/approval number j ,¢ 10. APl number 50-029-21199 11. Field/Pool Kuparuk River Oil Pool 13. 14. Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented 73' 16" 3644' 9-5/8" 8332' 7" 230 Sx AS II 850 Sx CS III & 575 Sx CS II 555 Sx Class G 25O SX CS I measured 8070'-8098', 7770'-7830', 7850'-7870', true vertical 5740'-5886', Measured depth True vertical depth 103' 103' 3674 2981 ' 8362' 6265' 8115'-8141', 4 SPF, 120° phasing 12 SPF, 120° phasing 5901'-5915', 6061'-6083', 6094'-6114' Tubing (size, grade, and measured depth) 3.5", 9.3 #/ft, J-55 set at 7987' MD Packers and SSSV (type and measured depth) Baker "FHL" ~ 7654', Baker "FB-I" ~ 7957'; Baker "FVL" Stimulation or cement squeeze summary Reperforate A Sands @ 4 SPF @ 180° phasing Intervals treated (measured) Reperforated 8115'-8144', MD RKB Treatment description including volumes used and final pressure SSSV @ 1900' ~ ,.,.,, ,, , ,_ ~ KtttlVtU DEC 2 1 1993 Alaska Oil & Gas Cons. Commission Representative Daily Average Production or Injection D¢ta Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X OiI-Bbl Gas-Mcr Water-Bbl N/A N/A N/A 11 96 48 16. Casing Pressure Tubing Pressure N/A N/A 1100 psi 208psi Status of well classification as: Water Injector Oil X Gas Suspended Service 17. I hereby certify that the foregOing is true and correct to the best of my knowledge. Signed ~~~' ~ Title Senior Operations Engineer Form 10-404 Rev 09/12/90 Date / Z- / 7 "~' 3 SUBMIT IN DUPLICATE ARCO Alaska, Inc. 0 Subsidiary of Atlantic Richl~d Company WELL DESCRIPTION OF WORK 2X-15 RE-PERFORATE A3 SAND DATE CONTRACTOR / I~Y PERSON 11/22/93 SCHLUMBERGER/SACK RATHERT DAY PBTD (RKB) LAST TAG (RKB) . DATE 1 8281 8164- 11/12/93 KUPARUK RIVER UNIT WELL SERVICE REPORT l c,cc#, so,# , ~I 230DS28XL - 10223 In u, cos-r IACCVM-VL COSX [ $7,925 l. $7,925 Isssv TYPE / STATUS ...... ' ' lC.MCfl .... TIME 1245 LOG ENTRY 'MIRU SCHLUMBERGER, STDBY FOR WELLHEAD X-OVER 1430 RIH W/1 11/16" TOOL STRING, HE~, CCL, MPD, 29' 2.5 T1TAN, 4 SFP, 180 DEGREE PHASING, ALTERNATING BH (DOWN) and DP (uP), ORIENTED 137 DEGREES CCW FROM THE HIGH SIDE. 5.5' FROM CCL TO TOP SHOT 1530 1615 1700 TIE IN TO CBL DATED 11/7/84, PULL UP TO 8109.5 W/CCL, SHOOT 8115' TO 8144', POOH OOH, ALL SHOTS FIRED RDMO SUMMARY: RE-PERFORATED A3 SAND FROM 8115' TO 8144' W/4 SPF '~995 Anchorage or~ CHECK THIS BLOCK IF SUMMARY IS CONTINUED ON BACK COMPLETlil INCO~LET~ Weath~rReport ITeml~' ']ChIll Factor,, ]Visibility miles,, ,,,- ]Wind VeL "{Slgn~j ,mph[ ~[~o~t;~,,,~'/.o/./J/l~$toot'th, ,,, ,,, STATE OFALASKA ~ 0 ~ I G ~ l~ A ~ A~-.~ OILAND GAS CONSERVATION COMMIS,'51ON . .... ,~ :.: REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown __ Stimulate X Plugging Perforate Pull tubing Alter casing Repair well Pull tubing Other 2. Name of Operator ARCO Alaska, Inc, 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 1109' FSL, 238' FEL, Sec. 4, T11N, R9E, UM At top of productive interval 1274' FNL, 1430' FEL, Sec. 10, T11N, At effective depth 1401' FNL, 1227' FWL, Sec.10, T11N, At total depth 1506' FNL, 1066' FEL, Sec. 10, T11N, 12. Present well condition summary Total Depth: measured 8 3 9 0' true vertical 6285' R9E, UM R9E, UM R9E, UM feet Plug? (measured) feet ~ 6. Datum elevation (DF or KB) 112' RKI~ 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2X-1,5 9. Permit number/approval number 84-167 / 9-453 10. APl number 5o-029-211 cjcj 11, Field/Pool Kuparuk River Oil Pool Effective depth: measured 8 2 81 ' true vertical6209' Casing Length Size Structural Conductor 72.5' 1 6" Surface 3643.5'9 5/8" Intermediate Production 8 3 31 .5' 7" Liner Perforation depth: measured 8144'-8115', 8098'-8070' 7870'-7850', 7830'-7770' true vertical feet ~ Junk (measured) feet None Cemented Measured d~pth .. 230 Sx AS II 1 03.~ 850 Sx CS III & 3674' 575 SX CS II 555 Sx Class G 8 3 6 2' 250 Sx CS I True vertical depth 103' 2981' 6265' 4 SPF 120 degree phasing 12 SPF 120 degree phasing 6114'-6094', 6083'-6061', 5915'-5901' Tubing (size, grade, and measured depth) 3 1/2" 9.3 Ib/ft, J-55, 7987' MD RKB Packers and SSSV (type and measured depth) Baker FB-1 @ 7957', Baker FHL @ 7654', Baker FVL @ 1900' 13. Stimulation or cement squeeze summary 14. , 5886'-5740' TVD RECEIVED Intervals treated (measured) 7870'-7850', 7830'-7770' .Anc~0r~j3 Treatment description including volumes used and final pressure 337 bbls gelled water, 15 bbl diesel, 30,300 lbs of 16/20 Carbolite, final pressure 6500 psi. Re0resentative Daily Average Produ~ion or Inje~ion Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 7 7 0 1075 167 Subsequent to operation 209 126 0 1050 126 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations. X. 16. Status of well classification as: Oil X Gas Suspended , Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge, Fnrm '' -t3a. I~R.v ~3R/I~/RR Title Senior Operations Engineer Date RI IRMIT IN 1311PI I~ATI:: ARCOAlaska, In~ ~ Subsidiary of Atlantic Richfield Company WELL PBDT - '"NTRACTOR REMARKS FIELD - DISTRICT- STATE OPERATION AT REPORT TIME WELL SERVICE REPORT 15'3o 2~ J * ? /,¢,z¢ 15",FO / ! v ¢../ [] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK STATE OF ALASKA ~"' ALASKA OIL AND GAS CONSERVATION COMMI,'SSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown__ Stimulate Plugging Perforate Pull tubing Alter casing Repair well Pull tubing Other ..~ 2. Name of Operator ARCO Alaska. In(;, 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service . Location of well at surface 1109' FSL, 238' FEL, Sec. 4, T11N, R9E, UM At top of productive interval 1274' FNL, 1430' FEL, Sec. 10, T11N, R9E, UM At effective depth 1401' FNL, 1227' FWL, Sec.10, T11N, R9E, UM At total depth 1506' FNL~ 1066' FEL, Sec. 10, T11N~ R9E~ UM 12. Present well condition summary Total Depth: measured true vertical 8390' feet 6285' feet Plugs (measured) 6. Datum elevation (DF or KB) 112' RKB 7. Unit or Property name Kuparuk River Unit feel~ 8. Well number 2X-15 9. Permit number/approval number 84-167 / verbal bv L. Smith 10. APl number so-029-21199 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 8 2 81 ' true vertical 6209' feet Junk (measured) feet 13. 14. Casing Length Structural Conductor 7 3' Surface 3 6 4 4' Intermediate Production 8 3 31 ' Liner Perforation depth: measured 8144'-8115', true vertical 6114'-6094', Size Cemented Measured depth True vertical depth 1 6" 230 Sx AS II 103' 103' 9 5/8" 850 Sx CS III & 3674' 2981' 575 Sx CS II 7" 555 Sx Class G 8362' 6265' 250 Sx CS I 8098'-8070', 7870'-7850', 7830'-7770' 6083'-6061', 5915'-5901', 5886'-5740' Tubing (size, grade, and measured depth) 3 1/2" 9.3 Ib/ft, J-55, 7987' MD RKB Packers and SSSV (type and measured depth) Baker FVL SSSV @ 1900', Baker FB-1 ~ 7957'~ Baker FHL @ 7654' Stimulation or cement squeeze summary Intervals treated (measured) 7870'-7850', 7830'-7770' Treatment description including volumes used and final pressure scale inhibitor squeeze treatment, 36 bbls diesel w/solvent~ 94 bbls "SOC" scale inhibitor~ 470 bbl sea water~ final pressure 2000 psi. Re0resentative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Anchorag~ Prior to well operation 500 225 1000 1025 160 Subsequent to operation (est) 5 0 0 2 2 5 1 0 0 0 1 0 2 5 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations ~'. Oil X Gas Suspended __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service . 160 Signed ~c.t' .....).- /("'z'~ ...,"L~'~'' ~,''''~ ..~,~.,r',Z~ .,,,(.,'.~'~ Title Senior Operations Engineer Form 1 - Rev F06/15/88 Date ~/'~/ ~'/('¢/)' SUBMIT IN DUPLICATE ARCO Alaska, Inc! ,a Subsidiary of Atlantic Richfield ComDany WELL SERVICE REPORT WELL PBDT CONTRACTOR ,vlARKS i FIELD - DISTRICT - STATE OPER.~TION ,~T REPORT TI M E iDAYS DATE [--] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather Temp. I Chill Factor Visibility ]Wind Vel. Report °F] "F miles Signed (' STATE OFAU~,A ( 0 R ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well _ Plugging Change approved program _ Pull tubing _ 2. Name of Operator 15. Type of Well: Development ARCO Alaska, lnG, Exploratory 3. Address Stratigraphic P. O. Box 100360, Anchorage, AK 99510 Service 4. Location of well at surface 1109' FSL, 238' FEL, Sec. 4, T11N, R9E, UM At top of productive interval 1274' FNL, 1430' FEL, Sec. 10, T11N, R9E, UM At effective depth 1401' FNL, 1227' FWL, Sec.10, T11N, R9E, UM At total depth 1506' FNL, 1066' FEL, Sec. 101 T11N, R9E, UM 12. Present well condition summary Total Depth: measured 8390' feet true vertical 6285' feet Operation Shutdown _ Re-enter suspended well _ Time extension _ Stimulate ~ Variance Perforate Other 6. Datum elevation (DF or KB) Plugs (measured) RKB 112 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2X-1,5 9. Permit number 84-1§7 10. APl number 5o-029- 21199 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured true vertical 8281' feet Junk (measured) 6209' feet None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 72.5' 1 6" 3643.5' 9 5/8" 8331.5' 7" measured 8144'-8115', 8098'-8070' 7870'-7850', 7830'-7770' true vertical 6114'-6094', 6083'-6061', Cemented Measured depth True vertical depth 230 Sx AS II 1 0 3' 1 0 3' 850 Sx CS III & 3674' 2981' 575 Sx CS II 555 Sx Class G 8362' 6265' 250 Sx CS I 4 SPF 120 degree phasing 12 SPF 120 degree phasing 5915'-5901', 5886'-5740' Tubing (size, grade, and measured depth 3 1/2" J-55 set at 7987' Packers and SSSV (type and measured depth) Baker FB-1 @ 7957'1 Baker FHL ~ 7654'r Baker FVL ~ 1900' 13. Attachments Description summary of proposal X Refracture A Sand with gelled water sand frac. Detailed operation program _ BOP sketch 14. Estimated date for commencing operation June, 1 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil _X Gas Service Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~.~ ....t~ .,~ ,- ,d-~.,~...~_,-~,, ~,,~ _ . ~ ...t-~ Title - FOR ~MMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test ~ Location clearance~ Mechanical Integrity Test _ Subsequent form require Approved by the order of the Commission ORIGINAL SIGNED BY LONNIE C. SMITH 10_ ,/TL~ q- ~pproved Copy Returned Commissioner IlAppr°val No.4:~ ....,~v~.. ~.. Date Form 10-403 Rev 5/03/89 SUBMIT IN TRIPLICATE 5/24/89 Kuparuk Well 2X-15 A Sand Fracture Procedure Cost Tracking AFE #K80283 . . . , . . . MIRU Slickline unit. Tag bottom. Pull C Sand CV's at 7911', 7724', and 7686' RKB. Run DV's at 7911', 7724', and 7686' RKB. RDMO. Adjust lift gas rate to approximately 100-150 MCF/D, or lowest stable rate if lift gas is not stable at 100-150 MCF/D. Obtain 24 hour well test. MIRU Slickline unit. Pull GLV's and OV @ 7587', 7075', 5940', and 2075' RKB. Run DV's. (NOTE: GLM @ 4291' RKB currently has DV in place.) Set standing valve in Camco 'D' nipple at 7979' MD-RKB. Pressure test the tubing. Pull standing valve. RDMO. RU fracture equipment. Install "Tree Saver". Pressure up 7" annulus to 3500 psi. Carry out all fluid quality control procedures(Onsite Operations Engineer). Obtain a sample of the proppant and of the gelled water and gelled diesel with breaker. Check the proppant for fines. Record proppant weight prior to pumping. After frac, verify and record weight of remaining proppant. Obtain samples from pad and slurry stages while pumping. Pump the 90 Bbl pre-pad at 25 BPM. Shut down and determine the ISIP. If the treating pressure is excessive, be prepared to pump ball sealers to open perfs. (The A Sand was perforated with 228 holes with a diameter of 0.38") Pump fracture treatment per the attached schedule. Expected wellhead treating pressure: WHTPE = 4750 psig Fracture Gradient = 0.75 psi/ft (6030' TVD) Tubing Friction = 180 psi/1000 ft (7950' MD) If excessive treating pressures are experienced, try reducing rate in small increments, down to a minimum rate of 15 BPM, adjusting additive rates as appropriate. If treating pressure at 15 BPM exceeds 6000 psi, shut down job and confer with engineering. The maximum recommended treating pressure is 6500 psi based on analysis of tubing strength and PBR type. 8. Rig down frac equipment. Follow attached flowback procedure. 5/24/89 Kuparuk Well 2X-15 Post-Frac Flowback Schedule Cost Tracking AFE #K80283 I , . , , , . Operations Engineer -- Place frac fluid samples in a 140°F water bath and verify that the gel has broken by the design break time. Then contact Production to initiate flowback. DO NOT ATTEMPT FLOWBACK IF GEL HAS NOT BROKEN. Contact Anchorage Engineering to discuss options if gel remains unbroken. It's recommended that a baseline choke inspection be obtained while the well is shut in, or while the well is being flowed to tanks. This inspection will establish the initial condition of the choke, and allow for any obstructions to be removed before the flowback. To start flowback, open choke to establish a 5 to 10 bbl per hour flow rate. If excessive proppant is produced or unbroken gel is apparent, SI WELL AND CONTACT OPERATIONS ENGINEERING. Do not exceed 10 bbl per hour for the first day of flowback. Record straps, choke settings, and WHP's. Develop a choke inspection program based on the initial well response, the well's piping, choke size, and other factors influencing the risk of erosion from the particular well's flowback, through discussion with the Drill Site Foreman, Drill Site Supervisor, Corrosion Engineering, and KOE. On the second day, decrease wellhead pressure by 50 psi each 12 hours. Monitor flowback to check for gel or proppant. Again, if unbroken gel is apparent CONTACT OPERATIONS ENGINEERING immediately. Continue to reduce wellhead pressure by 50 psi each 12 hours. Send strap volumes to A. Ramirez/B. O'Dell for transmittal to Anchorage Engineering. Application for Sundry - Well 2X-15 A Sand Refracture Treatment No BOP's are used during the fracture. The fracture treatment will be pumped through a manifold on surface. A Sand Pressure (6200' SS) = 2543 psi 10/01/87 SBHP offset well 2X-14 A Sand Pressure (6200' SS) = 2963 psi 11/04/88 SBHP No workover fluid will be used during this process. ARCO Alaska, Inc. Post Offic '00360 Anchorage. za 99510-0360 Telephone 907 276 1215 Date: November 25, 1987 Transmittal #: 7019 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2X-15 Kuparuk Well Pressure Report(Otis) 10-1-87 2V-4 Kupaurk Well Pressure Report(Otis) 11-16-87 2X-13 Kuparuk Well Pressure Report(Otis) 10-1-87 2X-16 Kuparuk Well Pressure Report(Otis) 10-3-87 Static 'A' Sand 'C' Sand PBU 'A' Sand PBU 'A' Sand Receipt Acknowledged: DISTRIBUTION: D&M SAPC /.,, r,~' ~,,r,. ,. ' ~ ~ .~ c~ ~.,.1~ t''~' ?,,~,.. ,~, ...... ,,. ,.,.,. ~,, ..... ~ state of ~ ~evron Mobil Unocal ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Incr," Post Offic~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 .. DAT~;: 10-22-85 TP, ANSMITTAL NO: 5410 RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEEItING RECORDS CLEkK ATO-1115B P.O. vOX 100360 ANCHORAGE, AK 99'510 TRANSMITTED HEREWITH AK~ ~rt~: FOLLOWING I'£E~IS. RECEIPT AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. FINAL PRINTS/ SCHL/ ONE * OF EACH CEMENT. BOND LOG/ VARIABLE DENSITY " '~3B-8 06-06-85 RUN #1 5850-8369 ~ 42X-15 11-07-.84 '~2X-13 11-17-84 ~2X-12 12-08-84 '~2X-11 12-08-84 '-~X-10 12-21-84 '~ 2X-9 12-20-84 ~ 2W-6 11-25-85 '~ 2V-16 06-06-85 "~ 2V-15 06-07-85 "'2V-13 ' 06-03-85 -.~2U-8'~' ' 04-02-85 RUN RUN RUN RUN RUN RUN RUN RUN RUN RUN 'RUN ~"'.'2U-7 :?~'' 04-01-85 KUN 2U-6 :.i'i.'~'.'' 03-31-85 ". RUN 571',i:::: 0 4-01- 8 5 2 U- 4 ..~i::~.:i::':i. 03- 02- 85."" i.(.U N ..'~2D-16,% ' 12-19-84' hUN 2D~15'::':.'', 12-18.-84 RUN ~"'2D- 1" 11-03-84 RUN ~lR-8 ' 06-17-85 RUN "~'lR-7 · 06-08-85 · t{UN · ~R-5 06-08-85 t{UN · "~ 1L-15. 11-05-84 RUN lQ-15 05-27-85 RUN '~J1Q-3 ' 04-17-85 , HUN %CPF-1A 12-21-84 CEMENT EVALUATION TOOL 1F-'16 . 03-12-85 RUN ~lR- 5' ~.:.,: :~: ~.'' 06-26-85 RUN ~1~-5' 06-27-85 ~' RUN :, . .... '~2U-2":'"'"::' 03-25-85 "':. hUN ' ~2U-15 '''' 03-07-85 hUN '~3B'9 ' '.. -06-30-85 ' RUN ~3C-11 06-29~85 RUN =~3Ci12 06-29-85. ' RUN .. BPAE B. CURRIER CHEVRON , D &M 5900-8258 5896-8410 3050-7215 3100-6370 3350-6973 5100-8338 5700-7290 4550-7108 4650-6428 6590-8553 4970-6938' 0070-~122 5600-8107 5994-9161 6284-7850 5200-7459 3285-6454 5693-6652 5987-8324 4302-7028 6950-8628 4883-6600 6490-7566 - 8978-10744' 2200-3856 LUGS/. Ck~4ENT ~VALUATION LOGS %1. 8269-8712 _% 2 #1 %1 6974-'8~44 .8254-8532 5790-9450 6400-7002 6000-8246 6500-8726 5400-7457 DRILLING*BL _ L. JOHNSTON. mO B I L '" NSK CLEi~K*DL W. PAShhR EXXON PHILLIPS OIL J. RATHmELL' PLEAS~ ACKN~4LEDGE SOEIO~' ........... '-' t~'/SE ...... . UNION VAULt/~0' FIL~I ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany 3 ~/ ARCO Alaska, Ir~' Post Offi6. ,.,.,x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 08-21-85 TRANSMITTAL NO: 5296 RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHOkAGE, AK 99510 TRANSMITTED HEREWITH ARE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RECEIPT AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL. SEQUENCE OF EVENTS FROM WELL SERVICE REPORTS PRESSURE DATA ~1C-4 '- 07-23-85 '-~ 1C-5" 07-29-85 "~ 1C-5 ,~- 07-30-85 '~1C-6 ~' 07-25-85 "'~iC- 6 .... 07-24-85 '~iD-8 -~ 07-30-85 ~ 1H-3' 07-30-85 --1R-5' ' 07-05-85 '-'--1~- 6' 07-06-85 -~ 1R-~ · 07-U~-85 1Y-10 - 07-27-85 1Y-11-' 07-28-85 2A-2 07-04-85 2S-13' 07-30-85 2U-14' 06-30-85 2U-14" 07-01-85 2U-15' 07-08-85 2V-2 07-27-85 2V-2. 07-28-85 2W-7" 07-26-85 ~2W-7" 07-27-85 2X-15' 07-09-85 ., 2X-15" 07-04-~,5 2Z-l' 07-05-~5 "- 2Z-6' U4-08-85 ~'3B-7 ~ 06-27-85 3B-8~' 06-28-85 3B-8-~ 06-27-85 '~3B-9 ~ 07-18-85 3B-11 07-20-85 3B-12 07-21-85 3C-11 07-29-85 STATIC BHP PBU PBU STATIC BHP STATIC BHP STATIC BHP STATIC BHP ~HP & MISC. BHP & MISC. STATIC BHP & ~,~ISC. STATIC BHP END OF PBU 'C' SAND STATIC BHP PkESSUkE DATA 'A' SAND PBU 'A' SAND PBU PRESSURE TEST & HISC. 'A' SAND PBU 'A' SAND PBU 'A' SAND ONLY PBU 'A' SAND PBU FLO%~ING BHP & FLUID I.D. FLOWING BHP & TEMPEI{ATURE BHP SURVEY & MISC. STATIC BH'P STATIC BHP & MISC. STATIC BHP & MISC. BHP & MISC. STATIC BHP & MISC. BHP SURVEY & MISC. STATIC BHP & MISC. STATIC BHP ,~ MISC. RECEIPT ACKNOWLRDGED: BPA~.'* B. CURRIER CHEVRON* D & M* DRILLING L. JOHNSTON DISTRIBUTION: W. PASHER EXXON HOBIL* PHILLIPS OIL* NSK CLERK J. RATHMELL* · ARCO Alaska, Inc. is a Subsidiary o! AtlanticRichfieldCompany CAMCO DRESSER ATLAS DRESSER ATLAS CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO DRESSER ATLAS OTIS OTIS OTIS OTIS OTIS OTIS OTIS OTIS OTIS OTIS OTIS OTIS CAMCO CAMCO OTIS CAMCO CAMCO CAMCO CAMCO E E I STATE OE ~'ASKA* SOHIO* UNION* K. TULIN/VAULT ARCO Alaska, Inc. Post Office Box[~ .{60 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 30, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT: Well Completion Reports Dear Mr. Chatterton: Enclosed are Well Completion Reports for the following wells: 2W-4 2X-15 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU10/L93 Enclosures ' ~'aOrage' ~,ol~mi~ioa ARCO Alaska, Inc. is a Subsidiary of AtlanticRIchfieldCompany ~.STATE OF ALASKA ALASKA ._ANDGAS CONSERVATION cC~,, AISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well REVISION OIL ~(X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-176 3. Address 8. APl Number P, 0. Box 100360, Anchorage, AK 99510 50- 029-21199 4. Location of well at surface 9. Unit or Lease Name 1109' FSL, 238' FEL, Sec.4, T11N, RgE, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1274' FNL, 1430' FEL, Sec.10, T11N, RgE, UM 2X-15 At Total Depth 11. Field and Pool 1506' FNL, 1066' FEL, Sec.10, TllN, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 112' RKB] ADL 25645 ALK 2576 , 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 10/15/84 10/22/84 1 2/09/84 N/A feet MS LI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 8390'MD,6285'TVD 8281'MD,6209'TVD YES [~X NO [] 1900 feet MD 1500' (Approx) 22. Type Electric or Other Logs Run D IL/FDC/CNL/GR/SP/SFL, Gyro, CBL/VDL/CCL/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOL'ESIZE CEMENTING RECORD AMOUNT PULLED , 16" 62.5# H-40 Surf 103' 24" 2;~0 SX Arcti(; Set II · . . 9-5/8" 36.0# J-55 Surf 3674' 12-1/4" 850 sx CS Ill & 575 sx C$ II 7" 26.0# J-55 Surf 8362' 8-1/2" 555 sx Class G & 250 ~ C$ , 24. Perforations open to Production (MD+TVD of Top and BottOm and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 8144' - 8115' 3-1/2" 79~17' 7957' & 7~5~, 8098' - 8070' w/4 spf, 120° phasing 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 7870' - 7850' DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 7830' - 7790' w/12 spf, 120° phasing See attached Adde~ldum. dated 5/2/85. 7790' - 7770' , 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED=k. OIL-BBL GAS-MCF WATER-BBL ~OILGRAVITY-API (corr) Press· 24-HOUR RATE ~ 28. CORE DATA Briefdes~ripti~n~f~ith~~~gy~p~r~sity~fract~r~s~apparentdipsandpresen~e~f~i~~gas~rWater~S~bmitc~rechips~NONE A!aska Oil & Form 10-407 GRU10/WC26 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEQLOGICMARKERS ' ' 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 Upper Sand 7769' , 5839' N/A Base Upper Sand 7872' 5916' Top Lower Sand 8046' 6043' ~ ' .... Base Lower Sand 8228' 6172' ] . · , , . · , 31. LIST OF ATTACHMENTS , , Addendur~ , , , 32. I hereby certify that the foregoing, is true and correct to the best of my knowledge . Signed '~)~7~ .,~J_//~,J~/ Title Associate Engineer Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska .... Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing, the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10,407 ADDENDUM WELL: 11/07/84 11/09/84 4/01/85 2X-15 Arctic Pak w/250 sx CS I, followed by 65 bbls Arctic Pak. 8281' PBTD Rn CBL/VDL/CCL/GR f/8258' to 5897' WLM. Rn GCT gyro from surf to 8250' WLM. Frac well in 8 stages w/312 bbls belled diesel, 800# 100 mesh & 11,000# 20/40 mesh. Drill~endent RECEIVED Alaska Oil & 'Date ARCO Alaska, Inc. i' Post Office Bo,, ~00360 \ Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 24, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2X-15 Dear Mr. Chatterton: Enclosed is an addendum to the 2X-15 Well History to include with the Well Completion Report dated 04/16/85. If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRUIO/L05 Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. ~.' Post Office B(~. .,0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 19, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT' Revised Well Dear Mr. Chatterton. Completion Reports Enclosed are revised Well Completion Reports for the following wells. 2A-2 2D-5 2E-14 2A-3 2D-14 2E-16 2A-4 2E-10 2G-14 2A-5 2E-11 2H-3 2C-15 2E-12 2W-11 2C-16 2E-13 2X-15 These reports were revised to reflect the cement quantity used when each well was Arctic Packed. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU6/L06 Enclosures RECEIVED APR 2 21985 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRIchfleldCompany STATE OF ALASKA ([ ALASKA ~ ._ AND GAS CONSERVATION C , ,vllSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well REVISION OIL [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-176 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21199 4. Location of well at surface 9. Unit or Lease Name 1109' FSL, 238' FEL, Sec.4, TllN, RgE, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1274' FNL, 1430' FEL, Sec.10, TllN, RgE, UM 2X-15 At Total Depth 11. Field and Pool 1506' FNL, 1066' FEL, Sec.10, TllN, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) [ 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 112' RKB[ ADL 25645 ALK 2576 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 16. No. of Completions 10/15/84 10/22/84 12/09/84I N/A feet MSL 1 17. TotaIDepth(MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set I 21.Thickness of Permafrost 8390'MD,6285'TVD 8281 'MD,6209'TVD YES [~X NO [] 1900 feet MD 1500' (Approx) 22. Type Electric or Other Logs Run D I L/FDC/CNL/GR/SP/SFL~ Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSlZE WT. PERFT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62,5# H'40 Surf 103, 2/~" · - -rr .... , 9'5/8" 36.0# J-55 Surf 3674' 12-1/4" 850 sx CS III & 575 .~× CS II 7" 26.0# J-55 Surf 8362' 8-1/2" 555 sx Cla~ 0 & 250 s: CS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 8144' - 8115' 3-1/2" 79R7' 7q57' & 7654' 8098' - 8070' w/4 spf, 120° phasing 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 7870' - 7850' DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 7830' - 7790' w/12 spf, 120° phasin, g N/A 7790' - 7770' 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED=1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE APR 2 ,o ..... Alaska Oil & 6as 6ons. 6ommissien Form 10-407 JHM2/WC29 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE -. . 29. 30'. .... . . ' ' "'. FORMATION TESTS': GEOLOGIC MARKERS ' . NAME Include interval tested, pressure data, all fluids recovered and gravity, . MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 7769' 5839' N/A Base Upper Sand 7872' 5916' Top Lower Sand 8046' 6043' Base'Lower Sand 8228' 6172' : · . · . , , . ., . ., . , . , · , · ., ,,., , , : . : , 31. LIST OF ATTACHMENTS ,., , , 32. I hereby certify that the foregoing is true and correct to the' best of my knowledge Signed ..... _~O. ~f)(-~/ -'~'~~ Title Associ ate Engi neer Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this'form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 Show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none" Form 10-407 ADDENDUM WELL: 11/07/84 11/09/84 2X-15 Arctic Pak w/250 sx CS I, followed by 65 bbls Arctic Pak. 8281' PBTD Rn CBL/VDL/CCL/GR f/8258' to 5897' WLM. Rn GCT gyro from surf to 8250' WLM. RECEIVED J U L 0 ,~;' ]985 Alaska Oil & Gas Cons. Commission Anchorage Dr-illin~-Super int end ent Date ARCO Alaska, Inc. Post Olfice Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 'l"Fc/~i',!,'ii;i'.:i:l:'l"l"E!'.~)' I..lli!:l:;:E:l,i.l:'f'H ~::'~I:;:l!i: 'l"l..llii: F:'[:)I...I...E~I,,.J]:'i'.,~E ]:'i'IEH,.;,. I::'l...li!:~'~:.~'lii: ';' '" ]:) [] N ;.~;' i'.,! [:] F' :1: ~;' '1" I? ~ i".!.? H :I: 'i' '1" r~'~ I... I', I::. C Ii.=. :[ F' T ~'::~ i".! R Iii: '1" U I::,' N Iii: :1: E Iii: )) C (:)I::' Y T H ,. ARCO Alaska., Inc. Post Oli'ic 360 Anchorag,-, A~aska 99510 Telephone 907 277 5637 ,,. ., ~:'.~ T'I" N" I:;: Iii; [; [)I:;: I),S' C I... r..!: F:,' I< F.:, T [)..- i i i 5 B (l.'.;F:'~[,~ I-)OX 1,0(;):~6,';> '(>, i:.,~ C I. If] I':: ¢, 6 ii..: (', I< 9 '": .....:~ t ,?> . . 'F' I),. H Ii!: IR Iii: !.J ]i T H r..'~ F;.: E T H Ii!; F:' 0 L.. I..¢'11...I ]: F! i.'; N ,. ,.. ,.;. ' , . ~. ......... I:;: Iii: [':: [ii: :[ !::"1: .. (.'~! ! ):') 17 Iii: T I...I F.:.F!, (] i:.! E ,S' ]: (;; i".! I:': .1;::, .... ....... 1.10'l...li!: i':':r'.,' ' ],: r., I... '.. l!!:'l::: :1: l',! T .? ,S' r, H L. l If'i q r:' ,::, n: Fi: F:.: ;.., ... ¢,, i.,.~ ,,;,, ...... . ,..,.¢:,, ...... , . ,, ~, C Y !.)Ii!; I:;: I... [)(:)l< ,f,, ,,, ,.r ,, I) il: L./,.'., I" 1... ' .,,,. ~ ~,, 5" . F:',I),C/' C N L. '"' C; F;I :~,,. ..... . I::' I> C ,," C N I.... "" [;. I';'.. I:.::,q W ' " '"" I) ,./... ,,/ ~..'. -,,~. ]:1 .... ":'F:'L.. ":'" F:' 1:, i:: / I'l N I... "" F.;. F:: R ¢~ kl ,,,' ........ , ,, , , · x ,/ -,,. ,~ '"':...'." F:' D C, C N L.. '"' C; 17' I::' [) i ...... I:." I1: I::' fl % // f::' II ~ /' .,..' ,'~n ...% . ~...'. ~' C 'f: I.) E: I::~ I... [) (:] I< . . .,,",..,' .CI' I; .I. 1...,/,:, F' I... (~ R I> I.":: i'.,! / i',l E: t..I...,. [.'.; I:;.: I::: ¢', iAI I) F.i: i'.! i N Iii: I.J ...-(:.; F:: F:' (:)I:;: (:) !:, :1: I.../,'.i: F:' I....". [; F;,' I) E: l".! / ii Ii;: U '"' (:-) F;,' F:' (:)I::: (:) I> iii: N / N Iii: U '"' C; I:;: F;: ¢, ,, r:: I::: [:: Iii: :1: F:"T' A C K i,.l (:) H I... E: I)(.; E: I) · '5 t ,::'.., ;b ' F;' I If...!,", '~ '" .,,. t 6 ," 4 .... ,..:~:" 6"r ,:,.,,'. ,',,..: R I.! N'"' ' ....... '"~ "; "~ '''~' · ii' i '<>~',":', ,' "; .... ,;::,....: "¥ F;: I..J i",! "" ' ....." ........... .,,. t ,:: <':~ ? ,.1. .... :' "" ':~,5 7 4 .... S 7; 4"> f;: t.! ~ .I .,,. t ..... ... I:;~1.1'..". ' ...... .. I,!.,,, t , ,3,':~ ;' '~ :" ::~ ..... ~' 4. , . ...... ~ ..... : ,.,"., ,..) ", :,.. I, "" I,, LIN,,,, i 3 6 r 4 .... ,:::,'"' I:;:1 l i"~'"' ''~ ....... ~ 4 3 0 "' 6 2! ~ 4 · 'I1' .,.% f ¢.',, F;'. U l'.,I :Il: ~,:~ ' ' 2 ,.L::, ()'..., 6 '2 ,'3 4. "i:.;: U/'J '"' '') ' ':):4 -'.r F:/'.'..,.'. ':',".', '.:, ,'11' ,,.;, ~'t .,,,, '1,,,,,! ,,, ';.,' ,,,2 -,.. ~ .., , ,.,.~ ,:.~. ~"~ .... I, I..I I.!.,,. ,::. "> :5 .':':, ""~ '" ..;. .... :7 ,;:. ,;:., % ~::,~ ~ ;..j .,,. ,:) ,.~ ,.~ -~. ;.:., .... ..'. ,.~,:.:~ ,-~ ,,,11( '11' t.,, ,',,',, '7 ;,,~ ,/ ' ~.,,~ ~"., ~.,? ('t -..!.:: L. ) . , I) :1:/.i' '1" I:;: :1: !':': !.J 'f' ]: 0 i".! ' ARCO'Alaska, Inc. Is a subsidiary ol Alhll'HtCl[lchli,,,.IdCompan'y .. :7:. S"F (:','I" I!!: i:) I::' ,".', I...,q .S'I< ~.'.', .... .,. I::. ) ~-.' O,H ]. ('1 ( t ['i~ I..."" i ' ..... t. li",! :1: [:)N (F:":I:'I.:H,?) '.'. i .... ]F.':I... ) ')':'1( .,. T[!I..': ]; i":!,."V¢'~t..ll... 'T' .' . · . ,.. ARCO Alaska, Inc."~' Post Office B(~. ~00360 Anchorage, Alaska 99510 Telephone 907 276 1215 February 5, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2X-15 Dear Mr. Chatterton' Enclosed is a copy of the 2X-15 Well History (Completion Details) to include with the Completion Report, dated 12/21/84. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU4/L128 Enclosure xc' 2X-15 Well File RECEIVED FEB 1 1 l B5 Alast(a Oil & Gas Cons. commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany /. ARCO Alaska, In~''" Post Offic~ _ u., 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Date: 1/23/85 Transmittal No: 4925 RETURN TO: ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 / Tr.~smitted herewith are the following items. Please acknowledge receipt /~nd return one signed copy of this transmittal. BHP REPORTS & SEQUENCE OF EVENTS 2B-lw'> 10/16/84' '"Static" SBHP 2B-i~ 10/17/84 " " 2B-2~~' .....10/17/84 " " 2B-6X ........ "6/02/84 " 2B-10f~ 6/02/84 " 2B-11~_ 6/03/84 " 2B-12N.-- 6/02/84 " 2B-14~ .... 10/28/84 " " 2B-13y. .....10/28/84 " " 2D_5.A 10/05/84~ ,, ,,. 20-1~ 9/21/84 "Static/G. Ring" 20-2 * .... 9/22/84 " " 20-3 .~ 9/23/84 " " 20-4 ~ 9/23/84 " " 20-8 % .... 9/30/84 2F-15,~ 4/13/84 2X-13~"12/18/84 2X-14..~~ 12/21/84 .2X-15% ..... 12/23/84 2X-16¥"12/21/84 · . "Static/G. Ring/Tag" SBHP Receipt Acknowledged: lB-3 ~ :?" 6/26/84 SBHP 1B-4~/ .~.,6/26/84 " · . lB-6 Y .... 7/01/84 " 1E-2 w 6/22/84 " 1E-7 ~ :.--"~ ~/14/84 " 1E-4 ~-- 10/15/84 " 1E-12 ~.'... 6/24/84 ' " 1E-20X-- 6/23,22/84 " 1E-22~ ~ 4/23/84 " 1E-25~ .... 6/23/84 1E-25~ 11/09/84 1E-29.~" 6/23/84 1E-29} 10/14/84 1F-4 *,.. 9/14/84 1F-4 ~ ..... 9/14/84 1~-7 '~" 7/05/84 1F-11 ~-~ 4/25/84 1P-14~ ..... 2/07/84 1F-15%~ 2/14/84 10-1. ...... 6/29/84 ¢iG-1N .- 9/13/84 /10-3 ,. ...... 5/16/84 v 10-5.' 6/29/84 1H-4 ~-- 6/24/84 1Y-3 ~ 1/21/84 1Y-5~ 5/06/84 1Y-9~'~- 5/06/84 10-14.--' 1/12/84 1L-2 ~-'~ 10/21/84 iL-3 '~"- Date: DISTRIBUTION B. Currier Drilling "Static" BPAE Geology Chevron Mobil D&M NSK Ops. Il ,, ,1 " "Static" II 'I II II I1 II ,1 ' II II " "Static" II ,! II I1 I! II 11 II Il Il Il Il ,, /cat w. Pasher State G. Phill±ps Sohio ,.~ '~' Phillips Oil Union J. Rat~ell Well Files ARCO Alaska. I.l~C. is a subsidiary of AllanllcR'chi[eldComDan¥i ' ARCO Alaska, Inc. { Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 December 26, 1984 Mr. C. V. Chatterton Commi ss i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- 2X-15 Dear Mr. Chatterton. Enclosed are the Well Completion Report and gyroscopic survey for the subject well. I have not received the portion of the 2X-15 Well History covering the completion details. When I do, I will forward a copy to you. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU3/L21 Enclosures RECEIVED DEC 281 0~! ~x Gas Cons. Cor~misslol3 Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompany WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. ~'t-atus of ~Vell Classification of Service Well OIL I-~x GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-176 3. Address 8. APl Number P. 0. Box 100:360, Anchorage, AK 99510 ............... 50- 029-21199 4. Location of well at surface ~ VE.,-,i~-J~.!.g i 9. Unit or Lease Name 1109' FSL, 238' FEL, Sec./+, T11N, RgE, UM Kuparuk River Unit At Top Producing Interval t~::::'' 'i 10. Well Number 127/+' FNL, 1430' FEL, Sec.10, T11N, RgE, UN ,B.H._.-- [ 2X-15 At Total Depth 11. Field and Pool 1506' FNL, 1066' FEL, Sec.10, T11N, RgE, UN Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River Oi I Pool 112' RKBI ADL 256/+5 ALK 2576 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 10/15/84 10/22/8/+ 12/09/84I N/A feet MSLI 1 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 8390'ND,6285'TVD 8281 'MD,6209'TVD YES [] NO [] 1900 feet MD 1500~ (Approx) · 22. Type Electric or Other Logs Run D I L/FDC/CNL/GR/SP/SFL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 103' 24" 230 sx Arctic Set II (f.pprox.) 9-5/8" 36.0# J-55 Surf 3674' 12-1/4" 850 sx CS Ill & 575 sx CS II , 7" 26.0# J-55 Surf 8362' 8-1/2" 555 sx Class G .24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) , r 8144' - 8115' 3-1/2" 7987' 7957' & 765/+' 8098' - 8070' w/4 spf, 120° phasing 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7870' - 7850' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7830' - 7790' w/12 spf, 120° phasing N/A 7790' - 7770' 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF wATER-BBL .CHOKE SIZE IGAS-OILRATIO I TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED .l~ OIL-BBL GAS-MCF WATER-BBL' OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE RECEIVED Alaska 0il & Gas C0~}s. Commission Anchorage Form 10-407 GRU3/WC14 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. ,. 30., . : GEOLQGIC 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 Upper Sand 7769' 5839' N/A Base Upper Sand 7872' 5916' Top Lower Sand 8046' 6043' Base Lower Sand 8228' 6172' , 31. LIST OF ATTACHMENTS 32. ............ I hereby"'certi~'y' - ' [~a~ ...... foregoing~is true and correct to the best of my knowledge , Signed ~ ~J ~U~ ~,Lb~/~/' Title Associate E,gi neer Date.., 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 (G L) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO 011 and Gas Company Well Hl~...~ry - Initial Report - Dally Inal~ucll~ne: Prepare Ind submit the '°Initial Repo~l" on the first Wednesday after a well Is spudded or workover operations are stirred. Dilly work prior to spudding should be summlrlzed on the form giving Inclullve dates only, District Alaska Field Kuparuk River Auth. or W.O. no. AFE 304344 iCounty, parish or borough North Slope Borough ILease ADL 25645 or Unit ITItle Comp 1 e t ion Istate Alaska ,/Vall no. 2X-15 Roll'N 4 Operator ARCO Alaska, Inc. Spudded or W.O. begun loire I Completion Date and depth as of 8:00 a.m. 11/13/84 12/07/84 Complete record for each day reported API 50-029-21199 12/o6/84 IHour 1430 Hrs. I^.CO w.,. 56.24% Prior status if e W.O. RU CBL ts, RIH w/CBL/VDL/CCL/GR & 6.109" 8272' to 5897'. RIH w/Gyro, tl failure. surf-8250' WLM. gauge ring f/ RIH w/GCT f/ 7" @ 8362' 8282' PBTD, Perf'g 10.0 NaCl/NaBr Accept rig @ 1430 hrs, 12/06/84. ND tree, NU & tat BOPE; OK. Perf 8144'-8124', 8124'-8115', 8098'-8090', 8090'-8070' w/4" gun, 4 SPF, 120° phasing. Perf 7870'-7850' w/5" csg gun. RECEIVED F E B 1 1 1985 Alaska 0il & G~s Cons, (;glillTIISSi0~'l Anchor:.?.g~ The above Is correct Signature For form prepara~on-a'~d-dl~b-utl~-n;' see Procedures Manual, Sed~on 10, Drilling, Pages 86 and 87. JDate 12/19/84 ITM Drilling Superintendent ARCO Oil and Gas Comr .y Daily Wel .story-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged. Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not reduired upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation il space is available. I Accounting cost center code District ICounly or Parish IState Alaska North Slope Borough Alaska Field JLease or Unit I Well no. Kuparuk River I ADL 25645 I 2X-15 Auth. or W.O. no. ~Title AFE 3-4344 I Completion Roll'N 4 AP1 50-029-21199 Operator ARCO Alaska, Inc. Spudded or W.O. begun Completion A.R.Co. W.I. 56.24% Date 12/06/84 Date and depth as of 8:00 a.m. Complete record for each day reported 12/08/84 thru 12110/84 Iotal number of wells (active or inactive) on this DSt center prior to plugging and I bandonment of this well I our ~Prlor status If a W.O, I 1430 Hrs. 7" @ 8362' 8282' PBTD, RR Kuparuk crude oil Rn 5" csg gun, perf 7830'-7810' @ 12 SPF. Rn 5" csg gun @ 12 SPF, perf 7810-7790' & 7790'-7770'. TIH w/6.125" gage ring/JB. TIH w/Bkr 7" WL set FB-1Pkr, set @ 7950'. PU BHA & blast Jts, rn 3½" tbg. PU Bkr FVL SSSV, tst @ 5000 psi. Land tbg, set pkr & tst tbg to 2500 psi. Tst ann & up tbg @ 2500 psi. Sheared PBR. Set BPV, ND BOPE, NU tree, pull BPV, tst tree to 5000 psi. Tst pack-off to 5000 psi. Pmp 30 bbls diesel, followed by Kuparuk crude dn ann. Shut SSSV, bled tbg to 500 psi; OK. Open SSSV. Sheared out ball catcher. Set BPV. RR @ 1000 hrs, 12/9/84. ~ Bkr FB-1 Perm Pkr @ 7956.79' - Bkr FHL Pkr @ 7654.02' Tbg Tail @ 7986.66' - SSSV @ 1900.06' Old TD I New TD I PB Oepth I I Released rig J Date IKInd of rig 1000 hfs 12/09/84 Classifications (o11, gas, etc.) { Type completion (single, dual, etc.) Oil I Single Producing method I Official reservoir name(s) Flowing I Kuparuk Sands Potential test data Rotary Well no. I~a'ie Reservoir Producing Interval Oil or gas Test time Production Oil on test Ga~ per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective d~'te corrected The above Is correct 12/19/84 Drilling Superintendent For form prel~aratlo~d ~trtbu;lon, ' sea Procedures Manual, Section 10, Drilling, Pages 86 and 87. ARCO 011 Inetmctlone: District Alas Field Well History'-Initial Report- Dally-: Wto~eldey ifil, a will Ii apudded or wo~V. ovlr operetlone em on the form giving Inclualve datll only.. Auth. or W,O. no. AFE 304344 Nabors 26-E North Slope Borough Leall or Unit., ADL 25645 stet, Alaska Vell no. 2X-15 Title Drill API 50-029-21199 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded ARCO W.I. ]Dat. IHour [Prior statu. If & W.O. 10/15/84 2345 hfs 56.24% Date and depth as of 8:00 a.m. 10/16/84 10/17/84 10/18/84 .'~..~'. 10/19/84 Complete record for each day reported 16- ~ ~ 10~/ 700', (597'), DD Wt. 9.1, PV 17, YP 34, PH 9.5, WL 12.6 Accept rig @ 1630 hrs, 10/15/84. NU diverter sys. 2345 hfs, 10/15/84. Drl 12-1/4" hole to 500', DD to 700'. 539', 2.6°, 835.5E, 538.99 TVD, .81VS, .728, .51E 630', 5.8°, 840.5E, 629.73 TVD, 7.01VS, 5.97S, 4.62E 16"~ ~ IO~t 2088', (1388'), TIH w/BHA #2 Wt. 8.8, PV 17, YP 22, PH 10, W'L 14.5, Sol 7 DD, drl & surv 12¼" hole to 2088'. 721', 9.4°, 848.5E, 719.92 TVD, 18.62 VS, 14.558, 13.04E 903', 14.5°, S55.5E, 897.76 TVD, 56.67 VS, 37.938, 43.44E 1084', 18.7°, S57.5E, 1071.28 TVD, 108.00 VS, 65.898, 86.54E 1389', 26.9°, 858.5E, 1351.83 TVD, 227.17 VS, 125.848, 189.53E 1608', 33.8°, 858.5E, 1541.97 TVD, 335.42 VS, 184.85S, 280.41E ._~Z~L[~'.,. 43.9°, S58.5E, 1855.83 TVD, 598.27 VS, 321.348, 505.08E 16" ~ ~ 10.5I 3155', (1067')~ TIH w/BHA #5 .... ~9,4, PV 25, YP 34, PH 9, WL 11.4, Sol 7 ~i~.:~ '"~ ...... " r 2 "h ' ~~~D~,,& suv 1¼ ole to 3155 . 624.0E ~~?i:'$0.0°, S55.5E, 2275.69 TVD, 1045.48 VS, 560.65S, 883.13E ~i~.5.9°, S58.SE, 2506.58 ~VD, 1318.06 VS, 716.63S, 1107.61E .......... 3085', 46°, S60.SE, 2572.63 ~VD, 1386.33 VS, 751.29S, 1166.43E 9-5/8" @ 3674' ' 3696', (541'), RD Cmt Lns ""'-Wt.' 9.52' PV 24, YP 33, PH 9, WL 9, Sol 10 Drl f/3155'-3696' 10 std sbt trip, no fill. C&C hole. POH SLM, LD BHA. RU to rn 9-5/8" csg. RIH w/92 its 9-5/8" 36# J-55 HF-ERW BTC csg. Lnd on Tankco fluted hgr, RU BJ hd. Pmp 5 bbl FW, tst ins to 2000 psi, ok. Mix & pmp 850 sx CS III @ 12.2 ppg. Mix & pmp 575 sx CS II @ 14.9 ppg. Pmp 5 bbl FW. Fin displ w/mud. Cmt to surf. CIP @ 0530 hrs 10/19/84. FC @ 3591'; FS @ 3674'. 3085'MD 46° 860.5E 2572.63'TVD 1386.33'VS S751.29 1166.43E 3312'MD 46.3°S60.5E 2729.89'TVD 1550.01'VS S831.90 1308.91E 3512'MD 46.9°859.5E 2867.31'TVD 1695.32'VS S904.55 1434.76E The above ia correct. Slgnatu,e I Date see Procedures Manu~, Section ~. Drilling, Pagea 88 and 87. D['C 2 8 39B4 ITitle ' :. Drillings.. Superintendent AR3B-459-1 Alaska Oil &.,-.Gas Cons. Commission Anchorage Number all dally well history forme conaecutlvely aa they are prepared for each well, [Pag~ no. ARCO Oil and~_~? Company Daily Well History--Interim Instmctlone: This form ~l~'dl~.rl~.or workover operations, if testing, coring, or perforating, show Iormation name in describing work performed. Number all drill stem te~'"~~.¢l~crlption of all cores. Work Derformed by Producing Section will be reported on "Interim" sheets until final completion. Report offi~.or rep ~lllllaf~._~i~ 011 "Final" form. 1) Submit "Interim" sheets when filled Out but not less frequently than every 30 days, or (2) o. Wednesday of the w~'" ~?o..'~:~..--~ "~..-~---- s,,bmlt ..kly t ..... k ...... d fo.owi.g se.in° o, o...~ u~,. co.~,.,o.. District Alaska Field ICounty or Parish Jstete Alaska North Slope Borough ILease or Unit [Wellno. ADL 25645 2X-15 Kuparuk River Date and deptll as of 8:00 a.m. 10/20/84 thru 10/22/84 10/23/84 10/24/84 10/25/84 Complete record for each day while drilling or workover in progress 9-5/8" @ 3674' 8142', (1034'), Drlg Wt. 10.0, PV 20, YP 14, PH 9, WL 6, Sol i0 RD BJ, ND diverter, NU & tst BOPE, instl WB. PU BHA, GIH to 3591', tst csg to 1500 psi; OK. DO FC, FS + formation to 3707' Conduct formation tst to 12.5 ppg EMW. Drl, ND & surv 3707'-8142'. 3747', 48°, S61. 4144', 48.2°, S64. 4397', 47.5°, S62. 5025', 47.1°, S60. 5651', 45.4°, S62. 6249', 46.0°, S56. 6876', 44.5°, S59. 7191', 42.4°, S59. 7537', 41.4°, S60, 5E, 3026.22 TVD, 1868.40 VS, 989.80S, 1585.43E 5E, 3288.53 TVD, 2166.13 VS, 1131.22S, 1847.66E 5E, 3458.31TVD, 2353.23 VS, 1214.91S, 2015.51E 5E, 3884.19 TVD, 2814.19 VS, 1431.57S, 2422.98E 5E, 4316.09 TVD, 3267.23 VS, 1651.25S, 2819.26E 5E, 4729.92 TVD, 3698.67 VS, 1874.08S, 3188.73E 5E, 5173.46 TVD, 4141.72 VS, 2100.62S, 3569.46E 5E, 5402.13 TVD, 4358.34 VS, 2210.56S, 3156.13E 5E, 5659.66 TVD, 4589.39 VS, 2326.09S, 3956.24E 9-5/8" @ 3674' 8390', (248'), TIH Wt. 10.0, PV 16, YP 10, PH 9, WL 5.8, Sol 10 Drl 8142'-8390', circ, 10 std short trip, C&C, POH. RU Gearhart, log DIL/GR/CDL/CNL/CAL, SP out. RD Gearhart. RU ~Rchl, GIH w/DIL/SFL/GR/SP/CAL/FDC/CNL; could not pass 5750', POH, RD Schl. GIH f/wiper trip. 9-5/8" @ 3674' 8390', (0'), C&C mud Wt. 10.0, PV 12, YP 6, PH 8.5, WL 6.2, Sol 12 FIH, tight spots 5800'-6600' & 6800', C&C, 28 std short trip. Pm. tight spot 8056'-8390') C&C, POH. RU Schl. GIH W/DIL/CAL/CNL/GR/SP/SFL/FDC, tl failed. POH, CO tl, log 8390'-3674', RD Schl. GIH, rm 8148'-8390', C&C f/csg. 7" @ 8362' 8390', (0'), Make rough cut on 7" 10.0 NaC1/NaBr C&C, POH, LD DP. CO rams to 7" & tst. RU & rn 209 jts + 2 mrkr its 7", 26#, N-80 HF-ERW BTC csg w/FS @ 8361 & FC @ 8281'. C&C mud. Cmt w/80 bbls BJ'mud sweep @ 11.0 ppg, 230 sx C1 "G" + 6% gel, 3% KCi,' 2.5% D-19, 1% D-31 & .25% R-5 @ 11.9 ppg, followed by 325 sx C1 "G" w/3% KC1, .7% D-19, .3% D-31 & .1% D-6 @ 15.9 ppg. Displ w/320 bbl 10.0 ppg brine. Bump plug w/3000 psi. Flts held. CIP @ 0410 hrs, 10/25/84. PU BOP & set slips. 'Cut 7". The above is correct Signature For form preparation and dlstrYbutior~r - see Procedures Manual Section 10, t' Drilling, Pages 86 and 87 Date 11/21/84 AR3B-459-2-B Drilling Superintendent RECEIVED DEC 2 8 191] Alaska Oil & Gas Cons. Commission Number all daily well history forms consecutively as they are prepared for each we '. IPage~no, ARCO Oiled, .,, Gas Compa"~~*' ,~ Daily Well History-Final Report Instructions: Prepare ~L~lJlJlfrelr-th _~,~j~l~'tl'.,,on the first Wednesday after allowable has been assigned or well is Plugged. Abandoned, or Sold. "Final Report" ahoulc~J.eubl~ftJf~li'J~J~.~-~tJJ]~l¥.~l)eretlone ere suspended for an indefinite or appreciable length of time. On workovers when an official test ia not required upon compl~l~lJ~, .relx~lf, L .r..~41~.l.l_[j~[l~'i[~'[d_repreaentative test data In blocks provided. The "Final Repeft" form may be used for reporting the entire District ' ~[~ County or Parl~h [ State Alaska~. I North Slope Borough I Alaska Field '. ~Lease or Unil Well no. Kuparuk Rtve~'"~'---'~' '1 AI)L 25645 I 2X-15 Auth. Or W.O. no. I Title AFE 304344 I Drill Nabors 26-E Operator ARCO Alaska, Inc. Spudded or W,O. begun Spudded Date and depth as of 8:00 a,m, 10/26/84 API 50-029-21199 IA.R,Co. W.I. 56.24% IDet, 10/15/84 Complete record for each day reported 7" @ 8362' 8281' PBTD, RR 10.0 NaC1/NaBr Cut 7", ND BOPE. to 3000 psi; OK. 10/25/84. Iotalnumber of wells (active or inactive) on this Dst center prior to plugging and I bandonment of this well I our Prior status if · W.O. 2345 hrs Make final cut on 7" csg. NU tbg spool & tat RD & pmp out cellar. RR @ 1345 hrs, Old TD. .._ New TD PB Depth Released rig Date K nc~ of rig 1345 hfs 10/25/84 Classifications (o11, gas, etc,) Type completion (single, dual, etc,) Oil Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data 8281PBTD Rotary Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T,P, C.P, Water % GOR Gravity Allowable Effective date corrected The above is correct For form preparation and di~t~bution, see Proced .... M .... I, Section 10, ~iC ~ ~% ~,~ Drilling, Pages 86 and 87. Nas~a 0il & G~s Co~s, gomm~ssio~ Ancho;'~ge AR3B-459-3-C ITltle Drilling Superintendent Number all dally well history forms cor~secuttvely es they are prepared for each well. iPag~ no. Dlvldon o! Atllmtk:RIcMleldC~pany, SUB.SURFA CE DIRECTIONAL SURVEY F'~ UIDANCE F~ONTINUOUS ~"~ O0 L Company Well Name Field/Location ,ATL,ANTIC RIC,HF,I, ELD COMPANY 2X-15 (1109' FSL~ 238' FEL~ S4, T11N, R9E, UM) ,,K,,UPARUK, NORTH SLOPE, ALA$1<,A ..... .. Job Reference No. 69807 Logged By: JOHNSON RECEIVED "')" 2 ....... ~'.'i Alaska 0il & Gas Cons. Comrnissio~ Al~chorage Date D.EC-6-84 Computed By: STEVENS GCT DiRE~IUNA[, SURVE~ C U~T~t-~ER I,IST I,~G A~CO AI,A.SKA. iDaC. ?A-15 KUPARuK SURVEY L)A 9'F': C;[15Tt)~-'-ER l, lSfl,i(; ARCt] AI,Ab;KA, INC, 2x-L5 K tJP.qRIjK !":OR'I'H SL,(IPF_,, Al_,A,qr~h A Lo A L; K A i .,"J "I' F: I~ P U I, A 1' E I', VA[,UF& OATI'E: 8-f~OV-84 . 2O0. 300, 40(';. 600 o 70A . 800. 900 . O0 00 O0 0 u DATE uF' SURVEY: H-NUV-R4 KELi, Y BOShING EbEv'AT1UN: EN(; T t,~ I.~E.R: dOHNSON l?O0. 1300. 1400, 1500. 1600, 1700o 1~00, 0 U Ou Q0 O0 00 00 20UO. 2100. 22UO. 2300. 2400. 2500, 2600. 2700. 2Rt)O. 2900. O0 o 0 00 Ou nO 0 o g. dO.Ob lo lq S 50 b9 E c)'15.33 19 ~ S 57 47 E 1068.56 72 43 S 59 42 E 12b0.71 20 b2 S 5U 15 F 1~.3~,q5 29 2 S 5b b! k 1424.74 ~{.t ~ S 57 43 ~; 15~4.92 q9 't2 S 5~ 22 F' 16o0..~9 4Z 3 S 5~ q8 E 3000. 31 uo, 32~0, 330n. 3400. 350O. 3600. 3700. ~ROo. 3900. 00 O0 OU 0u O0 1~45. 19 191c~.b6 1990.02 2060,06 2!2d,U8 2195.32 2260.34 7324,bl 238 't. 02 2449,16 PAGE 1 2515,74 2eSb,.Lfi 2723,99 2792.02 29?9.99 299 J, 306-~. I 5 112,00 2403.74 lb 44 ~ %~ 58 F 2413.92 254].11) 40 24 $ 61 20 F 26Il.gq 268f).82 40 42 2a17.49 4'1 1.~ S 60 47 F 2gUS, {0 4 2952.15 48 3f) l~.n8 DOGLEG RIECTANGIJLA~ COORDINATES HOt{IZ, SEVERITY Nt. ItiTH/Sf)tJT[t EAST/~ES'I' i)IST, DEG/1 O0 FEET FEFT FEET DEPARTURE AZIMUTH DEG MIN 0°0 -0.3 -0.7 -1 ,0 -0,~ 3,4 13.1 2.9,8 51.3 0.00 O.O0 N O.O0 E O.O0 0.22 O.ul N 0.04 W 0.04 0.05 0.09 S 0.44 W 0.45 0.0~ 0,32 S 1.03 w 1,08 o.14 0,73 S 1,66 W 1.81 2.84 l.b5 S 1.93 W 2.47 1,~1 5.49 S 0.76 K b.b5 3,~3 12,~3 $ 7 70 ~ ~4,96 3.30 23.76 S 20:b7 E 31.50 3.28 3b,8(.) $ 37.99 E 52.U9 N 0 0 E N 81 47 w 5 77 59 $ 72 41 S 66 21 w S 51 lb $ 7 52 ~ $ 30 50 841 $ 45 54 77.1 1o7.4 143.5 103.4 225.0 273.0 324.2 381 .S 4.43.7 509.3 2..t7 51.20 S 59.b0 E '18.bO .t.02 67.01 S 8b.O1 E 108.o2 1,78 80.34 S 115.~9 E 144.b2 0,93 105.9b S 150,ol F 184,15 4.H1 12b.92 S 18'/,5A ~. 22o.4B 2.55 153.13 S 22b.77 E 273.63 5.ug IB1.3'I S 269.o3 E 324.9b 2.b5 211.39 $ 31~.'t6 ~ 382.49 2.~ 244,20 $ 371.38 E 444.47 2.ul 277.91S $ 49 17 E 8 53 1~ E 5 54 52 E 5 55 54 k 8 56 4 E 5 56 40 E 8 56 58 E 5'17.2 645.8 715.! 786.5 850.6 934 .? J 00~ . 9 10~6.6 1104,3 1247.~ 7 1,ol 313.04 S 9Hb,40 E b77.92 5 O.b9 34~.8'1S 544.25 ~: b46.47 7 I.U3 384.~3 $ 003.76 K 715.'/b 2 1.38 ~21.b! S 064,74 E 787,11 O 1.~8 ~bO,lO S t20,d4 E 860,23 7 1,06 500.22 S 789.~9 E 934.96 7 U.80 541.76 S U53.~0 E 1010.'16 1 1.93 585.21 $ 916.70 E 1087.57 I 0.15 63u.'ll S 980,12 E 116b,52 7 3,80 67o.57 S 1043.b5 E 1243.76 5 57 '1E 5 57 20 E 6 57 30 E S 57 37 E ~ 57 39 E 5 57 39 ~ 5 b7 2b E 5 57 14 E 5 57 2 E 1316,6 1187.9 1400.0 1532.5 1605.0 [077.9 1751.0 1824.5 1898.q 19'14.0 4.21 717.U1 S 11o5.72 F 131. U.28 2,32 753.48 S 116'/.38 E 1389.43 O.b5 7BB.O5 $ 1230.71 E 1461.39 0.1~ ~22,9b S 1294,30 b; 1533.17 0.27 ~SB,~l S 1357.'10 E lbO~.20 0.29 ~93,90 S 1421.20 F lb78.95 1 q2 96b,bl S 164~.20 E 1825.44 0:74 1001.44 S lb14.J1 E 1899.'10 0,1~ !U~7.'19 $ lOBU.12 F 1974,79 $ 57 0 L 5 57 22 E ~ 57 33 E ~ b7 42 ~ $ 57 49 ~ S 57 57 E fi 58 4 E 6 58 11E 5 58 17 ~ FT ,~ EAb!!k F.O PEP1 H q 1 O0. ou 42O0,0O 43U0. OU 4400, Ou 4500. O0 ~700. oO 4800,Ou 490R,ou 5 100. () 0 5200, O0 5400,flu 5500. ou 56U0,00 5700. O0 5800. OU 5900. Ou 6000.00 OlOn. OO O200.OU biO0, Oo 6400, OU 65OO, OU b6OO. oO 6700, O0 ogUO . 7000. O0 7100.0o '12 t) n. 00 ? It)f). O0 '1400. 7500. OU 7hUO, OU -1700. Ou '1 R O 0. r) 7900. Ou TwC. A b A ;:;, h. A ['P ti V7 VFRTICAI, DFI?T!-i 4561 .,,'4 40 t0.49 4099 o }~ 0 47 ~9.4(.-. 4839,59 4910o13 4981.3~ 5~ 52. '13 5123,55 5194,02 C(~,,~PtJTATI rll~ UAl'F:: ~-NOV-~4 J!~'[F'RI')uI-,ATr;I) VA[,oF,5 i-'f'~t~ ~;Vr:lq 10{) DEVIATION A?,I ~ u'l'ti V LR 'f ] C/% i~ I)EP £H 3149,5~t 3216.77 37d2. q,'~ 341~.3q ,4553.gU 362 l, 6 '/ 36 o q, 7 b 3R26.35 3RgR.12 4033 · ! 0 4102.b5 4242.59 ')~12,10 4380.75 VER'I'ICAb SECT ion 2049.58 2124.68 2190,04 2273,42 2346.93 2420.55 2494.15 25D7,64 2641,06 2714.17 2787.]3 2800.29 2932.85 30u5.20 3077.51 3149,50 ~221.1. t 3292.22 3304,03 3436,8U 35O9,43 351~1 365J .89 3'725.64 3796.93 3807, 3 q 3 R, ¢) 2 4008,03 40'18,63 ,414fi.g7 421~.50 'i287.02 4354,77 4421,76 44BO.ill .t557,01 4622,94 4687.69 %752.4~ FEE J' U~' DUGLFG SEVER £ T¥ DEG/loO 0.38 1.39 0,15 2.77 O 28 O,bO O,b2 0.85 0,21 U,-/4 0,30 0,28 0,34 0,46 0,48 0.59 0.98 0,56 0.14 ().(Jq 0.41 0.40 0,~7 1.~7 1,12 0,72 0,98 0,18 0,76 2,15 1.00 0.44 0.55 1,75 i,38 PA'FL t)F SURVEY I 8-NOV-84 K<[,LY BI.ISHTNG FI, EVA'I'It)N: LNGINEER: JOHN6()t,I M k A,5 t.lt~ ED RECTANGUI,AR COURDI,tA'fE5 itiJRI7.. NORTM/Sf)LJTH E ASq'/W r-S'I' I)iSl'. F'E F'[' F E E T F EIE T lu74,22 S 174o.29 E 205u.24 1109,4J 5 1812.08 F 2125,24 1142,56 S lb79.43 E 2199.48 1i75,92 S 1946,08 E 227],76 12l(.),'lb S 2010,85 E 2347,23 1245,95 S 2075.54 F 2420,80 1281,35 $ 2140,10 E 2494,37 1316,52 $ 2204,05 ~i 256'~,82 1351,'17 $ 2269.09 E 2641,22 1386.91 $ ~333.~4 E 2';1~,41 lq21,74 ~; 2397,01 F' 2'181 45 1456,a8 S 2qh1,81 F 2u60[$9 1490,96 S 2525.09 F 2932.93 1525,43 S 2589,33 E 3005,26 1559,99 S 1652.~q E 3077°56 1594.4() S 2110,15 E 3149.54 102B,39 S 2'1'19.21 E 3221,1] 1662.30 S 2U41,75 E ]292,Z4 lbg'/ 34 S 290q,44 K ]t64,04 1733~79 S 2961.q3 E 1770,25 S 3u30.24 E 3509,44 1805,01S 3092.83 E 3581,02 1~42.~9 S t155,11 lU78,97 S 3217.1.t f' 3725.65 1914.95 $ 327H,6~ E 3'196.94 1950,7~ $ 3339,~1 E 3B6'1.81 198o.30 S 3400.40 ~: 393B.04 2021,8~ ~ 3960.72 F: 400e.04 2057,86 $ 3521.44 E 4078.04 2093.02 S 3582,02 F 414u,99 PAGE 2 212~,b3 S 3o42,uq 2162,b4 S 3'101.57 2190.15 $ 3760.46 2229,22 S 2263,27 S 3877,04 229b,~4 5 39]5.91 2329~15 5 3~9],]4 2360.~5 2393.~6 S 4105.55 2429.35 $ 41bl,~O 112,00 F'r DEPARTURE AZIMUTH DEG ~IN 6 58 24 E S 58 31E ,5 58 42 g S 58 51 ii $ 58 50 E ,959 lC: ,559 5 E 859 9 E 559 12 1~ $ 59 lb E :5 59 19 E 6 59 23 E 6 59 29 E 5 59 32 E $ 59 35 E $59 3'1 g :~ 59 40 E $ 59 41E ,5 59 42 E ~ 59 4 N 59 42 E 5 59 42 b 5 59 42 E b 59 42 k ~ 59 42 E H 59 42 E ~ 59 41 E ~ 59 41 E 421~,b2 6 59 41 E 4281.03 5 59 42 E 4354.78 6 59 42 ~ 4421.77 5 b9 43 g 4489.82 5 59 43 E 465¥.01 6 59 44 E 4022,95 5 59 44 E 40fil,7() b 59 45 ~ 4752,4~ 3 59 45 E P^T~: oF' ,SbRvEY: B-NuV-84 I<{:::LLY BUSHING {~:bEVATIuN; ~NG I ml{i-.R; dOH N,.%ON L~,J'I'F;~I)~JI~,~TLjl.) VAI.,Uh:b FC.'-i< k. Vu~N lO0 F'bjEl' UF MI'.A;~URF~L) DFP'I'h D 1~ P T I-~ IlbAr< COURD!I~IA'I'E,5 OOTH EAST/Wb;$ J~ DIS1', F~ET U 2 U 0.0 t) 8 ]90. (} o hi) 0'~' . !4 & 0 R 1. 'l 0 421~,b4 427~.22 4337,93 439b,U6 4452.16 E 4887.17 [: 4~50.57 5 5027,2! ~'; 5U98.82 ~' 5163,40 112,00 FT DEPARTURE AZIMUTH DEG Ctl,qI~uTATJ (]~ t) fi 't~ F,; PAGE F)A'IPE IJF ~URVE~: 8-NOV--8~ KELLY BbSttlNG [<L, EVAI'IUN: 112,00 FT !hTFTtgPUI,AI'tCD VAI,b!~:,% r'{)~t e. iVgf, i l l;OO FEi'-iT 0~' MEASURED HEP1 't'R t~ F: SiJ,~-Sr~A ~EAbliaF'L, VFTaTICHI, V~RTICAb OEVIATi[),,i l)t', 1' j't! U!':. P'P:I i~i~ P'i'~t PEG FFEq' DEG/1U0 FEEl FEEl FEET O.ou u.uO -.112.0u O 0 lOOO.Ob 902.Ub NNO. F)O 16 19 2t)(~O, t)u 1 ~4b,-/q 1733.79 43 I1 30o0,~o Pb!b. 14 2403.74 4b 44 ~OOn,Oo 3 t 9',), o2 3o~3.~2 49 11 bO0(),OO 3~Tt),U() 3'15H, 0() 4] 6 bOoO.O0 4661.~9 44~q,,19 40 36 7000,00 $2ht,,49 blb4.49 43 40 8000,00 t)uO~,'/4 bH97.'14 43 33 N () 0 E 0.0 0 S 5b b9 E 77.17 S SO ,44 E b77.27 s bl 16 E 2o49.58 S 61 3J E 27~7.~3 S 59 b5 E 3509.43 S 60 4 E 421~.50 S 5'1 40 E 4887.15 O,00 2,47 1,ol t.21 0.38 0,74 0,06 0.98 O,b8 o,o0 u,o0 N O.O0 ~. 0,OO N 0 O ~ bl.ZO 5 59.50 ~: 7~,50 $ 49 1'/ E 313,o4 S 4Hb.40 E b7'1.92 S 57 7 E ~ o1S 1105.72 E I31B 28 ~ 57 O ~ 1 122 S 174o,29 E 2050124 8 58 24 E 1,t21.74 S 239'1,ol E 2'187,45 8 59 19 E 1770,26 $ 3030,24 E 3509,44 S 59 42 E 2/2~,~] $ ]~42,09 E 421~,~2 $ 59 41 E -~ ~16b;7~ $ 4219,b4 E 4~87,17 $ 59 41 £ ~vtb,lb $ 44~2,16 E 5163,40 ~ 59 14 E Cf.~.~pUT~TJnN mgA~ 1 11 21 41 .51 6~ '7.t. 102 123 114 14b 157 16,9 181 195 llhF'[) VF:~'.rlC~I, wERI'ICAt., OEYTA']'Jai'd A'ZIP[i'ri-~ 2O9 223 237 252 268 284 299 313 .]42 357 372 387 402 417 447 462 47 o 491 7.O4 91;'.d0 800,Ou 14 17 S 5.5 lb ~: O.~[ 10!2.0(~ QuO.O() 1, bO ~{ 57 2 F 6,2i.) 1112.U(, l()O0,0O 2u 16 S 5~ 1] F 4,10 1212.o() I]U(,,Ou 23 20 S 6() lb ~ 3,62 1312,00 12uO.Ou 2q b2 S 6U 5! ~: 5,64 1q12.OO ]3QO,Ou ~ 17 S 5b 51 E 0,68 1512.U0 14t)O,Ou ~1 ,i5 8 50 57 b 1,95 161.2.O() lhuO.{tu ~b 24 S 5~ 35 E 9.6b I 712,t)0 16l)(),0(.~ 40 14 S 5R ~9 E O,23 2012,~;0 lqO0.00 4b 13 5 5~ q5 E 5.00 2112.90 20uO.O~ 47 2! 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T ...................... ~r .......................... ................ ~ ................. r ............. ~ .......... :"I .............. : ......... ZZi:ii:'i:: ":": ': !..i2i.~.i2:].:!.:~Li..i..i:.....!.....:..::...~.!.......i~.~iZ..i.~.2.:....."!...~i.. ~!': :: :_.i.i..i .... :.:.i.'_.:_..'...: ......... :::::::::::::::::::::::::::::::::: ::::::::::::::::::::: - 1000 -2000 - ] 000 0 l o00 2000 3000 4000 5000 WEST EaST ' Su~gest~orm to be inter,cd in each "ACtive well folder to d~.eck for timoly compliance with our rc~ulations. · '' oPerat6r, ~ell Narn~ ~nd Numker Reports and Materials to be received by: Date Required Date Received Remarks Ccmpletion RepDrt Yes '/~ _~ ~~. · ,, , ~ud. nc~ , IV6. "Pt ~~.. 0.~~ ~re ~ips " ff~ ,~x . Core ~scrip~on ~ ~:'. ~,. · ' ..... 'Registered S~ey Plat ~ ~ Inclina~on S~ey ~ T ,,. ,,., .., . . . Dire~ional ~ey. ~-~--. F/ / / ,. ,. , . , ,, ~ ,, , ~s R~' ~9. Yes ........................................ ..,,,..:~,, '~"' ,,! ~~'~ ....... ~ 7~>, ../' ncho~aO~e, 5 e%ephon e 90'/2'/6 121 November 21, 1984 Mr. C. W. ch~ttert°n m~ss~oner Co~ ~ ~ aska _ ._.~vat~on ctate °!.ql ~. GaS ~ch S~BJEC% ~o~thl Y ~portS De~r ~r. ch~ttert°u: EnclOSed ~re the ~outhlY state Re~ortS ~or the 2~.16 WSP 20-3 21-15 1L-1 2D-2 2~-1~ 2G-l~ 1L-16 20-1 2G-15 1L-15 2G-16 . 2E-16 Sincerely ' ~'ng £ng~ueer ~Itt/05 EnclOsures RECEIVED NOV 2 Alaska Oil & Gas Cons. Commission Anchorag~ · · STATE OF ALASKA O( ALASKA~ _ AND GAS CONSERVATION C , .... ~ISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [~ X Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 84-176 3. Address 8. APINumber P. 0. Box 100360, Anchorage, AK 99510 50- 029-21199 1120' 4. Location of Well at surface FSL, 241' FEL, Sec.4, T11N, R9E, 6. Lease Designation and Serial No. ADL 25645 ALK 2576 5. Elevation in feet (indicate KB, DF, etc.) 112' RKB~ PAD 77' UM (Approx.) 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 2X-15 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool For the Month of. October ,19 84 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 2345 hfs, 10/--15/84. Drld 12-1/4" hole to 3696'. 9-5/8" csg. Drld 8-1/2" hole to 8390'TD as of 10/22/84. Ran logs. csg. Secured well + RR ~ 1345 hfs, 10/25/84. Ran, cmted & tested Ran, cmtd & tstd 7" 13. Casing or liner ru.n and quantities of cement, results of pressure tests 9-5/8", 36#, J-55 BTC csg w/shoe (~ 3674'. Cmtd w/1425 sxs Cold Set III. 7" 26# J-55 BTC csg-w/shoe @ 8362' Cmtd w/55,~ sxs Class 14. Coring resume and brief description N/A 15. Logs run and depth where run DIL/FDC/CNL/GR/SP/SFL f/8374' - 3671' RECEIVED 16. DST data, perforating data, shows of H2S, miscellaneous data N/A NOV 2 6 Alaska 0il & Gas Cons. commission Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ----~'~~/'~'~ _~'"~~ . .' TITLE .... Area Dr, ll,ng Engineer DATE,//'///... _.~~',.~'.. SIGNED NOTE--R~rt~'n t'c/~',~m is required for each calendar month, regardless of the status of operations, and must be ~ed ir~uplicate with the Alaska Oil and Gas Conserv/~,t,~n Commission by the 15th of the succeeding month, unless otherwise directed. Form 10 404 v H I LL/MR35 Submit in duplicat~ Rev. 7-1-80 ARCO Alaska, Inc. Post Office ~"~' 60 Anchorage, A,aska 99510 Telephone 907 277 5637 Date: 11/06/84 Transmittal No: 4816 RETURN TO: ,. ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 /Anchorage, AK 99510 ' oJTransmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. OH FINALS/Gearhart 2X-15 "Raw" Comp. Density/Neutron 2''j 10/22/84 "DIL" II II II II II 511./ II " Comp. Density/Neutron 2''~' " " " " " 5" j " " Dual Induction Laterolog 2'''~ "' II II II II Run 1 3671 - 8374 " 3671 - 8374 " 3671- 8374 " 3671- 8374 " 3671 - 8374 5" J " " 3671 - 8374 /cat Alaska Oil & Gas ' ~ Gons. Co['nmJssion Receipt Acknowledged: B. Currier BPAE Chevron D&M Date: DISTRIBUTION Drilling Mobil NSK Ops. W. Pasher G. Phillips Phillips Oil J. Rathmell State of AK ~.~ Sohio Union Well Files ARCO'Alaska, Inc. Post Offic~( 360 Anchorage; ,-,,aska 99510 Telephone 907 277 5637 Da=e: 11/14/84 Transmittal No: 4849 P~E TUEN TO: ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 Transmitted herewith are the following items. Please acknowledge receipt and return one sigmed copy of this transmittal. OH LIS TAPES/Schlumberger f~69730 2I)-16- 11/08/84 Run 1 ,../~69713 2W-5 .' 10/31/84 " /" ~69639 1L-16, 10/17/84 " ~--~;9678 2D-l' 10/27/84 Run 2 /- ,-,'~9640 2G-15 ' 10/15/84 Run 1 ~' ~6967i 2}I-3. ' 6/04/84 Runs 1,.2 /~39712 ' 2E-16 ' 10/30/84 Run 1 /~39667 2X-15 ' 10/23/84 " 3266.5 - 7855.5 3729 - 8112 4000 - 7837.5 2638 - 6787 2717.5 - 697O 76.5 - 6803 3391 -- 7693.5 3638 - 8396.5 Receipt Acknowledged: Date: DISTRIBUTION B. Currier Drilling W. ,asher BPAE Geology G. Phillips Sohio Chevron Mobil Phillips Oil Union D & M NSK Ops. J. Rathmell Well Files MEMORAi OUM State of Alaska ALASKA 0IL AI~D GAS. CONSERVATION C0~ISSION To~ cC~a~erton THRU: Lonnie C. Smith~ Co~mm~issioner DATE: October 23, 1984 F,LENO: D.41.42 TELEPHONE NO: FROM: Doug m~os ~ SUBJECT: Petroleum Inspector Witness BOPE Test at ARCO' s Kup 2X-15 Well, Sec. 4, TllN,R9E,Ut.~, Permit No. 84-176, Nabors Rig No. 26E. Friday October 19, 1984: After witnessing the BOP test on Parker Rig No~' 19~', 'i 'trag~l~d-to Nabors Rig 26E to witness the BOPE test there. The test co~enced at 2:30 pm and was concluded at 4:00 pm. There were no failures and I filled out an AOGCC BOPE test report which is attached. In summary, I witnessed the successful BOP test at ARCO's Kup 2X-15 well. Attachment 02-00IA(Rev. 10/79) O&G #4 ., ' · STATE OF DLLASKA' ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspect'ion Report !nspector .~.~..~,~9 ~O_f .... we!! .../~-~. ..... ~,,,~'-/~ O~rator ~~ Representative ~~ ~ ~~~' Well ~ ~ ~ ~/~ Pe~it Location: Sec ~ T//~ R ~ M ~.~, ~ Casing Set ~ 3& 7~ ; ft. Drilling Contractor ~~m~ Rig ~ .~ Representativ~ L' ~/~D~ .. . Location, General Well, Sign General Housekeeping Reserve pit Rig BOPE Stack Annular' Preventer ' ~ Pipe Rams '~ Blind Rams Choke Line Valves~' H.C.R. Valve ~;: Kill Line Valves Check'Valve / Test Pressure ,I o o ACCUMULATOR SYSTEM Full Charge Pressure '~.~OOC~ psig Pressure After Closure ~ ~ ,, psig 200 psig Above Precharge Attained: miL'A{ sec, Full Charge Pressure Attained: ~ miL %~ sec, N2 /,~0~,' ~0i ~.,/o0/ ~_-1.-00 .. ,psig ~ ~_ Controls: Master O~ Remote 0~_ Blinds switch cover~3 , , , Kelly and Floor Safety Valves Upper Kelly ~ ~ Test Pressure Lower Kelly ~% Ball Type ~/ I Inside BOP/~ Choke Manifold .. No. Valves No. flanges ...... Adjustable Chokes Hydrauically operated choke Test Pressure Test Pressure _Test Pressure ~ Test Pressure 13... ,Test Results: Failures /~/o/~: Repair or Replacement of failed equipment, to be made within Inspector/Commission office notified. . . Remarks: Test Time / hrs ..... ~d) _days and ~11 Distribution orig. - AO&GCC' cc - Operator - Supervisor Inspector ARCO Alaska, I~ Post OffiL_ Jox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 October 22, 1984 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Revised Conductor As-Built Location Plat - Wel 1 s 9-16 Dear Elaine, Enclosed is a revised as-built location plat for the wells. If you have any questions, please call me at Sincerely, Gruber Associate Engineer JG/tw GRU2/L25 Enclosure 2X Pad subject 263 -4944. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany FROM' 10/18/'8~ O1:07 PHASE ~ WELLS 9 AS-BUILT Thru I IZ ,~ o 15 I II o ~ IO o ~ I§ 9o oi8 4 c:rr T. F~I~ tO iTING WELLS I Thru 8 LOCATED IN PROTRACTED SECTION 4 TOWNSHIP 11 N, RANGE 9 E, UMIAT MER. NO SCALE NOTE: BASIS OF BI[ARING tS MONUMENTATION ?X-NOR'I'H AND P_X MIDDLE PER LHD ~ ASSOCIATES, . ~ i.-------- P . DRILL SITE ~.X CONDUCTORS AS-BUILT LOCATIONS WELL 14 WELL 15 WELL 16 ReV.//~ WELL 9 y=5,971,052.927 Lot. 70o I9'55.4995~ X: 518,529.196 Long. O,B. EleY. 72.1 Pod Elev. 76.~ I,O50 FSL 599 FEL WELL IO y=5,gTI,II2.911 L~t. T0~1~'56.089~ X, 518,529,180 Loag. 149~50'58,9146' O.G. ~v. 72.0 Pod E lev, 76.2 I~ll FSL 598'FEL WELL I I y =5~971,11Z.955 Lat. 70~ t9'56.6199' X = 51 8,529.084 Long. 149°50'58,9131' O.G. Etev. 71.9 Pod Elev. 76.0 I, I 70' FSL 598' FEL '~1: WELL I~ y,5,~7 t ,232,789 Lot. 700 19'57.268~";~ X: 518,5Z9 168 'Long. 0.~. Elev. 71.9 Pad Etev 16.3 ..~ " I, ~30' FSL 598' FEL .;~1 WELL 13 ~,5,911,253.114 Lat. 0,~, Elev. 7~.0 Pod Elev. 76.8 I,~9' FSL 2~8' FEL X: 518 88~.1~1 Long D.C. Liar, 7~.1 Pod Elev. ~7.O I~1 69' FSL ~ , ;.:~ y:5,971,11~,t38 Lot 70 195G~8~7 O.G. Elqv. 7~.~ Pod ~lev, 76,9 ~.'~ I,IO9' FSL ~8 FEL, X= 518,889.140 LOn~. 149050'48,4076~ O,G. Elev. 7~.4 Pad Elev. 7 7.0 .:;~ I,O49'FSL 259 FEL ~:,~ ~-.~ ~ ~ . '.~? ~ ~F ~'~%~ '~: ~ ~.,,,"",,, ~' .,.. ........... . f ;~ '.. ~ ,..'~ I HEREBY CERTIFY THAT I ANt PROPERLY REGISTERED LICENSED TO PRACTICE LAND SURVEYING IN THE STATE O~ ALASKA ~ THAT THIS PLAT REPRESENTS A SURVEY MAD£ UNDER MY DIRECT SUPERVISION 15 THAT ALL DETAILS ARE CORRECT AS O,,F SEP, TEMBER ~l,,19B~,. ,' , , ',~ '- ~:~- ARCO Alaska, Inc. I "DRIL~' SITE 2X ::~ CONDUCTOR AS-BUILT LOCATIONS ' Droughtsm~n' I v. .' ' ARCO Alaska, ~' Post OffiCe= Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 3, 1984 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plat - 2X Pad Wel 1 s 9-16 Dear Elaine' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, . Gruber Associate Engineer JG/tw GRU1/L75 Enclosure If ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany DRILL SITE 2_..X A' -BUILT CONDUCTORS LOCATIONS PHASE Tr WELLS AS-BUILT 9 Thru I . I! lO ol4 ol5 Ol6 · · · · p~/HA 9 IO SE 1;- EXISTING WELLS I Thru 8 LOCATED IN PROTRACTED SECTION 4 TOWNSHIP 11 N, RANGE 9 E, UMIAT MER. NO SCALE NOTE: BASIS OF BEARING IS MONUMENTATION ZX-NORTH AND ZX MIDDLE PER LHD 8~ ASSOCIATES. WELL 9 WELL I O Y: 5,97 i,052.927 Lot. 7'0° 19'55.499' X: 518,529.196 Long. 149050'58.919' I,O50' FSL 599' FEL Y =5,971,112.911 Lot. 70° 19"56.089' X: 518,529.180 Long. 149°50'58.915' I,IIO' FSL 598' FEL WELL II WELL WELL Y :5~971 ,172.955 Lot. 70° 19'56.680" X: 51 8,529.084 Long. 149 ° 50'58.$15" 1,170' FSL 598' FEL Y:5~97 I ,232.789 Lat. 70° 19'57.268' X: 51 8,529.168 Long. 149°50'58.906" 2,250' FSL 598' FEL Y : 5,971,233. 114 Lot. 70° i 9'57.265" X: 518,889. 151 Long. 149050' 48.394' 1,229' FSL 238' FEL WELL 14 WELL 15 WELL 16 Y: 5,971 , 175.080 Lot. 70°19'56.67,2- X: 518,889.157 Long. 149°50'48.399- I~ I 69' FSL 238' FEL Y :5,971,11 3.138 Lat. 70 ° 19'56.085" X: 51 8,889.054 Long. 149050'48.406" !,109' FSL 2:58' FEL Y: 5~971 ,055.154 Let. 70 °19'55.493' X: 518,889.140 Long. 149°50'48.407" I,O49' FSL 239' FEL $ I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED L!CEINS.ED TO PRACTICE LAND SURVEYING- IN THE STATE OF ~THlS SURV ',. ALASKA E~ THAT THIS PLAT REPRESENTS A SURVEY MADE UNDER MY DIRECT SUPERVISION I~ THAT ALL DETAILS ARE CORRECT AS OF SEPTEMBER 21, 1984. . . ,o ,, I ARCO Alaska, Inc. ~. ~ North Slope Drilling / %\"71 t I DRILLSI¥-E 2X I CONDUCTOR. AS BUILT :. ION J Droughtsman: HZ D'.g. no.: NSK 9.05.224d 2 ~_ _ I"'"",'"'""' .... '"' ..... SC~L~.-~ U-:~ ,~L~ _ ..., -. - !September 21, 1984 Mr. J. B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 2X-15 ARCO Alaska, Inc. Permit No. 84-176 Sur. Loc. I!20'FSL, 241'FEL, Sec. 4, TllN, R9E, UM. Btmhole Loc. 1480'FNL, 1044'FEL, Sec. 10, TllN, R9E, UM. Dear Mr. Kewin: Enclosed is the 8.pproved application for permit to drill the above referenced well. If coring' is conducted, a'one cubic inch chip from each :foot of recovered, core is required. Samples of' well cuttings' and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If. available, a tape containing the digitized log information shall, be. submitted on all logs~.':or copying except experimental logs, velocity surveys. and di'pmeter surveys, Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations im these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. . Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention .. Mr.. ef~.rey B. ~.ewln Kuparx~k River Unit 2X-15 -2- September 21, 1984 equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled, l,~ere a diverter system is required, please also notify this =m' 24 hours prior to commencing equipment installation so that the Commission may witness testiD before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Ver% truly Mours, ~..__~ , ~ ......... % ".i.., { . :.:,,". '..,'. Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF T}!E COM~M~ISSION be Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o enc!. ARCO Alaska, Inc. i~~ Post Office .. 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 31, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2X-15 Dear Mr. Chatterton: Enclosed are: o An application for Permit to Drill Kuparuk 2X-15, a $100 application fee o Diagrams showing the proposed horizontal projections' of the wellbore o A proximity plat ° A diagram and description of the surface hole system , ° A diagram and description of the BOP equipment Since we estimate spudding this well on October 16, earliest approval will be appreciated. If you have any questions, please call me at 263-4970. S iw~B .~n~~re 1 Y ' . ~re~' D~i~ii'ng Engineer JBK/JG/tw GRU1/L22 Attachments along with ARCO Alaska, Inc. is a Subsidiary o! AtlanticRichfieldCompany and vertical d i ve rte r 1984, your Alaska 0il &.Gas Cons. Carnrnissio. ~nchorage STATE OF ALASKA ALASI[., OIL AND GAS CONSERVATIONt, OMMISSION PERMIT TO DRILL 20 AAC 25.OO5 la. Type of work. DRII'L [~X REDRILL [] DEEPEN [] EXPLORATORY [] lb. Type of well DEVELOPMENT OIL i~X DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC I] SINGLE ZONE MU LT,PLE ZONE I~.?~ ~..~ .:,.~: v ":.'t 2. Name of operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 1120' FSL, 241' FEL, Sec. 4, T11N, R9E, UM At top of proposed producing interval 1232' FNL, 1472' FEL, See.lO, TllN, RgE, UM At total depth 1480' FNL, 1044' FEL, Sec.lO, TllN, RgE, UM 9. Unit or lease name ".' --, Kuparuk River 10. Well number {:~. 2X-15 "?3 11. Field and pool ~.~_ .,'.~.~ Kuparuk River Field ~¢ Kuparuk River Oil Pool 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. RKB 112', PAD 77' I ADL 25645 ALK 2576 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500~000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 30 mi. NW of Deadhorse miles 1044' ~ TD feet 2X-16well 60' ~ surface feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 8431' MD, 6326' TVD feet 2560 10/16/84 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 500 feet. MAXIMUM HOLE ANGLE 46 ol (see 20 AAC 25.035 (c) (2) 2774 psig@ 80°F Surface ~185 psig@ 6187 ft.-TD FTVD) 21 Proposed Casing, Liner and Cementing Program SETTING DEPTH QUANTITY OF CEMENT SIZE Hole Casing 16" 9-5/8" 24" 12-1/4" 8-1/2" Weight 62.5# 36. O# 7" 26. O# 22. Describe proposed program: CASING AND LINER Grade CouplingI Length H- O/ J-55 HFIERW BTC/ 3591' J-55 HFIERW.TC/~,~, - MD TOP TVD 80' 35' I 35' 35' 35' 1 34' I 34' MD BOTTOM TVD 115' I 11.5' 3626' I 2982' 8431' I 6326' (include stage data) ± 200 cf 850 sx Cold Set III & 600 sx Cold Set II 300 sx Class G ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 8431'MD (6326' TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Expected maximum surface pressure is 2774 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 2000 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli thrOugh the permafrost interval. 2X-15 will be 60' away from 2X-16 at the surface. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any (see attached sheet) 23. I hereby certify that the foregoing is true and correct to the best of my knowledge SIGNED TITLE Area Drilling Engineer Th e space ~v'~O~,~sion uS~' CONDITIONS OF APPROVAL Samples required Mud Icg required []YES E~NO I []YES [~O Permit number / Approval date APPROVED BY " k. -/. Form 10~01 --~RU1/P~12 [ / Rev. 7-1-80 DATE Directional Survey required I APl number ~ES F]NO I 5o-029-2119 9 SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER by order of the Commission DATE .q~pt~mbe~' ?1, 1984 Submit in triplicate Permit to Drill 2X-15 interruptions in the disposal process. The well will be completed by the workover rig using 3-1/2", 9.2#/ft, J-55, 8rd tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. ~'"',. E C E iV E D ,~,,i~.~si<a Oil & Gas Cons. Commission Anchorage ' t ' · . ARCO i ALASKA. I~NQ ..~... t · ~ · " PAD 2X,;I~ELL NO".lS'iPROPOSED.'. ..... KUPARUK-Fi. EL-D.!--NORTH-SUOPE,~ALAS'KA--I ' - { .... EASTlflAN WHII~STOCKL] INC,~ ' . ..... i !'"~V ' t ..... . ~ , AVER · KDP.'. _ IYD~-5OO._TMD.=$OO-DEP..=O .... ~ . . , BUtLD'3 DEO : . PER-'COO o . . -';33--{ ' ' ' ' .. 3e.; EO0 ' TVD'-{18?I' TI'ID-2030 DE!::"-$81' '' 4.51TOPiUONU} SNDS TVD~1892' THD=2059 DEP':602 .... t" ' '" t .... 82'~Tr'ID= 305'1-~EP='1'31 4' m 2 1'VD.~2932. T,D=~$$4.0EP=~ 6?5 K-5 TVD=4752 TMD-6 ,- R S~DS 60O0 - 69 'DEP-355,3 !742 DEP=46g3 . i ..Alaska Oil & Gas Caaa. Commission ~ ] } Anchorage hooo 'ooo'i :~ooo . .~ooo sooo . ,sooo -..VER:T-~.C*~ eC~'~ !, . . . , . 'TOP LO~R SNDS iTVD-6067 T~MD=8058 DEP-4910",~ BASE KUP SNDS .TVD'-'6187'i T~D-.8231 DEP=5034 SLOPE. LOCA~ION~ .*.! IDO0 3000 .......... ~, . · SEC ;ET LO~ATION ' FNL: 1320 IO. II IN. fl · . ~ FEL ~E 8' !(TO O00FEE ARGEI' TVD--60! Tt'ID-?98 DEP-485 ~OUrH 2 E;^Sr i 1 I"1 I:,N - E ARGET-) (LOGI~I NG 'PT , o. -',~nn- 'i ~ i '".'" i,. ........... A [ .~S A, ./NC .... ..... ~,~ , · . i ......... PA~,~j ~ ............... ~ · " t~ ~[I .~ ~D~, -~' . 1~ : _ ~ . _ ~ ~ ~ ............................. ..... ' ............., · ' * ........... ~ ....... r ........ ~ . ~ , ~ ~ ~ ..... i : . I i , J ~ I I ; ; . .... !snn_ : :. ~ ..... , .., .... ~~ . :_ ~_~ .... ',' ',' '~' ~ ~'~r~.' i ~~ ', ..... ," ........... e .................... ~ .... · .... ~ ...... I " - .......... ' t ~ ~' .... -- . ~ ~ , . , . ~ . : _ : ~ _ ,. ' : ~ ~~ t~1 ,-~ . ' ~ ~ .......... : t ..... ' ' ....~~ ' ~ '~ : ~ :, - ,,., . : :: ,' .... ... . ::', ::' : ::. '' J .. : ' '~. , .. ~ , ,-'--~ - .--~,~;',":-:: -~:: ~'z -'-' ...... ' .............................. ' ..... ~,,,~c ~ l~n~ ~ ....... '.' ~ , : . ::. I .. .. ~ ~ '" Alask~ Oil &' 6as Con.;. Ceal~iSSiOn ann,. ,'~ , , , , j ...... .. ~ ., ~~.. _..~._ : :::'::_:__ '"::: ':':: ::'' : I '_.~ :, . _ '~ I .~ : _ _.~.~..:_.7. _::.'~: ': . r ............. ~~"~' ....... ::. :-.:..- .. :. , :..:.: ,'2==..::: . ,...: .:,:. ::.::::t,:.:,:.:.: :,,,. :.:..::,:. :.:,: ,,:::.:~:_:.::::.:. ~~::.:.:...~ ..... :~. ............... , .... ~--~~ ...... ......... :._~ ................. ,,,= ..... ........ ~D ..... , , . ,' ~ ..... i~.. .~~i ' Surface Diver-.er System 16"-2000 psi ~ankco star-.in_: head. lankco qu~ck connect assy. 16" X 20" 2000 psi double s~zuooed accepter. 20" 2000 psi Orilling spool ./lO" siOe ouSless. lO" b~il velves~ hyor~ulic~lly ec:u~sed~ ./10" ines to reserve piS. Valves s~ open eusom~sic~ily upon closure of annular preventer. 20" 2000 psi annular prevenser. 20" bell nipple. t~,ainlzenance & Opera,ion Upon initial ins'~allasion close annular prevenser and verify ~hat bail valves have openeo properly. 2. Close annular preventer and blow air :hrouc. h divertmr lines every 12 hours. Close ~nnular proven:er in the event :hat 9e~ or fluid overrioe and close b~ll v~lvm to upwind divertmr line. Do not shut in ~ell under ~nv circumstances. m 16" Conductor PREYE,N~ 9 PIPK ,> ~' ~ ' PSi RSRR~ .~-./~ 5ODD BOP STACK II" - 3000 ~si ~ !~-5/~' - 5000 ~sl sDzcer s~Dcl !~-5/~" - 5DOD psi ~ I~-~/~' - SODD ~si oriiiinc !~-~/~' - ~OOD psi pipe rmms 6. 1~-5/~" - SOOO psi !~-5/~' - 5000 ps~' p~pe SPOOL "' :-" -' !PE ,~. CHECK AND FILL ACCUMULATOR RESEA¥OiA TD LEVEL Wi~ HYDEAUL]C PLUiD. 2, AJSURE THAT ACCUMULATOR PRESSURE IS 30DO !SOD PS] DDWNSTEEJ~wA OF TldE REGULATOR. 3. OBSERVE T!EE, THEN CLOSE ALL'UNiTS S]H~LTANEDUSL¥ A~D RECORD THE TIME AND PRESSURE RE,wJ~)NG AFTE~ ;.LL UNTM ,~. ARE CLOSED WiTH CHARGING PRIMP OFF. ~. RECORD O~ NADC REPORT. THE ACCEPTABLE LOWER IS 45 SECONDS CLOSING TIME AND i2OO PS] PRESSURE. '~ 2 BOP STACX TE.~T .... !. FILL BOP STACX AND MANIFOLD WITH ARCTIC ~)!ESEL. 2. CHECK THAT ALL HOLD DOWN SC~E~WS ARE FULLY ~. PRED~E~]NE DEPTH T~A7 TEST PLUG WILL AND S~T IN WELLHE~. RU~ ih' LDCX DOWN SC~FW5 4.T~ST ALL CDMPOKEh~S TO 25D PSi ~g HOLD FOR M ] NUTE~. 5. INCREASE PRESSURE TO iBOO PS] ~D HOL~ FOR MINUTE~. BLEED TO ZERO 6. DPEN ANNULAR PEEYENTE~ AND CLOSE TOP SET OF 7, INCENSE ~EESSURE TO 3DOD PS; AND HOLD FOR V~S. TO ZE~O PSI TO TEST VALVES. T~7 EE~N]NG UNTESTED ~NIFOL~,VALVES', IF A~Y, W)TN 3ODD PSI OPSTRE~ OF VALVE AND ZE~O DOth'STREW,.. )LE[D SYST~ TD ZEnO ~, OPEN TOP S~ OF PiPE ~J AND CLOSE ~O~O~ S~ DF ' ~ PIPE ~.~,~t~Y lO. 1NCR~E PRESSURE TO 3DOD PSi AND HOLD FOR 1D ~.~Jmq'~ ~~. OPEN BO~D~, S~ OF PIPE ~.S. BACK OFF ~., ~'~'~ JOINT AND PUL[ OUT OF HOLE. CLOSE BL]ND R~S ~ %Ow TEST TO 3DOg PSI FOR ID MINUTES. BL~ED TO Z~RD PS1. i2. OPEN BL]ND ~ AND RECOVER TEST PLUG. ~KE SURE ~N]FOLD AND L]N.-r~ ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE S~ iN DRiLLiNG POS~T~ON. 13. TE~T STANDPIPE VALVES TO 3DOD PS~. ~4. TEST K~LLY COC~ AND INS!~E BOP 70 $DOG PS] w~TF, NOSEY PUMP. 15.RECORD T~S7 ]NFDRMAT)DN ON BLDWO~-,...~-,-~~r~'~r' Tr~ FORff, S~GN AND SEND TD DRiLL~N6 SUPERVISOR. ]6. PERFD~ C~PL~[ BOPE TEST ONCE A WEEK AND FUNC- TIONALLY DPE~TE SDPE DAILY. CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE (1) Fee (2) Loc (~//--'- ~ d? ~/2thru 8) (3) Admin /~thru (10 ~nd 11) (12 thru 20) ' e 10. 11. 1. Is the permit fee attached ......................................... 2. IS well to be.located in a defined pool ................ {ine ' 3. Is well located proper distance from property ... -. 4. Is well located proper distance from other wells .................. 5. Is sufficient undedicated acreage available in this pool 6. Is well to be deviated and is well bore plat included ............... 7. Is operator the only affected party ................. ' ' 8. Can permit be approved before ten-day wait,. . ' Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... 12. 13. 14. 15. 16. 17. 18. 19. 20. NO Is conductor string provided ............................. Is enough cement used to circulate on c2~c;~; a~'surface . ~.. Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ...................... Will all casing give adequate safety in collapse, tension iud burst. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment proCedure included on 10-403 ............ adeqUate well bore separatio proPosed ~ ' ' Is n ......................... REMARKS (5) OPE (21 thru 24) 21. 22. 23. 24. Is a diverter system required ....................................... Are necessary diagrams of diverter and BOP equipment attached ....... Does BOPE have sufficient pressure rating - Test to /~D'z~z~ psig .. Does the choke manifold comply w/API RP-53 (Feb.78) .................. (6) Add: 25. Additional requirements ............................................. ~ · Additional Remarks 0 '" i Geology: Engineering: HWK .n. ~ LCS' ~BEw/ rev: 12/08/83 6. CKLT ' ' INITIAL GEO. ,UNIT' ON/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologicallY organize this category of information. RECEIVED NOV .[ 6 ]~ 0il & Gas Cons. Commission Anchora.~ u t-; Z T TYm~ 0 i-5 002 03.'4 O0~ ~ '~ _: O65 05? ':' '" ":-6 :2 4 7 7:. 60 3.:_PT :, ;.;: L b' 3 C .St: ~ ( .S C. T .'--. 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