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Home My WebLink About184-1531. 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: Bradenhead Repair 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 7,923' feet N/A feet true vertical 6,286' feet N/A feet Effective Depth measured feet 7,331' / 7,543' feet true vertical feet 5,853' / 6,011' feet Perforation depth Measured depth 7,446' - 7,560'feet True Vertical depth 5,942' - 6,023'feet Tubing (size, grade, measured and true vertical depth) 3 1/2" J-55 7,558' 6,021' Packers and SSSV (type, measured and true vertical depth) SSSV: 1,949' MD 1,895' TVD Packer: BAKER FHL 7,331' MD 5,853' TVD Packer: BAKER FB-1 7,542' MD 6,011' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 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: Contact Email: Authorized Title: Contact Phone: measured TVD 3,134' Burst Collapse Production 7,877' Casing 6,276'7,907' 3,630' Plugs Junk measured N/A N/A Length 82' 3,595' 117'Conductor Surface 16" 9 5/8" Size 117' 7" N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025653 / ADL0025658 KUPARUK RIVER / KUPARUK RIVER OIL ConocoPhillips Alaska, Inc. KUPARUK RIV UNIT 2D-03 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 184-153 5002921178-0000P.O. Box 100360, Anchorage, AK 99510 3. Address: 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Gas-Mcf MD measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing PressureWater-BblOil-Bbl BAKER FVL LOCKED OUT 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. Brennen Green & Roger Mouser N1927@conocophillips.com 907-659-7506Well Integrity Field Supervisor p k ft t Fra O s 184 6. A G L PG , r Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Kayla Junke at 9:17 am, Apr 27, 2023 Digitally signed by Brennen Green DN: C=US, O=ConocoPhillips, CN=Brennen Green, E= n1927@conocophillips.com Reason: I am the author of this document Location: Date: 2023.04.27 08:30:10-08'00' Foxit PDF Editor Version: 12.0.1 Brennen Green P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 27, 2023 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski, Please find the enclosed 10-404 from ConocoPhillips Alaska, Inc. for the Bradenhead repair on KRU 2D-03 (PTD 184-153). If you have any questions, please feel free to contact me or my alternate, Roger Mouser, at 659- 7506 Sincerely, Well Integrity Field Supervisor N1927@conocophillips.com ConocoPhillips Alaska, Inc. Digitally signed by Brennen Green DN: C=US, O=ConocoPhillips, CN=Brennen Green, E=n1927 @conocophillips.com Reason: I am the author of this document Location: Date: 2023.04.27 08:29:32-08'00' Foxit PDF Editor Version: 12.0.1 Brennen Green Date Event Summary Executive Summary Repair braidenhead by seal welding leak area. 04/11/23 (AC EVAL) TIFL (PASS), OA DDT (IN PROGRESS) 04/19/23 (BH REPAIR) OA DDT (PASS) DE-GAS THE IA (COMPLETE) 04/21/23 (BH REPAIR) PURGE OA WITH N2 (COMPLETE) RIG UP INDUCTION HEAT (COMPLETE) 4/22/2023 (BH REPAIR) AES WELDED THE BRADEN HEAD (COMPLETE) REMOVED THE INDUCTION HEATING UNIT (COMPLETE) 4/23/2023 (BH REPAIR) BH WELD NDE (PASSED) PRESSURED OA TO 800 PSI WITH GAS & SNOOPED BRAIDEN HEAD WITH NO SIGNS OF LEAKS Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (Est. 63' of Rathole) 7,679.0 2D-03 6/23/2022 zembaej Last Rev Reason Annotation Wellbore End Date Last Mod By REV REASON: Pulled rock screen, added HEW and CDR window 2D-03 9/12/2022 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: L1 LINER NOT SET ON CDR3. OPEN HOLE. 8/4/2022 rmoore22 Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 35.0 Set Depth (ft 117.0 Set Depth 117.0 Wt/Len (lb/ft) 62.50 Grade H-40 Top Connection WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 34.9 Set Depth (ft 3,630.0 Set Depth 3,134.4 Wt/Len (lb/ft) 36.00 Grade J-55 Top Connection BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 30.1 Set Depth (ft 7,907.1 Set Depth 6,275.9 Wt/Len (lb/ft) 26.00 Grade J-55 Top Connection BTC Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 30.0 Set Depth 6,021.9 String Ma 3 1/2 Tubing Description TUBING Set Depth (ftKB) 7,558.2 Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE8RD 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) 30.0 30.0 0.04 HANGER 8.000 FMC GEN III TUBING HANGER 3.500 1,948.8 1,894.5 30.86 SAFETY VLV 5.937 BAKER FVL SAFETY VALVE (LOCKED OUT 3/5/90) PULLED FXE on 3/18/95 BAKER FVL 2.810 2,028.6 1,962.3 32.37 GAS LIFT 5.312 MMH FMHO 2.867 4,040.7 3,432.7 43.14 GAS LIFT 5.312 MMH FMHO 2.867 5,534.9 4,528.3 42.26 GAS LIFT 5.312 MMH FMHO 2.867 6,634.4 5,332.8 43.98 GAS LIFT 5.312 MMH FMHO 2.867 7,276.0 5,811.4 41.01 GAS LIFT 5.312 MMH FMHO 2.867 7,317.3 5,842.5 41.21 PBR 5.000 BAKER PBR BAKER 3.000 7,331.0 5,852.8 41.26 PACKER 5.968 BAKER FHL PACKER BAKER FHL 2.937 7,367.3 5,880.1 41.39 GAS LIFT 5.312 MMH/3.5x1/1/DPHFCV/BEK/ Comment: STA 6 MMH FMHO 2.867 7,435.3 5,931.0 41.82 GAS LIFT 5.312 MMH/3.5x1/1/DPHFCV/BEK/ Comment: STA 7 MMH FMHO 2.867 7,441.9 5,935.8 41.88 BLAST JOINT 4.500 BLAST JOINT (1) 2.992 7,473.0 5,959.0 42.16 BLAST RINGS 4.500 BLAST RINGS (2) 2.992 7,531.6 6,002.3 42.57 GAS LIFT 5.312 MMH FMHO 2.867 7,542.0 6,010.0 42.63 LOCATOR 4.500 BAKER LOCATOR BAKER 3.000 7,542.8 6,010.5 42.64 PACKER 5.875 BAKER FB-1 PACKER BAKER 4.000 7,545.3 6,012.4 42.65 SBE 5.000 BAKER SEAL BORE EXTENSION BAKER 4.000 7,554.2 6,018.9 42.70 NIPPLE 4.540 CAMCO D NIPPLE NO GO (MILLED OUT TO 2.80" ON 3/11/22) CAMCO D 2.800 7,557.7 6,021.5 42.72 WLEG 4.570 WIRELINE RE-ENTRY GUIDE, ELMD TTL@ 7537' during Otis FLUID ID LOG on 01/20/95 BAKER 2.992 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Make Model SN ID (in) 7,583.6 6,040.5 42.86 LEAK - CASING Exit window milled by CDR3 on 07/23/22. Window was milled from 7583.6 to 7586.5 at the exit. Window is for the unlined lateral that was aborted due to hole issues at the window while drilling. 0.000 7,584.2 6,040.9 42.86 WHIPSTOCK NS High Expansion Wedge (HEW) Northern Solutions 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) 2,028.6 1,962.3 32.37 1 GAS LIFT GLV BK 1 1,341.0 3/8/2022 0.156 4,040.7 3,432.7 43.14 2 GAS LIFT GLV BK 1 1,319.0 3/8/2022 0.156 5,534.9 4,528.3 42.26 3 GAS LIFT GLV BK 1 1,339.0 3/8/2022 0.188 6,634.4 5,332.8 43.98 4 GAS LIFT GLV BK 1 1,322.0 3/7/2022 0.188 7,276.0 5,811.4 41.01 5 GAS LIFT OV BK 1 0.0 3/7/2022 0.188 7,367.3 5,880.1 41.39 6 PROD DMY BK 1 0.0 9/19/2016 0.000 7,435.3 5,931.0 41.82 7 PROD DMY BK 1 0.0 9/19/2016 0.000 7,531.6 6,002.3 42.57 8 PROD DMY BK 1 0.0 9/19/2016 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,446.0 7,450.0 5,938.9 5,941.9 C-3, 2D-03 11/24/1984 12.0 IPERF 120° Ph; 5" DA Csg Guns 7,453.0 7,455.0 5,944.1 5,945.6 C-2, 2D-03 11/24/1984 12.0 IPERF 120° Ph; 5" DA Csg Guns 7,459.0 7,461.0 5,948.6 5,950.1 C-2, 2D-03 11/24/1984 12.0 IPERF 120° Ph; 5" DA Csg Guns 7,465.0 7,470.0 5,953.1 5,956.8 C-2, 2D-03 11/24/1984 12.0 IPERF 120° Phasing; 7,478.0 7,481.0 5,962.7 5,964.9 C-1, UNIT B, 2D- 03 11/24/1984 12.0 IPERF 120° Ph; 5" DA Csg Guns 7,492.0 7,495.0 5,973.1 5,975.3 UNIT B, 2D-03 11/24/1984 12.0 IPERF 120° Ph; 5" DA Csg Guns 7,501.0 7,504.0 5,979.7 5,981.9 UNIT B, 2D-03 11/24/1984 12.0 IPERF 120° Ph; 5" DA Csg Guns 7,559.0 7,560.0 6,022.4 6,023.2 A-5, 2D-03 12/17/1984 1.0 APERF SINGLE SHOT 2D-03, 9/12/2022 6:03:18 PM Vertical schematic (actual) PRODUCTION; 30.1-7,907.1 FLOAT SHOE; 7,905.3-7,907.1 FLOAT COLLAR; 7,824.6- 7,826.3 APERF; 7,615.0-7,616.0 APERF; 7,613.0-7,614.0 APERF; 7,611.0-7,612.0 APERF; 7,581.0-7,625.0 WHIPSTOCK; 7,584.2 LEAK - CASING; 7,583.6 APERF; 7,561.0-7,562.0 APERF; 7,559.0-7,560.0 WLEG; 7,557.7 NIPPLE; 7,554.2 SBE; 7,545.3 PACKER; 7,542.8 LOCATOR; 7,542.0 GAS LIFT; 7,531.6 IPERF; 7,501.0-7,504.0 IPERF; 7,492.0-7,495.0 IPERF; 7,478.0-7,481.0 IPERF; 7,465.0-7,470.0 IPERF; 7,459.0-7,461.0 IPERF; 7,453.0-7,455.0 IPERF; 7,446.0-7,450.0 GAS LIFT; 7,435.3 GAS LIFT; 7,367.3 PACKER; 7,331.0 PBR; 7,317.3 GAS LIFT; 7,276.0 GAS LIFT; 6,634.4 GAS LIFT; 5,534.9 GAS LIFT; 4,040.7 SURFACE; 34.9-3,630.0 FLOAT SHOE; 3,628.1-3,630.0 FLOAT COLLAR; 3,547.6- 3,549.2 GAS LIFT; 2,028.5 SAFETY VLV; 1,948.8 CONDUCTOR; 35.0-117.0 HANGER; 34.9-39.4 HANGER; 30.0 KUP PROD KB-Grd (ft) 40.91 RR Date 10/9/1984 Other Elev 2D-03 ... TD Act Btm (ftKB) 7,923.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292117800 Wellbore Status PROD Max Angle & MD Incl (°) 45.52 MD (ftKB) 2,700.00 WELLNAME WELLBORE2D-03 Annotation Last WO: End DateH2S (ppm) 100 Date 11/20/2015 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 7,561.0 7,562.0 6,023.9 6,024.6 A-5, 2D-03 12/17/1984 1.0 APERF SINGLE SHOT 7,581.0 7,625.0 6,038.6 6,070.8 A-4, 2D-03 7/6/1990 4.0 APERF 180° Ph; 2.5" Titan II HC 7,611.0 7,612.0 6,060.5 6,061.3 A-4, 2D-03 12/17/1984 1.0 APERF SINGLE SHOT 7,613.0 7,614.0 6,062.0 6,062.7 A-4, 2D-03 12/17/1984 1.0 APERF SINGLE SHOT 7,615.0 7,616.0 6,063.5 6,064.2 A-4, 2D-03 12/17/1984 1.0 APERF SINGLE SHOT 2D-03, 9/12/2022 6:03:19 PM Vertical schematic (actual) PRODUCTION; 30.1-7,907.1 FLOAT SHOE; 7,905.3-7,907.1 FLOAT COLLAR; 7,824.6- 7,826.3 APERF; 7,615.0-7,616.0 APERF; 7,613.0-7,614.0 APERF; 7,611.0-7,612.0 APERF; 7,581.0-7,625.0 WHIPSTOCK; 7,584.2 LEAK - CASING; 7,583.6 APERF; 7,561.0-7,562.0 APERF; 7,559.0-7,560.0 WLEG; 7,557.7 NIPPLE; 7,554.2 SBE; 7,545.3 PACKER; 7,542.8 LOCATOR; 7,542.0 GAS LIFT; 7,531.6 IPERF; 7,501.0-7,504.0 IPERF; 7,492.0-7,495.0 IPERF; 7,478.0-7,481.0 IPERF; 7,465.0-7,470.0 IPERF; 7,459.0-7,461.0 IPERF; 7,453.0-7,455.0 IPERF; 7,446.0-7,450.0 GAS LIFT; 7,435.3 GAS LIFT; 7,367.3 PACKER; 7,331.0 PBR; 7,317.3 GAS LIFT; 7,276.0 GAS LIFT; 6,634.4 GAS LIFT; 5,534.9 GAS LIFT; 4,040.7 SURFACE; 34.9-3,630.0 FLOAT SHOE; 3,628.1-3,630.0 FLOAT COLLAR; 3,547.6- 3,549.2 GAS LIFT; 2,028.5 SAFETY VLV; 1,948.8 CONDUCTOR; 35.0-117.0 HANGER; 34.9-39.4 HANGER; 30.0 KUP PROD 2D-03 ... WELLNAME WELLBORE2D-03 By Samantha Carlisle at 2:51 pm, Aug 29, 2022 C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2022-04-12_22012_KRU_2D-08_CaliperSurveywithLogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22012 KRU 2D-03 50-029-21178-00 Caliper Survey w/ Log Data 12-Apr-22 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile FTP ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 184-153 T36485 Kayla Junke Digitally signed by Kayla Junke Date: 2022.04.27 11:10:44 -08'00' ConocoPhillps ~~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 1St, 2010 Mr. Guy Schwartz Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 ~u I~JA~~ 20~ 8'~-~~~3 a~ _ 03 Dear Mr. Guy Schwartz: 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 10th, 20th and 24t1i, 2009. The corrosion inhibitor/sealant was pumped December 29th and 30th, 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, Perry K1 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 Fteld Date 01/01/10 - aa~ ~n ~n ~n n ~K Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2A-26 50103205750000 2080940 12" n/a 12" n/a 4.25 12/30/2009 2A-27 50103206040000 2091070 36" n/a 36" n/a 12.75 12/30/2009 2C-14 50029212260000 1842100 18' 2.5 50" 11/20/2009 12.32 12/30/2009 2C-15 50029212190000 1842030 SF n/a 26" n/a 4.67 12/30/2009 2C-16 50029212180000 1842020 SF n/a 33" n/a 7.22 12/30/2009 2D-02 50029211770000 1841520 SF n/a 24" n/a 4.45 12/30/2009 2D-03 50029211780000 1841530 SF n/a 24" n/a 4.67 12/30!2009 2D-04 50029211760000 1841510 SF n/a 24" n/a 4.45 12/30/2009 2A-05 50029211570000 1841260 SF Na 24" n/a 4.45 12/30/2009 2D-08 50029211580000 1841270 SF Na 28" n/a 4.67 12/30/2009 2D-13 50029210700000 1840120 21' 3.0 27" 11/10/2009' 5.1 12/30/2009 2D-14 50029211830000 1841590 SF n/a 24" n/a 6.37 12/30/2009 2D-16 50029211850000 1841610 28' 4.0 26" 11!10/2009 5.1 12/30/2009 3K-27 50029227510000 1970460 7' 1.0 12" 11/24/2009 2.97 12/29/2009 l ,; 04/30/09 ~~~~ NO. 5203 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ~,; ~~ -~ ~ ,~ j '}~' ~~~.~; ;; ~ ~,~(~,_, ~ Company: Alaska Oil & Gas Cons Comm ATTN: Beth ~' p - -~ Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk • Well Job # Log Description Date BL Color CD ~~3F-03 ~ ANHY-00070 INJECTION PROFILE ' - ~ 04/04/09 1 1 2D-03 ANHY-00075 PRODUCTION PROFILE _ - 04/10/09 1 1 1 E-29 604C-00030 PRODUCTION PROFILE l 9 04/14/09 1 1 3G-13 ANHY-00079 INJECTION PROFILE ~ _ c/ 04/15/09 1 1 3F-18 B04C-00031 PRODUCTION PROFILE / - 04/15/09 1 1 iD-117 8148-00027 INJECTION PROFILE 2 - '}- G 04/16/09 1 1 1D-128 AYS4-00057 INJECTION PROFILE 04/16/09 1 1 1H-21 B14B-00028 PRODUCTION PROFILE L 04/17/09 1 1 1 D-120 AYS4-00058 INJECTION PROFILE ' 04/17/09 1 1 2K-22 AYS4-00059 IBP/SBHP - 04/18/09 1 1 1 E-15 AYS4-00061 INJECTION PROFILE ~. 04/20/09 1 1 1Y-04 AYS4-00071 INJECTION PROFILE 04/28/09 1 1 3F-02 AYS4-00063 PRODUCTION PROFILE ~ - 04/22/09 1 1 1 G-04 8146-00036 SBHP SURVEY '~, L° _ G~ 04/23/09 1 1 iR-03A AYS4-00063 SBHP SURVEY i } -1_ r ~O~ _~?1 r ~ ~ C.~/(~ 04!23/09 1 1 iG-06 6146-00035 SBHP SURVEY ~ ~~ d ~c7 °- ~~c Qg ~ ~j~('~°~ 04/23/09 1 1 • iR-10 6148-00031 SBHP SURVEY - ~~ ~ 04/20/09 1 1 2F-02 AYS4-00060 INJECTION PROFILE v C _ )~ I Gf 04/19/09 1 1 1 R-15 6146-00032 SBHP SURVEY. - ~ ~ L 04/20/09 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 2D-03 (PTD 1841530) Report of Failed TIFL . . Tom & Jim, Kuparuk gas lifted producer 20-03 (PTO 1841530) failed a TIFL on 4/15/07 and has been added to the SCP report. The majority of the GL Vs are 1997 vintage and are suspected to be the leak point. Slickline will troubleshoot the leak for repair. Attached is a 90 day TIO plot and a schematic. Please let me know if there are any questions. Marie McConnell Problem Well Supervisor (907) 659-7224 n1617@conocophillips.com SC~ APR 3 () 2007 «20-0390 day TIO plot 4-17-07.gif» «20-03.pdf» I .--.. Content-Description: 2D-03 90 day no plot 4-17-07.gif 2D-03 90 day TIO plot 4-17-07.gif Content-Type: image/gif Content-Encoding: base64 Content-Description: 2D-03.pdf Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 4/18/2007 1 :50 PM . . KRU 2D-03 API: 500292117800 Well Tvee: PROD Anole @ TS: 42 deo @ 7418 SSSV Tvee: TRDP Orio Comeletion: 10/9/1984 Anole @ ID: 43 deo I1iJ 7923 SSSV Annular Fluid: Last W/O: Rev Reason: C/O CVs (1949-1950, Reference Lao: Ref Loq Date: Last Update: 12/18/2006 00:3.500) ~ ~ DescriDtlon Size Too Bottom TVD WI GrAde Thread Gas Lift 1 CONDUCTOR 16.000 1 0 1 117 I 117 I 62,50 H-40 MandrelNalve 1 SUR. CASING 9.625 1 0 1 3630 I 3134 I 36.00 J-55 I I 1 (2029-2000, _ CASING 7.000 1 0 1 7907 1 E ~76Graale IF J-55 1 I I Size i Too Bottom TVD WI Thread 1 Gas Lift I 3.500 1 0 1 7558 I 6022 1 idI J-55 I EUE 8RC MandrelNalve ii: 2 (4041-4042, Interval TVD Zone Status Ft SPF Date Type r.nmmAnt 7446 - 7450 5939 - 5942 C-3 4 12 11/24/1984 IPERF 120 deg Ph; 5" DA Cso Guns 7453 - 7455 5944 - 5945 C-2 2 12 11/24/1984 IPERF 120 deo Ph; 5" DA Cso Guns Gas Lift 7459-7461 5948 - 5950 C-2 2 12 11/24/1984 IPERF 120 deq Ph; 5" DA Cso Guns MandrelNalve 7465 - 7470 5953 - 5957 C-2 5 12 11/24/1984 IPERF 120 deg. Phasino; 3 7478 - 7481 5963 - 5965 C-1,UNITB 3 12 11/24/1984 IPERF 120 deg Ph; 5" DA Cso Guns (5535-5536, 7492 - 7495 5973 - 5975 UNITB 3 12 11/24/1984 IPERF 120 deo Ph; 5" DA Csa Guns 7501 - 7504 5980 - 5982 UNITB 3 12 11/24/1984 ¡PERF 120 deq Ph; 5" DA Cso Guns Gas Lift 7559 - 7559 6022 - 6022 A-5 0 1 12/17/1984 APERF SINGLE SHOT MandrelNalve 7561 - 7561 6024 - 6024 A-5 0 1 12/17/1984 APERF SINGLE SHOT 4 7581 - 7611 6039 - 6061 A-4 30 4 7/6/1990 APERF 180 deo. Ph; 2.5" Titan II HC (6634-6635, 7611 -7611 6061 - 6061 A-4 0 5 7/6/1990 APERF 180 deq. Ph; 2.5" Titan II HC 7611 - 7613 6061 - 6062 A-4 2 4 7/6/1990 APERF 180 deg. Ph; 2.5" Titan II HC 7613 - 7613 6062 - 6062 A-4 0 5 7/6/1990 APERF 180 deg. Ph 2.5" Titan II HC Gas Lift 7613 - 7615 6062 - 6063 A-4 2 4 7/6/1990 APERF 180 deo. Ph 2.5" Titan II HC MandrelNalve 7615-~ A-4 0 5 7/6/1990 APERF 180 deg. Ph; 2.5" Titan II HC 5 (7276-7277, 7615.. - A-4 10 7/6/1990 P. PERF 180 deg. Ph; 2.5" Titan II H( :'i8: nwn i::i Port _ Date Run Vlv St MD TVD Man Mfr Man Type VMfr V Type VOD Latch PBR Cmnt (7317-7318, 1 2029 1963 MMH 31/2X 1 GLV 1.0 BK 0.156 1287 7/27/1997 00:3.500) 2 4041 3433 MMH 31/2X 1 GLV 1.0 BK 0.188 1314 7/27/1997 3 5535 4528 MMH 31/2X 1 GLV 1.0 BK 0.188 1304 7/27/1997 4 6634 5333 MMH 31/2X 1 GLV 1.0 BK 0.250 1339 2/23/1998 PKR 5 7276 5811 MMH 31/2X 1 OV 1.0 BK 0.188 0 3/6/2002 (7331-7332, 00:6.151) 51 MD TVD Man Mfr Man Type VMfr V Type VOD Latch Port TRO Date Run Vlv Cmnt 6 7367 5880 MMH 31/2X 1 MACCO CV 1.0 BEK 0.000 0 12/15/2006 Production 7 7435 59311 MMH 31/2X 1 MACCO CV 1.0 BEK 0.000 0 12/15/2006 MandrelNalve 8 7532 60021 MMH 31/2X 1 MACCO CV 1.0 BEK 0.000 0 12/15/2006 6 T:T;:;;;!!!!!!!!!!!] (7367-7368, DeDth TVD TVDe ID 1949 1894 SSSV Baker 'FVL' Locked Out 3/5/90) Pulled FXE an 3/18/95 2.810 7317 5842 PBR Baker 3.000 Production 7331 5853 PKR Baker 'FHL' 3,000 MandrelNalve 7543 6011 PKR Baker 'FB-1' 4.000 7 (7435-7436, 7554 6019 NIP Cameo 'D' Nieele NO GO 2.750 ........ 7558 6022 GUIDE RE-ENTRY GUIDE 2.992 Perf = ~ 7558 6022 TTL 2.992 (7446-7450) =- '= ------ -- Perf - - - -- (7492-7495) - - - -- Production MandrelNalve 8 (7532-7533, PKR (7543-7544, 00:6.151) NIP (7554-7555, 00:3.500) TUBING (0-7558, 00:3.500, ----- - ------ 102.992) ...... ....- -- Perf ....... ........... (7581-7625) - -- .......... - - ==;; ==;; Schlumberger NO. 3357 Schlumberger -DGS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth (?! </- /):, 02/28/05 SCANNED JUN 1 6 2005 Company: Alaska Oil & Gas Cons Gomm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job # Log Description Date BL i'ð5 -o5C 2V-12 10942845 PROD PROFILEIDEFT 02/16/05 1 t8tf-153 2D-03 10922538 PROD PROFILE/DEFT 02/06/05 1 ~ &0 - 2.1 f.t;? 1 D-39 10942838 INJECTION PROFILE 02/11/05 1 ifjJ- -C~~- 2V-10 10942846 PROD PROFILE/DEFT 02/17/05 1 ~Ol- F33 1 C-131 10942848 INJECTION PROFILE 02/19/05 1 Ifo -/6/ 1A-19 10942839 PRODUCTION PROFILE 02/12/05 1 /79-0/0 2N-308 10942843 PRODUCTION PROFILE 02/14/05 1 ~;V~~b 1 L-17 10942850 INJECTION PROFILE 02/21/05 1 1B-15A 10922540 SCMT 02/24/05 fl/-lJfv fp 1 L-24 (REDO) 10942834 RST WFL & PPROF 01/26/05 1 Kuparuk Color CD -- 1 --- SIGNd4~¡ !ith~ DATE: ~þ- Please sign and returle copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. !"'"'"\ ",......., I, (QJ tïT r ^,-, 1\ ¡~'-J r e \ ") ! ¡ILl \ If l[ cQ. L Lrl'\ U :=J ill]~; !Æ ~ D~ ~ ~ ffi~ .. í I ! .. i ¡ I I I / i ì ! FRANK H. MURKOWSK/, GOVERNOR . AI/ASIiAOILANDGAS CONSERVATI ON COMMISSION May 12, 2004 333 W. 7'" 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 ~~-lb3'- Dear Mr. Wheatall: The Alaska Oil and Gas Conservation Commission ("Commission") performed an inspection of your well safety valve system (SVS) at Kuparuk River Unit 2D (KRU 2D) pad on May 6, 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. Effective May 6, 2004, and until an acceptable level of performance is achieved, the safety valve systems associated with wells located on KRU 2D must be tested every 90 days. When testing is scheduled, you must notify the Commission Field Inspector at 907-659-2714 to provide an opportunity to witness the SVS test. Sincerely, 1H ¡¿¡OJ T. Seamount, Jr. Commissioner Attachment cc: AOGCC Inspectors (via email) Safety Valve & Well Pressures Test Report - Review Reviewed By: P.I. Suprv Comm Pad: KRU_20 Inspection Dt 5/6/2004 Inspected by Chuck Scheve Interval: InspectNo: svsCS040507072635 Src: Inspector Field Name KUPARUK. RIVER Operator CONOCOPHILLIPS ALASKA INC Operator Rep Bob Noble Reason 90-Day Well Number Permit Number Separ PSI Set PSI UP Trip Test Test Test Code Code Code Date SI Oil,WAG,GINJ, GAS,CYCLE, SI Inner PSI Outer PSI Tubing PSI Yes/No Yes/No I 20-13 1840120 98 70 60 P P I-OIL 20-12 1840940 98 65 P I-OIL -- I 70 P I 20-09 1841030 98 70 65 P P I-OIL I 20-08 1841270 98 70 65 P P I-OIL i 20-068 1981760 98 70 65 P P I-OIL j 20-03 1841530 98 70 65 P P I-OIL I 20-15 1841600 98 70 50 P 4 I-OIL 1000 1000 ISO Yes Yes IA x OA communication L 20-01 1841710 98 70 0 10 P I-OIL ) Comments Performance Pilot on well 20-01 failed to trip on initial test,was replaced and passed retest. Surface Safety Valve on Well 20-15 had very slow leak when pressure tested. Valve to be repaired and retested by operator. Wells 8 Components 16 Failures 2 Failure Rate 12.5% ) Wednesday, May 12,2004 STATE OF ALASKA ALAb, v-~ OIL AND GAS CONSERVATION COMMISS,~N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate X 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 -- 65' FNL, 717' FEL, Sec. 26, T11N, R9E, UM At top of productive interval 1421' FNL, 1256' FEL, Sec. 23, T11N, At effective depth 1145' FNL, 1270' FEL, Sec. 23, T11N, At total depth 1077' FNL, 1272' FEL, Sec. 23, T11N, 12. Present well condition summary Total Depth: measured 7 9 true vertical 62 R9E, UM R9E, UM 6. Datum elevation (DF or KB) RKB 127 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2D-03 9. Permit number/approval number 84-153 10. APl number 50-029-21178-00 11. Field/Pool Kuparuk River Field/Oil Pool R9E, UM 23 feet Plugs (measured) None 86 feet Effective depth: measured 7825 feet true vertical 6215 feet Junk (measured) Valve @ 6614' Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 8 0' I 6" 204 Sx CS II I 1 7' 1 1 7' Surface 3595' 9-5/8" 850 Sx AS III & 3630' 3134' Intermediate 500 Sx Class G Production 7893' 7" 481 Sx Class G & 7 9 0 7' 6 2 7 5' Liner 250 Sx AS I Perforation depth: measured RECEIVED 7446'-7504' (Scattered), 7559'-7561', 7581'-7625' true vertical 5937'-5980', 6021'-6022', 6037'-6069' DEC 22. 99;r Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., J-55 @ 7538' Packers and SSSV (type and measured depth) Naska0il &AnGas Cons, C0rnmissi0fl Packer: Baker FH @ 7310' & Baker FB @ 7523'; SSSV: Baker FVL @ 1928' (Locked ob~)ch°rage 13. Stimulation or cement squeeze summary Fracture stimulate 'A' Sands on 7/22/97. /~t/ Intervals treated (measured) ORIGIN 7559'-7561 ', 7581 '-7625' Treatment description including volumes used and final pressure Pumped 210 Mlbs of 20/40 ,~nd 12/18 ceramic proppant into formation, fp was 4787 psi. 14. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation 3 7 5 329 12 1296 Subsequent to operation 523 159 220 1316 Tubing Pressure 154 141 1,5. 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. Si~]ned Form'/~0-404 Rev 06~8 fO/' ~', ~""~¢ ,"~'X Title Wells Superintendent Date // )----/7--?7 SUBMIT IN DUPLICATE nRCO Alaska, Inc.' .... KUPARUK RIVER UNIT '' WELL SERVICE REPORT ~' K1(2D-03(W4-6)) WELL JOB SCOPE JOB NUMBER 2D-03 FRAC, FRAC SUPPORT 0718971712.6 DATE DAILY WORK UNIT NUMBER 07/22/97 PUMP "A" SANDS REFRAC DAY - OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 3 (~) Yes O NoI (~) Yes O No DS-GALLEGOS JOHNS FIELD AFC# CC4f DAILY COST ACCUM COST Si~e~f'~2 ESTIMATE KD1401 23ODS28DL $97,523 $128,591 ~'/~~/~¢~ Initial Tb.q Press Final Tb_q Press Initial Inner Ann Final Inner Ann I Initial O u,eC/~nn I Final//O/t~r Ann 0PSI 2300PSl 1200PSl 1000PSll 400PSll '-" 400PSi DALLY SUMMARY I PUMPED "A" SANDS REFRAC ' WITH 210'226# TO 13 PPA 12/18 PROPPANT FLUSHED TO PERFS ' LEFT 1212 # PROPPANT IN IPIPE. TIME LOG ENTRY 08:00 MIRU DOWELL FRAC EQUIP, HOT OIL PUMP AND APC VAC TRUCK. 08:30 HELD ON SITE SAFETY MEETING 09:00 PRESSURE TEST TREATING LINE TO 8400 PSI. 10:48 PUMPED BREAKDOWN W/25BPM AND 3565 PSI, 50 #GEL 100 BBLS. 11:05 11:11 12:18 13:50 14:11 14:16 PUMP 20/40 PROPPANT SC_O~UR_.,._15BPM' AND~..4312 PSI. PUMP 108 BBLS FLUSH, INCLUDING 98 BBLS STRAIGHT SEAWATER. 15BPM AND 2814 PSI. SHUi- DOWN FOR iSIP 1624 PSI AND PUMPED PULSE TEST. PUMP DATA FRAC, 5TO 15 BPM AND 3680 PSI. SHUT DOWN FOR ISIP 1707 PSI AND CALCULATE CLOSURE PRESSURE. PUMP 115 BBLS PAD AT 5 TO 15 BPM AND 3440 PSI. PUMP 22,4144f 20/40 TO 2PPA, 15 BPM AND 3895 PSI. PUMP 189,024~ OF 12/18 FROM 6PPA TO 13 PPA 15 BPM 4787 PSI. 15:11 PUMP FLUSH FROM 15 TO 5 BPM, FLUSH 2 BBLS FROM PERFS. 15:19 SHUT DOWN AND RDMO SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $744.00 . APC $7,000.00 $13,000.00 _DIESEL $0.00 $1,512.00 DOWELL $88,823.00 $100,721.00 HALLIBURTON $0.00 $5,709.00 LI]-FLE RED $1,700.00 $5,554.00 NITROGEN $0.00 $1,351.00 TOTAL FIELD ESTIMATE $97,523.00 $128,591.00 STATE OF ALASKA ~' ~ ~ OIL AND GAS OONSERVATION OOMMISb,ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Pull tubing Alter casing 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 Stimulate X Plugging Repair well 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 65' FNL, 717' FEL, Sec. 26, T11N, R9E, UM At top of productive interval 1421' FNL, 1256' FEL, Sec. 23, T11N, R9E, UM At effective depth 1249' FNL, 1264' FEL, Sec.23, T11N, R8E, UM At total depth 1077' FNL, 1272' FEL, Sec. 23, T11N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 7923' feet 6286' feet Plugs (measured) None Perforate Other 6. Datum elevation (DF or KB) 6200' SS 7. Unit or Property name Kuparuk River Unit 8. Well number 2D-03 Producer 9. Permit number/approval number {14-153/90-435 10. APl number 5o-029-21 1 78 11. Field/Pool Kuparuk River Oil Pool fee~ Effective depth: measured 7 8 2 5' feet true vertical 6215' feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 7446'-7450' I !! 7501 -7504, Length Size 117' 16" 3630' 9 5/8" 7907' 7" Cemented Measured depth True vertical depth 200 CF I 17' 1 17' 850 Sx AS III & 3630' 31 34' 500 Sx Class G 300 Sx Class G 7 9 0 7' 6 2 7 4' measured 7453'-7455', 7459'-7461', 7559'-7561', 7581'-7625' true ve~ical 5937'-5940' 5943'-5944', 5947'-5949', 5951'-5955', , 5978-5980, 6021'-6022', 6037'-6069' 7465'-7470', Tubing (size, grade, and measured depth) 3 1/2", 9.3 Ib/ft, J-55, 7538' Packers and SSSV (type and measured depth) Baker FHL @ 7310', Baker FB-1 @ 7523', BXE SSSV @ 1928' 13. Stimulation or cement squeeze summary 14. Intervals treated (measured) Refractured the A Sand 6021'-6069' MD Treatment description including volumes used and final pressure Refractured the A Sand with 17,500 lbs 16/20 Carbo-Lite. 7478'-7481', 7492'-7495', 5961 '-5963', ~972'-5974', /'iOOj~.. ~00~. "vO,.O.0 Final treating pressure 4000 psi Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 600 100 10 1200 500 300 0 900 255 190 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Water Injector ~ Oil X Gas Suspended Service 17. Signed 42~~ ~~''~ Form 10-404 Rev 09/12/90 I hereby certify that the foregoing is true and correct to the best of my knowledge. Date SUBMIT IN DUPLICATE . ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company "iELL CONTRAC~OF~ O~W~II-- REMARKS IPBDT. WELL SERVICE REPORT I FIELD - DISTRICT- STATE /f/-~A" IDAys IDATE · ia35 - 5 7';' .' T'.Yrodp, ,, T' I$0o I'-I CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Ab OIL AND GAS CONSERVATION COMM. REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate X Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 65' FNL, 717' FEL, Sec. 26, T11N, R9E, UM At top of productive interval 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service _ 6. Datum elevation (DF or KB) 6200'SS 7. Unit or Property name Kuparuk River Unit 8. Well number 2D-03 Producer 9. Permit number 1421' FNL, 1256' FEL, Sec. 23, T11N, R9E, UM At effective depth 1249' FNL, 1264' FEL, Sec.23, T11N, R8E, UM At total depth 1077' FNL, 1272' FEL, Sec. 23, T11N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 7923' feet Plugs (measured) 62 8 6' feet 84-153/90-413 10. APl number 5o-029-211 78 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured true vertical 7825' feet Junk (measured) 621 5' feet Casing Structural Conductor Surface Intermediate Production Perforation depth: 7446'-7450' ! 7501 '-7504', 5937'-5940', 5978'-5980', Length Size 117' 16" 3630' 9 5/8" 7907' 7" measured 7453'-7455', 7459'-7461', 7559'-7561', 7581 '-7625' true vertical 5943'-5944', 5947', 5949', 6021'-6022', 6037'-6069' Cemented Measured depth True vertical depth 200 CF 117' 117' 850 Sx AS III & 3630' 31 34' 500 Sx Class G 300 Sx G 7907' 6274' 7465'-7470', 7478'-7481', 7492'-7495', 5951'-5955', 5961'-5963', 5972'-5974', Tubing (size, grade, and measured depth 3 1/2", 9.3 Ib/ft, J-55, 7538' Packers and SSSV (type and measured depth) Baker FHL 7310', Baker FB-1 @ 7523', BXE SSSV @ 1928' RECEIVED 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Perforated the A4 Sand from 7581'-7625' MD SEP o Alaska 0il & Gas Cons. Commls$io[ Anchora~,a 14. Prior to well operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 475 I 00 1 5 1 200 Tubing Pressure 225 Subsequent to operation 600 I 00 1 0 1 200 255 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 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. Si,ned ¢~'~ 'd~. ~ Title 6~-~"~;~ ~~~$~Date ~ '"~"~ "~) Form 10-404 Rev 06/15/88 ~ u, SUBMIT IN DUPLICATE ;,-I · --, ~ , DIS1': DS ~ d <'~ V.,' /~-? HR Ced file KUPARUK oPERATION5 ENGINEERING PERFOIIATION IIECOFlD [1,~ Fill (:OIIPLETION O~TAILS: ~-/,- ~ x.'~.~/¢~./e , ,, ,,, PERF Ira.. _ (N~ ~o. 2 '/z ". _ ~/,~ /1~,. ///~, ~,~,;,,.... ................ tu, o-t Jo,.,~ ~L 7 ~, o~/ i,- ~.. ~/.,~ . ,. /1~ ~. (m~ DIL) (~~l) (fl) M ~IH ~MENT$ i i i iiii ii i i J iii iiii iii iiii iii ii i J i ii iiii iiii i i i / ~ ~- ~= z¢~ ' 7~o¢ - ~-,, ?/.~._,~ · , Il I I Illll I I I I I I I I I I I I I III kl. I III I , · i i · i m i i · i · · ii i il i ii i · il .i ARCO Alaska, Inc; Post Office b~x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 1, 1990 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached in triplicate is an Application for Sundry Approval on the following Kuparuk well. We II Action Anticipated Start Date 2D-03 Stimulate June, 1990 If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Operations Engineer cc: J.R. Brandstetter ATO 1120 w/o attachments L. Perini ATO 1130 KOE1.4-9 "=~. '.~k.a Oil & Gas Cons, Cornrnfssio~ Anchorag/a ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCon,,,-:,:'~;W STATE OF ALASKA A,. ~ OIL AND GAS CONSERVATION COM~v,,~,~,ON D APPLICATION FOR SUNDRY APPROVALS I INAL 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate _~ Pull tubing _ Variance _ Perforate _ 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 65' FNL, 717' FEL, Sec. 26, T11N, R9E, UM At top of productive interval 1421' FNL, 1256' FEL, Sec. 23, T11N, R9E, UM At effective depth 1249' FNL, 1264' FEL, Sec.23, T11N, R8E, UM At total depth 1077' FNL, 1272' FEL, Sec. 23, T11N, R8E, UM Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 7446'-7450', 7501 '-7504', 6. Datum elevation (DF or KB) §200' SS 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2D-03 9. Permit number 84-153 10. APl number 5o-029-21 1 78 11. Field/Pool Kuparuk River Field Kuparuk Rive[-~?~. ~,. o~1 . 12. Length Size 7923' feet Plugs (measured) 6 2 8 6' feet None 7825' feet Junk (measured) 621 5' feet None Cemented Measured depth 'Tr~Je~¥eCr~ra~epth I 1 7' I 6" 200 CF 363 0' 9 5/8" 850 Sx AS III & 500 Sx Class G 7 9 0 7' 7" 300 Sx Class G 117' 117' 363O' 3134' 7907' 6274' measured 7453'-7455', 7459'-7461', 7465'-7470', 7559'-7561', 7589'-7603', 7611'-7616' true vertical 5937'-5940', 5943'-5944', 5947'-5949', 5951 '-5955', 5978'-5980', 6021 '-6022', 6043'-6053', 6059'-6063' Tubing (size, grade, and measured depth 3 1/2", 9.3 lb/fi, J-55, 7538' Packers and SSSV (type and measured depth) Baker FHL @ 7310', Baker FB-1 @ 7523', BXE SSSV @ 1928' 7478'-7481' 5961 '-5963' , 7492'-7495', , 5972'-5974', 13. Attachments Description summary of proposal _ Fracture A Sand with gelled water and 16/20 Carbo-Lite Detailed operation program X BOP sketch 14. Estimated date for commencing operation June 24, 1990 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas m Service Suspended 7. I ;i~lned hel~lby c.~rtifE that the. fo_regoing is true and correct to the best of my knowledge. Title FOR COMMISSION USE ONEY Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test Approved by the order Commission Form 10-403 Rev 5/03/89 Subsequent form ORIGINAL SIGNED BY LONNIE (~. RI~ITI-I require 10- ~/ Commissioner Approved Copy Returned IAppro ENo. SUBI(/IlT'Ih ~'RIPLICATE Sundry Notice - Well 2D-03 Pump an A Snad gelled water fracture treatment utilizing 190 bbls of gelled water and 22,000 lbs of 16/20 Carbo-Lite proppant. NO BOP'S WILL BE UTILIZED DURING THIS PROCEDURE. The treatment will be pumped through a surface manifold. A Sand Pressure (6200' SS) = 2640 psi SBHP 3/7/90 NO WORKOVER FLUID WILL BE USED DURING THIS PROCESS. Gas Cons. Anchora[~e M. Lyden/L. Wade May 31, 1990 Page 4 Kuparuk Well 2D-03 A Sand Refracture AFE #XXXXXX PRE-FRAC SLICKLINE 1. Obtain a 24 hour well test. 2. MIRU slickline unit. 3. Pull BXE-SSSV at 1928' MD. 4. RIH with 2" gauge ring and tag bottom. 5. RIH with blanking plug and set in CAMCO 'D' nipple. Pressure test tubing to 4500 psi. Pull blanking plug. 6. RDMO slickline unit. NOTE: Fill should have been tagged when reperforating the A4 Sand. Consult Operations Engineering if fill is tagged any higher than 7616' to evaluate if a pre-frac CTU cleanout is necessary. FRACTURE TREATMENT 7. RU fracture equipment. Install 'Tree Saver'. Pressure up 7" annulus to 3500 psi. 8. Perform all fluid quality control procedures (On-site Operations Engineer). Obtain samples of: - Clean proppant - Pre-pad, pad, 2, 6, 10, and 12 ppa stages and flush . 10. Record proppant weight before and after the frac. Pump the 20 bbl pre-pad. Pump refracture treatment per the attached schedule: WHTPE = Fracture Gradient = Tubing Friction = Recommended Max. WHTP = NOTE: 4000 psi 0.70 psi/ft (6050' TVD) 300 psi/lO00 ft (7540' MD) 6000 psi If treating pressure during the job exceeds 5500 psi, reduce rate. 1 1. Rig down frac equipment. M. Lyden/L. Wade May 31, 1990 Page 5 POST FRAC 12. RU Slickline unit. 13. Tag fill. 1 4. Reset BXE-SSSV at 1928' MD. 15. RDMO slickline unit. 1 6. Follow attached flowback schedule. After well has completed flowback, obtain a 24 hour test. The well should be left on A Sand only production. M. Lyden/L. Wade May 31, 1990 Page 6 Well 2D-03 Flowback Schedule The following flowback procedure for water-based gel fracture stimulations has been discussed and approved by Operations Engineering (KOE), Facility Engineering (KFE) and Production Operations. Deviations from or modifications to this procedure/piping installation are expected, but they should be reviewed/approved by each of these groups. . , , , , , Establish baselines for comparison by visually inspecting choke and performing NDT of erosion prone areas, immediately down stream of choke, all elbows and all tees, that will be exposed to flowback fluids. Document these inspections on the attached Flowback Log. Obtain representative fluid samples from the pad, slurry, and flush stages during the fracture treatment. Operations Engineer -- Place samples in hot water bath at 150° F to observe break time. After the design break time and after verifying that the gel has broken in the water bath, Operations Engineer will contact the Production Foreman to initiate start of flowback. If gel has not broken, DO NOT ATTEMPT FLOWBACK. Contact Anchorage Engineering to discuss options if gel remains unbroken. Open well up flowing to the test separator, the initial targeted nominal rate should be 300 BLPD. Set Iow flowrate alarm for 50 BLPD. Set high flowrate alarm on test separator for 600 BLPD for a 3" choke or at 1100 BLPD for a 4" choke. On bottoms up, verify that gel is broken. If excessive proppant or unbroken gel is present, SI well and contact KOE Coordinator. Do not exceed 500 BLPD for the first 12 hours of flowback. After the first 12 hrs, open the choke and flow well at 500 BLPD for the next 12 hrs. Record rates, choke settings and WHPs on Flowback Log. After the first 24 hrs of flowback, decrease wellhead pressure in 50 psi increments at regular time intervals (minimum two hours) until the well is producing at header pressure. LIMIT THE FLOW RATE INCREASE TO NO MORE THAN 750 BLPD IN A 24 HOUR PERIOD. Reset high flowrate alarm to stay below erosional velocity as predicted by the table provided by Corrosion Engineering and shown below in step 10. Alarm settings should be based on the maximum flowrate for the average GLR from the first 24 hrs of flow. If GLR changes again by more than 250 scf/bbl, change high flowrate alarm as appropriate. Record rates, choke settings, and WHP's during the flowback period on the Flowback Log. Take BS&W samples at bottoms up after every choke change and/or every 8 hrs and record results on the FIowback Log. If excessive proppant or unbroken gel is found contact KOE Coordinator. M. Lyden/L. Wade May 31, 1990 Page 7 . Inspect the choke internals visually and perform NDT on the erosion prone areas, down stream of the choke and the S-riser, twice during the first week and weekly thereafter until it is confirmed that an erosive condition does not exist. Maximum flowrates should be limited to those specified in the following table, if these maximums are exceeded choke the well back and inspect the erosion prone areas. C,-AS 4" CHOKE 3"CHOKE LIQUID MAXIMUM MAXIMUM RATIO FLOW RATE FLOW RATE 300 SC~BBL 3500 BLPD 2000 BLPD 500 2800 1600 1000 2000 1100 1500 1500 800 2000 1300 700 3000 1000 500 5000 700 400 . . Flowrates are to be increased over the maximums outlined in the previous table only after a non-erosive condition is verified through inspection and confirmed by Corrosion Engineering. Document on the Flowback Log. If erosion in the piping or choke body is identified, the well will be choked back to the previous non-erosive rate until some indication is obtained that the solids production has decreased and an assessment of the damage has been made. Appearance of any erosive conditions will trigger more intensive monitoring than stated above. Once the FTP has returned to normal line pressure, send all Flowback Logs and other pertinent information to KOE Coordinator. NOTE: Documentation of choke changes, all inspections, shake out results, etc., in addition to the flow data on the Flowback Log, will be very helpful in further refining the erosion potential and appropriate monitoring plans. ARCO Alaska, In Post Office ,~ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached in triplicate is an Application for Sundry Approval on the following Kuparuk well. W~ll Action Anticipated Start Date 2D-03 Perforate May, 1 990 If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Operations Engineer cc: J.R. Brandstetter ATO 1120 w/o attachments L. Perini ATO 1130 KOE1.4-9 ARCO Alaska, Inc. is a Subsidiary of AtianticRichfieldCompai~!., /-"" ' STATE OF ALASKA ,-.,_A~ OILAND GAS CONSERVATION COIWMI$.5,ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown _ Re-enter suspended well_ _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate X 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 65' FNL, 717' FEL, Sec. 26, T11N, R9E, UM At top of productive interval 1421' FNL, 1256' FEL, Sec. 23, T11N, R9E, UM At effective depth 1249' FNL, 1264' FEL, $ec.23, T11N, R8E, UM At total depth 1077' FNL, 1272' FEL, Sec. 23, T11N, R8E, UM 6. Datum elevation (DF or KB) 6200' SS _ 7. Unit or Property name _ Kuparuk River Unit j~ I 8. Well number ... I 2D-03 ~,~' (,,t"j , 9 Permit number 153 4%q ),~0~0/i 5o-029-21 178 - ~/'~n ,,[ 11. Field/Pool oiIKuparUkpool River Field ,~)~.u//~. ~',,.~ Kuparuk River feet 12. Present well condition summary Total Depth: measured true vertical Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 7446'-7450', 7501 '-7504', measured true vertical Length 117' 3630' 5937'-5940', 5978'-5980', 7923' 6286' 7825' 6215' Size 16" 9 5/8" 7907' 7" measured 7453'-7455', 7459'-7461', 7559'-7561', 7589'-7603', true vertical 5943'-5944', 5947'-5949', 6021'-6022', 6043'-6053', Tubing (size, grade, and measured depth 3 1/2", 9.3 Ib/ft, J-55, 7538' Packers and SSSV (type and measured depth) feet Plugs (measured) feet None feet Junk (measured) feet None Cemented Measured depth True vertical depth 200 CF 117' 117' 850 Sx AS III & 3630' 31 34' 500 Sx Class G 300 Sx Class G 7 9 0 7' 6 2 7 4' 7465'-7470', 7478'-7481', 7492'-7495', 7611 '-761 6' 5951'-5955', 5961'-5963', 5972'-5974', 6059'-6063' Baker FHL @ 7310', Baker FB-1 @ 7523', BXE SSSV @ 1928' 13. Attachments A4 Sand perforations. Description summary of proposal Detailed operation program X.~ BOP sketch 14. Estimated date for commencing operation May 29, 1990 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil ;K Gas __ Service Suspended 17. I Signed h~b~rt,~that~oing is true and correct to the best of my knowledge. Title FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test__ Subsequent form require 10- IIAppr°val N~) Approved by the order Commission ORIGINAL SIGNED .BY LONNIE C. SMITH Form 10-403 Rev 5/03/89 Commissioner Approved Copy SUB'MIT I1~ TRIPLICATE M. Lyden/L. Wade May 24, 1990 Page 4 Kuparuk Well 2D-03 Reperforate A4 Sand 5/24/90 CC: 230DS28DL This procedure is designed to perforate the A4 Sand to increase production and prepare the well for an upcoming refracture treatment. An E-line through tubing perforating system will be used, Two runs with 4 shots per foot each are required to cover the entire 44' interval, oriented 180° apart with 2 spf on the Iow side of the hole and 2 spf on the high side of the hole. Every fifth perforation should be a 'big hole' shot. The perforating will be performed underbalanced with a total of 4 shots per foot, 1 .) Obtain a 24 hour well test. 2.) MIRU slickline unit. 3.) Pull BXE-SSSV. 4.) Gauge tbg with at least 2.70" gauge ring through the 'D-Nipple' and tag fill. NOTE: On 1/3/90 fill was tagged at 7682' MD-RKB. On 3/6/90 this well was gauged to the 'D-Nipple' with a 2.79" gauge ring. The HLS perf gun swells to 2.625" so at least 2.70" clearance is necessary. (If the 2.70" gauge ring does not pass through the D-Nipple contact Operations Engineering before perforating) 5.) RDMO slickline unit. 6.) MIRU E-line perforating unit. Pressure test the lubricator. 7.) Tie-in and perforate the following depths: DIL/$FL (MD-RKB) (;;BL (MD-RKB) 7603' - 7625' 7603' - 7625' 7581'- 7603' 7581' - 7603' Shot Density/Phase Length 4 spf/180° 22' 4 spf/180° 22' Perforate underbalanced with well flowing. It is not necessary to fully open the well, just enough to lower the bottom hole pressure by 300 to 500 psi. Flow well only while shooting the perforations. Shut in well while running in and out of the well with the gun to prevent any semi-expendable perf gun debris from sticking the gun and allowing any debris to fall into the rathole. 8.) RDMO E-line perforating unit. 9.) MIRU slickline unit. M. LYden/L. Wade May 24, 1990 Page 5 10.) Reset BXE-SSSV at 1928' MD. 11.) RDMO slickline unit. 12.) Return well to production and obtain a 24 hour flow test once well stabilizes. Sundry Notice - Well 2D-03 Perforate the A4 Sand with a total of 4 shots per foot and 180 deg phasing from 7581' to 7625' MD. A Sand Pressure (6200' SS) = 2640 psi SBHP 3/7/90 NO WORKOVER FLUID WILL BE USED DURING THIS PROCESS. 1. SOO0 PSt 7" WI~LLHC, AD CO~N£C~OR :2. ~000 PS1 W~R£LIN[ RAJd$ (VARIABLE; 3. 5000 PS1 4 1/G" LUBR~CA'fOR 4. 5000 PS1 4 1/6" FLOW TUBI[ PACK-Orr 2 REt. INE. BOP EO,U 1 PI IEHT ARCO Alaska, Post Office. ,.,x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: September 2, 1987 Transmittal # 6049 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. 1Y-3 1Y-14 1Y-5 1G-1 1G-7 2D-3 Pressure Report 'A' Sand 8-20-87 100596H Static Gradient Survey 8-20-87 100556Y14 Static Survey 8-20-87 1005551Y5 Kuparuk Well Pressure Report(Camco) 8-24-87 Kuparuk Well PresSure Report 8-24-87 Kuparuk Well Pressure Report(Otis)'C' Sand 8-2-87 Alaska Oil & Gas Cons. Commission Anchorage Receipt Acknowledged: DISTRIBUTION: Date: BPAE Chevron Mobil SAPC Unocal D&M ARCO Alaska, Inc, is a Subsidiary of AllanlicRIchfleldCompany ARCO Alaska, Inc. Post Office Box 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 03-05-86 TRANSMITTAL ~ 5590 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Final Prints/ CBL-VD/ Schl/ One * of each 2D-3 ll-04-S~ Run #1 6448-7770 Please Note--This log was received 03-03-86 and I have no idea why it is so old. rhs Receipt Acknowledged: Vault*films NSK Clerk*bl 2'1986- Drilling*bi Anchorage ARCO Alaska, Inc. is a Subsidiary of AllanticRichlieldCompany .. RETURN TO: ARCO?~ 'a, Inc. f~,_: ~,-~Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 ARCO ALASKA, INC. KU PARUK _OPE RATIONS ENGINEERING RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED HEREWITH ARE THE FOLLOW RECEIPT AND RETURN ONE SIGNED COPY ***CONTINUED. FROM PREVIOUS PAGE*** 2D-5 FLOWING BHP ETC 05-06-85 ~~"' ACID JOB PREP 05-0 7-8S :~~~ ACIDIZE 'C'SD 05-11-85 2E-9 G.R. SBHP 06-11-85 2E-13 SBHP 06-10-85 2E-14 SBHP 06-10-85 25-15 SBHP 06-09-55 25-1 F~OWING ~ 0~-~ 9-S 5 2:~-Z SH~TCL 2H-3 ~HP ~ ZTC. 2~-~ COMP S~P 05-~3-55 ~-~ IN~. SS~P~ZTC 2~-5 S~HP 05-02-55 2U-6 SBHP & TCL 05-0 3-85 2U-7 SBHP P~ PROD 05-04-85 2u-s SSHP ~ ZTC. 05-04-55 2U-'9 PRESSU~ TEST 05-27-85 2U-10 BHP SAMPLE 06-05-85 2U-16 'A'SD FLUID ID 06-09-85 2U-16 PBU 06-07-85 2V-10 BHP & ETC. 05-17-85 2V-11 ' STATIC 05-12-85 2V-11 STATIC 05-23-85 2W-13 'C'SD ACID STIM 05-20-85 2X-i2 'C'SD ACID JOB 05-12-85 2Z-2 E/LINE FLUID ID 05-03-85 5,-,-~-£: 06-19-85 TP~NSMIT~AL NO: 5230 PAGE 2 OF 2 ING ITEMS. PLEASE ACKNOWLEDGE OF THIS TRANSMITTAL. CAMCO BAKER DOWELL OTIS OTIS OTIS OTIS CAMCO OTIS OTIS CAMCO OTIS OTIS OTIS CAMCO CAMCO CAMCO BAKER/cAMco OTIS OTIS OTIS OTIS OTIS OTIS OTIS DOWELL DOWELL OTIS/CAMCO RECEIPT ACKNOWLEDGED: BPAE* B. CURRIER C HE VRON * D & M DRILLING L. JOHNSTON MOBIL * NSK CLERK i ./ DATE DISTRIBUTION' W. PASHER EXXON PHILLIPS OIL* J. RATHMELL STATE OF ALASKA SOHIO* UNION* K.TULIN/VAULT ARCO Aiaska, inc. Pos1 Office 5oz 100360 Anchorag6. Alaska 99510-0360 7eiephone 907 276 1215 June 24, 1985 ~4r. C. V. Chatterton, Chairman Alaska Oil-and Gas Conservation Commission 3001 Porcupine Drive Anchorage; AK 99501 Dear Mr. Chatterton' Attached in duplicate are subsequent notices following wells at the Kuparuk River Field' Well Action Date Performed 1A-3 Fracture 5/30/85 1A-4 Fracture 6/1/85 1C-5 Perforate 4/27/85 1E-3 Perforate 3 / 28/85 1E-3 Fracture 4/3/85 1E-4 Perforate 4/20/85 1E-4 Fracture 5/7/85 1E-1 6 Fracture 4/1 4/85 1E-1 7 Fracture 3 / 26/85 1 E-29 Fracture 4/12 / 85 1F-1 6 Perforate 4/11 /85 1F-1 6 Fracture 4/1 5/85 1G-1 Fracture 4/1/85 1L-15 Fracture 3/31/85 1L-16 Fracture 3/31 /85 1Q-1 Fracture 5/31 /85 1Q-4 Acidi ze 5/1 7/85 1Q-4 Fracture 5/31/85 1Q-5 Fracture 5/1/85 1Q-6 Fracture 4 / 1 9 / 85 1Q-7 Fracture 4/27/85 1Q-7 Acidi ze 5/26/85 2C-1 0 Perforate 4/21/85 2D-3 Acidize 5/11 /85 2W-1 3 Ac idi ze 5/20/85 2X-1 2 Acidi ze 5 / 12/85 on the If you have any questions, please call me at 263-4212. T. M Drumm Kuparuk Operations Coordinator TMD/kmc Attachment (Duplicate) RECEi\,:ED Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COI~,MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator ARCO ALASKA, INC. 3. Address P. O. BOX 100360, ANCHORAGE, ALASKA 99510 4. Location of Well SURFACE LOCATION: TllN, R9E, UM 65' FNL, 717' FEL, SEC. 26, BOTTOMHOLE LOCATION: 23, TllN, R9E, 5. Elevation in feet (indicate KB, DF, etc.) 127 ' (RKB) 1071' FNL, 1357' FEL, SEC. UM 6. Lease Designation and Serial No. ADL 25653 7. Permit No. 84-153 8. APl Number 50- 029-21178 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 2D-3 11. Field and Pool KUPARUK RIVER FIELD KU'PARUK RIVER OIL POOL 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stim u lation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion,) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On May 11, 1985, the "C" sands of Kuparuk well 2D-3 were acidized to improve production. The treatment consisted of 50 BBLS of 12% HCL. Diesel was used for flushing and nitrogen to aid well cleanup. Prior to starting job, equipment was pressure tested to 4,000 psi. RECEIVED JUN 2 6 ]985 Alaska 0il & Bas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. KUPARUK Signed ~,, ~---~'~ ~,~-'~"~-~ Title OPERATIONS COORDINATOR The space below for Commission use 6/18/85 " ; ,/;_' ,1 Conditions of Approval, if any: By Order of Approved by. COMMISSIONER the Commission Date Form 10403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate · ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 1, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation 3001 Porcupine Drive Anchorage, AK 99501 Commission Dear Mr. Chatterton: Attached is our notice of intention to acidize Kuparuk well 2D-3. If you have any questions, please call me at 263-4253. field /kmc Attachment (In Triplicate) Coordinator RECEIVED MAY 0 £ 1985 Alaska Ui~ & Uas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO~wMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I~ 2. Name of Operator 7. Permit No. ARCO ALASKA, ]:NC. 84-153 3. Address 8. APl Number P. 0. BOX 100360, ANCHORAGE, ALASKA 99510 50-029-21178 OTHER [] 4. Location of Well SURFACE LOCATION' 65' FNL, T11N, R9E, UM 717' FEL, SEC. 26, BOTTOMHOLE LOCATION' 1071' FNL, 1357' FEL, SEC. 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 2D-3 1 1. Field and Pool 23, T11N, R9E, UM KUPARUK RIVER 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kg PARU K R I V ER 127' (RKB) I ADL 25653 POOl 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other X~] Pulling Tubing [] FIELD OIL (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is proposed that the "C" sand in Kuparuk well 2D-3 be acidized to improve production. The treatment will consist of 12% HCL acid. The acid is to be pumped by coil tubing nitrogen to aid well cleanup. Prior to be pressure tested to 4000 psi. unit and displaced with starting work, equipment will Fluid Requirements- 12% HCL 50 BBLS ANTICIPATED START DATE- May 6, 1985 RECEIVED ~AY 0 2 ]985 Alaska b, ~ was Cons. Comrn Anchorage Sign '"Title OPERATIONS The space belo~/f(~r Commission us/~ COORDINATOR Date' 5/1/85 Conditions of Approval, if any: Approved by. Approved Cop~ R®turne6 By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 /~pril 23, 1985 Mr. C. V. Chatterton Commi s s i one r 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' 2B-4 2B-15 2B-16 2D-3 If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU6/L12 Enclosures RECEIVED APR 2 5 1985 Alaska 0il & Gas Cons. C0mmJssi0r~ Anchorage ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany ~----' STATE OF ALASKA ----, ALASKA O,~-. AND GAS CONSERVATION CO JllSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL I~X GAs [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-153 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- ' 029-21178 4. Location of well at surface 9. Unit or Lease Name 65' FNL, 717' FEL, 5ec.26, T11N, RgE, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 1421' FNL, 1256' FEL, Se¢.23, TllN, RgE, UM 2D-3 At Total Depth 11. Field and Pool 1077' FNL, 1272' FEL, Sec.23, TllN, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i l Pool 127' RKBI ADL 25653 ALK 2579 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore J 16. No. of Completions 10/01/84 10/07/84 11/26/84J N/A feet MSL] 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 7923'MD,6286'TVD 7825'MD,6215'TVD YES I~[X NO []I 1949 feet MD 1500' (Approx) 22. Type Electric or Other Logs Run DIL/SFL/GR, Density/GE, Cal, Gyro, CBL/VDL/GR/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 117' 24" 204 ax Cold Set; II 9-5/8" 36.0# J-55 Surf 3630' 12-1/4" 850 sx AS III & 500 sx Class G 7" 26.0# J-55 Surf 7907' 8-1/2" 481 sx Class G & 250 s~ AS 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) 7446' - 7450' 7559' - 7561' 3-1/2" 7558' 7543' & 7331' 7453' - 7455' 7589' - 7592' w/1 spf 7459' - 7461 ' 7595t - 7597' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 7465' - 7470' w/12 spf, 120° phasing DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7478' - 7481' See attached Adde3dum, del;ed 4/2/85. 7492' - 7495' 7601' - 7603r w/1 spf 7501' - 7504' 7611' - 7616' 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 TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED OILoBBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None Form 10-407 GRUS/WC52 Submit in duplicate Rev. 7-1-8O CONTINUED ON REVERSE SIDE .~,//,.~, ~.~.-- 29. -.- 30.- · · . -"- ~ . . -~ .-.. · GEOLOGIC MARKERS : FORMATI'ON T'ESTS 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 7418' 5917' N/A Base Upper Sand 7480' 5963' Top Lower Sand 7540' 6007' Base Lower Sand 7700' 6124' 31. LIST OF ATTACHMENTS Add~nd~,m 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed_ )(--,) ~ 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- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". I~nrrn I N-Z~N'7 ADDENDUM WELL: 10/12/84 11/05/84 2/08/84 2/11/85 3/15/85 2D-3 Arctic Pak w/41.5 bbls AS I, followed by 56 bbls Arctic Pak. RU & rn CBL/VDL/GR/CCL/gage ring, log f/7770'-6448'. Calibrate gyro, rn gyro 7780' back to surf. RD, secure well. Pmp 15 bbls diesel @ 2600 psi/5 BPM. Pmp acid. Press up to 3400 psi, pmp 2000 gals, followed by 67 bbls diesel flush. Flowing well to tanks f/cln up. Flow well f/cln up. Frac well in 7 stages w/232 bbls gelled diesel, 1008# of 100 mesh & 9954# of 20/40 mesh. D r iL% {~- S up e-~ int end en t z ZDate ARCO Alaska, In,/- Post_ Offic~ _'ox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 · .. ,'-'~ F;-: t:: --"] ::'~ L_ ¢i I( ~::~, 7[ i') C' .. & '!"¥ i'-~: !:;,' 1:7 C: (3 F;: I) .;7 C: I... I!!: !::' I( ~'::'~ 'i" C:: .... 'i i 'i '.:.!'-' fi; F:'., 0 , :(-::(:)X l J-""~ ~'-~ C: !"I ".':.'.'-I':..' ~'-'-': C;- l'Z, ¢'~ !<: 9 "? 5: i ':'-." .... 'i '.':::' 7 ARCO Alaska, Ir Post OffiCe 8ox' 360 Anchorage, Alaska 99510 Telephone 907 277 5637 ,..- : '! i; .. F' T:: !...l () 'f' .I. ,?;' c, ~.:'l I / ' ~-.'.-~ ' ..-:. ~..~: _L. f i -I" ]i ,!'~ ~ !..' ... :" -':- ;- I ~"~ -. 2 }:: I--I F" . . O 'f' :[/._7 .!i-',..,'"-:' ,~--! : ~::' !'l.. [' ] ,~' ,!'..': );':: i"! 9 0 T :[ .!'..." :!:-" .'(.'): l'-i F:'/' ' ,':'-'~. ' .? f:", i"! :0 _.. '/:'.' ' ,? .,'-'",, i'-'!)7, F:' l:'-: !..I ./ I::, 1'7 r-;.' [:" ' -" i .... ........ ~'.-'~ :~:' i.'~i ~'d .'(.:, ' ,---':i ' ,?? A .H D ,,'::'-.,. C: Z[ R' )-7 ,:':~ I.. L. (Z) t..I 'i" ;C, C: !/I ..r..;. !... I... F:'l ! 11' f) T T", ~::','; I::' r'.: I--I "-:.' - ~ ...... , ......-'.... ~ ~._,, '- ........ F:' I... !..! ;[ ~.) :i: n () f' .[ ,!;' F:' I... U ]Z .... f', T,. D L-'-.' H ;.'7 .:-'-.'; ;,.'-;,' !-i F:' () f' :[ ,~;' F:' E!: r~ F" ' ,-.':-~ ' ,S' ~'-'~ i'-~ i) ,':? ~q i': 'r ;'". :1: ;Z '[ ~-.! G c, l:: F' (3 F:.' ...... :.: .. i -. ,... r'l i'" ¢,- ,::.r,.F: r., r;. ,..-' T.',hli'J :..'! ,i':... :.. , '' ' F-I'~: ,::"~ r":.. F;..' IZ;' ~-'": 0... 1::_:. 'f' I',' :':"~ I... !... :I: )?':".., ,.,:' r ",', ,.. ;..~r .... l--i ;' )::; f;' ,'-:~ (..If I (.7. .... ' ^ -' . .... ,.. f ,-,?,U '"' ~"i " .... ,'-- "r' IE,H F' ' .... ~ ;!';"f' r I::-: .,'--i f-: (, ;"': C I:"i'~l::' I::'r'":i .... i F.:.I'-I~-- , :... II ', I'-! =..- ...... .,.'r ..,""' I F' . ~.". F."-' ,ix, ,.,"'"' ,,,.' ~;,,.~ T E!: .??" 'f' .f".. i"i ..... !..J ii"' ,...' ,...' F: F:,: ¢i '-'c-r-I',,-';r',';- -' ,',, ,:", '~.- i t i" ,' "' I'"- i i '-' I ~ .,., L. . . .......... r--! !._! t". F' i:, ' .o ................................................................... ~ .................. t:'/:, I !::.: .............. ~ ............................. 1' '-; "J ' i-: F::-r [. i_ ]Z ,,r.. ,,, F:, .,r,....~._- ! _~ ;Z F. .... ,. I"-.' :' -..... ,.'.'. · I-4 I ,.'. .t. ll,.l~ -' I"tl .-i i,.~;i. I"1 ; '~ ''~ · - .... t . 4. "' /~n,¢ T;~r;,~:'l~ · " ' ' i,";~ [ ...."'['f?i"J I::".':{ Y Fii;.! !-:'1..): I.I U"~" 1 ' ; .....,_J .."', I ~,.': .... - ~"i (;! .S :[ !... ':,.' 'i F:' !4 ]. I... I. T F:' ,!~' I;Z) :1;! -:,,'. i !..! i".! ]: (')~"~ ":-." i i---!.?"f C:'Ll!!Zf::if ,.I .. I:;:i:"-,"I"I-IH[!]L.I... *-'- II< ~ 'FUI... ]] i'-~./'"¢;:'.'~U'L. T o. Al]CO Ala$~,a Ir~c ,S a gubs,O~&rf of ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 26, 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' 2D-2 2D-3 2D-4 If you have any.questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU5/L56 Enclosures RECEIVED MAR 2 7 1985 ~aska 011 & Gas Cons. C.om~i.-~i°n 'Armhorage STATE OF ALASKA -- ALASKA L ._ AND GAS CONSERVATION CO. AISSION WELL COMI LETION OR RECOMla'LETION REI ORT AND LOO 1. Status of Well Classification of Service Well OIL [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-153 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21178 4. Location of well at surface 9. Unit or Lease Name 65' FNL, 717' FEL, Sec.26, TllN, RgE, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1421' FNL, 1256' FEL, Sec.23, TllN, R9E, UM 2D-3 At Total Depth 11. Field and Pool 1077' FNL, 1272' FEL, Sec.23, T11N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Poo] 127' RKBJ ADL 25653 ALK 2579 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 10/01/84 10/07/84 11/26/84I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 7923'MD,G286'TVD 7825'MD,6215'TVD YES [] NO []I 1949 feet MD 1500' (Approx) 22. Type Electric or Other Logs Run DIL/SFL/GR, Density/GE, Cal, Gyro, CBL/VDL/GR/CCL '23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 117' 24" 204 sx Cold $¢1; II 9-5/8" 36.0# J-55 Surf 3630' 12-1/4" 850 sx AS Ill & 500 sx Class G 7" 26.0# J-55 Surf 7907' 8-1/2" 481 sx Class G & 250 s~ AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, siz~ and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7446' - 7450"~ 7559' - 7561") ._ 3-1/2" 7558' 7543' & 7331' 7453' 7455'J-- 7589' - 7592'1 w/1 spf 7459' 7461 '( 7595' - 7597' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7465' 7470'( w/12 spf, 120° p~hasing DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL usED 7478' 7481'\'~ See attached Adder~dum, 7492' 7495'~ 7601' - 7603'[ w/1 spf 7501' 7504'/ 7611' - 7616' 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 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,~, OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA None IVlA 2 7 1985 ',aJaska .Oil & Gas Cons. Commi~ion "--, Form 10-407 GRUS/WC28 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE " " ':':i GEoEo~icMARi~'i~RS' ~..."'~:. ¢ i:' i: :;:: :': !-;:-i':': -' · ' ':;FORM,~,T'ION'T~STS NAME Include interval tested, pressure data, all fluids recovered and graviiy, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 7418' 5917' N/A Base Upper Sand 7480' 5963' Top Lower Sand 7540' 6007' Base Lower Sand 7700' 6124' .. 31. LIST OF ATTACHMENTS ArJrlCn rt~,rn 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~~ ~/)]J~..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- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-4137 ADDENDUM WELL: 10/12/84 11/05/84 2/08/84 2/11/85 2D-3 Arctic Pak w/41.5 bbls AS I, followed by 56 bbls Arctic Pak. RU & rn CBL/VDL/GR/CCL/gage ring, log f/7770'-6448'. Calibrate gyro, rn gyro 7780' back to surf. RD, secure well. Pmp 15 bbls diesel @ 2600 psi/5 BPM. Pmp acid. Press up to 3400 psi, pmp 2000 gals, followed by 67 bbls diesel flush. Flowing well to tanks f/cln up. Flow well f/cln up. RECEIVED MAR 2 ? 1985 ~aska Oil & Gas Co.s. Commission ;Anchorage D~~rill~i'ntendent sJi ARCO Alaska, Inc. ~ Post Office Bo.. ,00360 Anchorage, Alaska 99510 Telephone 907 276 1215 February 27, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2D-3 Dear Mr. Chatterton' Enclosed is an addendum to the 2D-3 Well History to include with the Well Completion Report dated 02/12/85. If you have any questions, please call me at 263-4944. Sincerely, . Gruber Associate Engineer JG/tw GRU4/L202 Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. ''~ Post Office B~ 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 February !3, 1985 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2D-3 Dear Mr. Chatterton' Enclosed are the Well Completion Report and gyroscopic survey for the subject well. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU4/L145 Enclosures RECEIVED F E 1 5 1985 Alaska Oil &~Gas Cons. '~nchorago commission ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany :, ~"-' STATE OF ALASKA ~-" ALASKA., , AND GAS CONSERVATION CC IISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL I~(x GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-153 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21178 4. Location of well at surface 9. Unit or Lease Name 65' FNL, 717' FEL, Sec.26, T11N, RgE, UN ~ O ~: . :1~, .~_; ~ ~ ~,.~ S ~ Kuparuk River Unit At Top Producing Interval i V';_~'.i i~; 10. Well Number 1421' FNL, 1256' FEL, Sec.23, T11N, RgE, UM i~,,._~ ~ '. 2D-3 At Total Depth i~. ,. ~J 11. Field and Pool 1077' FNL, 1'272' FEL, 5ec.23, TllN, R9E, UN ~ ...... ~ ............. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6, Lease Designation and Serial No. Kuparuk River 0i l Pool 127' RKBI ADL 25653 ALK 2579 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. J 15. Water Depth, if offshore 16. No. of Completions 10/01/84 10/07/84 11/26/84I N/A feet MSL 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+I-VD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 7923'MD,6286'TVD 7825'MD,6215'TVD YES [] NO []I 1949 feet MD 1500' (Approx) 22. Type Electric or Other Logs Run DIL/SFL/GR, Density/GR, Cal, Gyro, CBL/VDL/GR/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 117' 24" 204 sx Cold Set II 9-5/8" 36.0# J-55 Surf 3630' 12-1/4" 850 sx AS Ill & 500 sx Class G 7" 26.0# J-55 Surf 7907' 8-1/2" 481 sx Class G & 250 s:( AS 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) 7446' - 7450' 3-1/2" 7558' 7543' & 7331' 7453' - 7455' 7459' - 7461' 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. 7465' - 7470' w/12 spf, 120° phasing DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 7478' - 7481' N/A 7492' - 7495' 7501' - 7504' 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED.k OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA BriefNonedeScription of lithology, porosity, fractures,, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 GRUI/WC06 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ': ::' i-..':- ' :~.; :_:, ;_ ~:j~oi.'_:-0Gi-~;I~,~'i~i~Fi-~ ~.:'?-":;:.~ !- '?. ? ;.~: :--:'~'~,~.! 7: ;:: :_/-;iF;-:'-~': ::'-:_'~,-;: ~: ~¢oRMAT'iON'TES~~ .:~ ' ": ,. 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 7418' 5917' N/A ~se Upper Sand 7480' 5963' Top Lower Sand 7540' 6007' Base Lower Sand 7700' 6124' . , ,.. 31. LIST OF ATTACHMENTS We~ H~s~ory (~n~,~d~ng ~dde~dum). Gyroscopic Survey (~ ~op~es) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge /I 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 supplemenl~al 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: 10/12/84 2D-3 Arctic Pak w/41.5 bbls AS I, followed by 56 bbls Arctic Pak. ~A~ 0 8 AJaska Oil & 6as Cot~s. (Jomrnissiorl Anchorage Drilli~ Su'p~rintendent ARCO Oil and Gas Company Daily Well History-Final Report In$1~uctions: 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 required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the enlire operation if space is available. Accounting cost center code District ICounty or Parish I State Alaska North Slope Borough Alaska Field ILease or Unit IWell no. Kuparuk River I Completion 2D~3 Auth. or W.O. no. ~Title AFE 802948 I ADL #25658 Roll'n 4 Operator [ AR.Co. ARCO Alaska, Inc. Spudded or W.O. begun J Date I Complete Date and depth Complete record for each day reported as of 8:00 a.m. 11/24/84 11/25/84 11/26/84 API 50-029-21178 W.I. J'l'otal number of wells (active or inactive) on this Icost center prior to plugging and 56.24% labandonment of this well I I Hour ' I Prior status if a W.O. 11/24/84 J 1600 Hrs. 7" @ 7907' 7825' PBTD, POOH w/gun (run #3) Accept rig @ 1600 hrs, 11/24/84. ND tree, NU &tst BOPE to 3000 psi. RU DA, perf 5", 12 SPF, 120° phasing f/7465'-7470' & 7478'-7481'. Perf gun #2, 7446'-7450', 7453'-7455', 7459'-7461'. RIH w/gun #3, misfire, POOH. 7" @ 7907' 7825' PBTD, RIH w/3½" tbg Repair gun #3, RIH, perf 7492'-7495', 7501'-7504' @ 5", 12 SPF. Rn 6" GR/JB f/7786'-surf. RIH w/Bkr FB-1, set @ 7523' WLM, RD DA. MU & RIH w/3½" CA. 7" @ 7907' 7825' PBTD, RR Rn 239 jts, 3½", J-55 EUE 8RD IPC tbg. Flr hand dropped screwdriver dnhole. Sting into FB-1 pkr, press tst to tst seal engagement. Did not shut pmp dn in time, set pkr. Approx 5-10K set dn on btm seals. Shear off PBR, space out, lnd on tbg hgt. Set BPV. ND BOPE, NU &tst tree to 5000 psi. Tst tbg to 2500 psi. Tst top pkr to 2500 psi. Displ w/30 bbls diesel, followed by crude oil. Tst orifice vlv to 2000 psi; OK. Tst SSSV; OK. Bled press to 3000 psi. Instl BPV. RR @ 0030 hrs, 11/26/84. Bkr FB-1Pkr @ 7542.84' - TT @ 7558.23' - Bkr FHL Pkr @ 7330.95' - SSSV @ 1948.84' Old TD New TD PB Depth 7825' Released rig Date Kind of rig 0030 Hrs. 11/26/84 ~ Rotary Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Oil Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production 'viC," "~ ~ 011 on test Gas per dayG ,i Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date '~'~ corrected The above is correct Signature J Date I Title /~]~' ~.~.~.,~...~ 12/14/84 Drilling Superintendent ForSorm prepar-at-io~-a~d distribution, see Procedures Manu.l~, Section 10, Drilling, Pages 86 and 87. ADDENDUM WELL: 10/12/84 11/o5/84 2D-3 Arctic Pak w/41.5 bbls AS I, followed by 56 bbls Arctic Pak. RU & rn CBL/VDL/GR/CCL/gage ring, log f/7770'-6448'. Calibrate gyro, rn gyro 7780' back to surf. RD, secure well. Drillin~ Superintendent $ UB-$ URFA CE DIRECTIONAL SURVEY F-~ UIDANCE F~ONTINUOUS F'~ OOL Company Well Name Field/Location ATLANTIC RICHFI ELD COMPANY i i ' i i 2D-3 (65' FNL, 717' FEL~ S26~ T11N~ R~E~ Lltl) =, , KUPARUK. NORTH SL..,qP~, ALASKA _' _ Job Reference No. 69804 Loq{3ed By: MCBRIDE RECEIVED .F E~ 1 5 !~85 Alaska Oil & Gas Cons. Commission Anchorage Date DEC- 04-1984 Cern ~puted By: STEVENS GC? DIRECTIONAL SURVEY CUSTOMER LISTING FOR A){CO AbASKA, KUPARUK NORTH SLOPE, ALASKA SURVEY DATE: 4-NOV'-U4 Ea(;iNEERt ~cBRIDE METHODS OF CnMPUTATION TOOL LOCATION~ TANGENTIAL- averaged deviation and azimuth INTERP(1LATION: LINEAR V~iRTiCAL SECTION: HORIZ, DIST. PROJECT,iD ()NTL) A TARGb2T AZIMUTH ARC(.] ALA,SKA, INC,, 2[9-3 KUPARt,IK NC)RTIi ~I, OPE~, ALASKA COMPLJTATION OA'I'E~ 4-DEC-84 PAGE 1 DATE UF SURVEYI 4-NOV-H4 KEI,,bY BUSHING EbI~,:VATION~, 12'1,00 Ff " 100 200 300 400 500 600 700 8OO 900 O0 -27 O0 73 O0 1.73 O0 273 O0 373 O0 473 O0 573 O0 673 O0 773 0 0 N 0 0 E O0 0 7 $ 62 59 W O0 0 6 S 64 25 W O0 0 0 $ 62 13 E O0 0 4 N 34 55 E O0 0 8 N 18 17 E O0 0 7 N 25 44 E O0 0 4 N 8 11 E O0 0 3 N 35 50 E 00 0 ! S 29 0 E 1000 O0 1000 O0 1100 1200 1300 1400 500 60O 1700 1800 1900 873 O0 O0 1099 O0 1199 O0 1298 O0 1,395 O0 1491 O0 1585 oO 1675 O0 1764 O0 1852 95 972' 0 23 N 3'1 9 W ,95 3 10 N 22 41 W 56 1072,5b 6 45 N 19 10 W 37 1171.37 10 38 N 1.7 55 W 1 1364,71 18 40 N 12 42 W I0 1458,20 22 57 N 15 8 W 93 ·1548.93 26 23 N 15 27 W 78 1637,78 28 9 N 15 37 W 17 1725,i7 29 59 N 1,5 1 W 0 75 3!26 I1 68 26 69 48,15 76 95 112~20 153,89 199,41 247,67 O0 2022 1895,04 33 50 2200 O0 2103 91 1976,91 36 15 2300 O0 2183,36 2056,36 38 25 2400 O0 2260,56 2133,56 40 39 2500 O0 2335.01 2208,01' 43 3 2600 O0 2406,85 2279,85 45 1 2700 O0 2476,99 2349,99 45 31 2800 O0 2547,20 2420,20 45 18 2900:00 2617.64 2490,64 45 7 N 1,1 32 w 298 71 N 13 59 W 352:59 N 13 6 W 409,77 N 12 27 W 470 32 N 12 4 w 533~74 N 11 37 W 600,37 PI 11 5 W 669,84 N 10 42 W 741,05 N 10 24 W 812,22 N 10 15 W 883,17 300o,00 2688,34 25ol 34 44 51. 3100'00 2759,26 2632:26 44 59 2829,82 45 3200 O0 2702,82 11 3300~00 2900 28 2773,28 45 12 3400 00 2970:76 2843,76 45 8 3500~00 3041,43 2914,43 44 52 3600,00 3112.47 2985,47 44 38 3700,00 3184.14 3057,14 43 57 3800.00 3256 41 3129.41 43 22 3900.00 3329:46 3202,46 42 57 N 10 27 W 953,85 N 10 29 W 1024,31 N 10 23 W 1095,13 N 10 11 W 1166,06 N 10 4 W 1236,97 N 9 56 W 1307.69 N 9 52 W 1378,06 N 9 59 W 1447.77 N 9 58 W 1516,86 N 9 57 W 1585,13 0,00 lO0,O0 200,00 300 O0 400 O0 5OO O0 600 O0 700 O0 800 O0 900 O0 000 -127 O0 0,00 -0,04 -0 02 -0 06 -0 03 0 14 0 35 0 51 d 62 0 63 TRUE SUB-SEA COURSE EASURED VERTICAl., VERTICAL DEVIATION AZIMUTh DEPTH DEPTH DEPTH DEG VERTICAL DOGLEG RECTANGULAN COURDINATES HORIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST AZIMUTH FEET DEG/IO0 FEET FEET FEET DEL BIN 0 O0 0 31 0 23 0 05 0 08 0 09 0 02 0 13 0 04 0 05 1,13 3,71 4 02 3 15 4 55 3 82 4 17 2 O4 1,92 1,89 ! 88 2~31 2 35 '1~78 2 54 2 31 ~4 0 10 0~40 o 42 0 58 0 12 0 46 0 20 0 61 0 27 0 60 0 94 0:55 0 O0 N 0045 0065 0 11 S 0 07 S 0 N 0 51 N 0 62 N 0 64 N 0,00 N 0 0 E 0,07 8 48 19 ~ 0,31 $ 78 31 ~, 0,35 S 72 29 W 0 31 5 76 34 W 0 24 ~ 63 33 W 0 36 ~ 20 42 W 0 51 N 5 5 W 0 62 N 0 46 W 064 iV 3 53 E 0 76 N 3 10 N 11 18 N 25 62 N 46 47 N 74 68 N 109 03 N 149 52 N 193 70 N 240 58 N 0 04 w 1 4 9 1.4 20 29 40 52 65 0 11 W 27 76 w 48 86 w 77 52 w 112 b6 W 154 99 W 200 83 W 249 I ~ 3 7 ~ ~ ~q 23 8 ~ 94 N 20 30 W 19 ~ 19 34 W 76 N 17 36 W 54 ~v 15 36 W 95 a 15 9 w 95 N 15 12 w 82 ~ .15 18 W 42 N 15 18 w 290 22 N 342 70 N 398 50 N 105 519 N 1 653, N 721, N 79 ,$4 N 186 863,18 N 199 78.92 W 300,76 ~ 15 12 ~ 92 31 W 354,91 ~ 15 4 ~ 77 W 412,29 N 14 51 w 15 W 472,97 N 14 35 W b8 W 536,49 N 14 19 w 38 W 603,18 N 14 2 W 1W 672,67 N 13 46 w 8 W 743,86 N 13 29 W 57 W 814,98 h 13 14 W 28 W 885,88 ~ 13 0 W 932,74 N 211 98 W 95b,53 N 12 48 W 1002,06 N 224:84 W 1026,98 h 12 38 ~ 1071,75 N 237,68 W 1097,79 N 12 30 k 1141,57 N 250,36 W 1168,70 N 12 22. ~ 1211.41N 262,83 W 1239,59 ii 12 14 w N 275,12 W 1310,28 N 12 '7 w 1281,07 1350,41 N 287,21 W 1380,62 N 12 0 ~ 1419.10 N 299,24 W 1450,31 h 11 54 W 148';,17 N 311,22 W 1519,39 m 11 49 w 1554,42 N 323,09 W 1587,64 N 11 44 w ENGINEER] McBRIDE INTERPOLATED VALUES FOa EVEN 100 FEET OF MEAfiURED DEPTH ARCO AbASKA~ T~C, 2D-3 KUPAEIJE NOE~H ~[,LiPE~ AbA$~A TRUE SUB-SEA EASURED VERTICAl, VER'fICAb DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG COMPUTATION OA'£E; 4-0EC=84 PAGE DATE OF SURVEY{ 4-NOV-Bi KELLY BUSHING ELEVATION{ ENGINEER{ ~'cBRIDg INTERPOLATED VALUES FOR EVEN 100 FEET OF MEAMUREO DEPTH VERTICAb DOGhEG RECTANGUbAR COORDINATES HORIZ, DEPARTURE 8ECTXON SEVERITY NORTH/8OUTH EAST/WEST [)IST, AZIMUTIt FEET DEG/100 FEET FEET FEET DEG 4000 O0 3402,54 3275,54 43 6 4100 O0 3475,45 3348,45 43 12 4200 O0 3548,35 3421.35 43 8 4300 O0 3621'22 3494,22 43 11 4700 O0 3913,47 3786 47 42 53 4800 O0 3985,80 3859 80 42 43 4900 O0 4060,51 3933 51 42 21 5000,00 4134 51 4007,51 42 12 5100,00 4208 20 4081.20 42 46 5200,00 4281 38 4154,38 43 4 5300 O0 4354 59 4227,59 42 53 5400 O0 4427 96 4300,96 42 42 5500 O0 4501 58 4374 58 42 25 5600 O0 4575 u5 4448 65 41 58 5700 O0 4550 02 4523 02 41 55 800,00 4724 28 4597 28 42 9 .900,00 4797'85 4670 85 43 6 6000,00 4870,52 4743,52 43 27 6100,00 4943,20 4816 20 43 16 6200,00 5016,22 4889:~2 42 47 6300,00 5089,94 4952,94 42 27 6400,00 5163.42 5036,42 43 4 6500 O0 5235,26 5108,26 44 33 6600' 6700,00 5306 54 5179,54. 44 15 .00 5378:50 5251.'50 43 28 6800.00 5451,75 5324.75 42 27 6900,00 5525.05 5398,65 42 0 7000,00 5500,70 5473,70 41 10 7100,00 5676,31 5549,31 40 28 7200,00 5752,77 5625,77 40 35 7300,00 5828.13 5701,13 41 9 7400 O0 5903.23 57'76.23 41 JO 7500:00 5977,47~5~50,47 42 24 7600.00 6050.90--5923,90 42 57 7700,00 6123.96 5996,96 43 16 7800,00 6196 58 6069,58 43 28 7900.00 6269:14 614~,14 43 28 N 10 6 W 1653 N 10 5 W 172 1 N 9 50 W 1790 N 9 51 W 1858 N 9 6 w 19 N 8 2 W 19~ N 8 7 W 2063 N 8 18 W 2131 N 8 30 w 2199 N 8 28 w 2267 36 21 67 11 35 64 76 75 33 N 8 43 w 2334 59 N 8 14 W 2402 N 6 18 W 2470 N 6 10 W 2538 N 6 15 W 2606 N 6 18 W 2673 N 6 22 W 2741 N 6 23 W 2807 N 5 1W 2874 N 3 15 W 2942 19 32 39 27 90 03 83 72 25 N 0 45 w 3010 42 N 0 50 w 3078 N 0 53 W 3146 N 0 29 W 3213 N 0 11E 3280 N 0 18 W 3349 N 1 45 w 3418 N 1 47 w 3487 N I 58 w 3555 N 1 55 w 3622 48 20 15 23 02 59 53 15 08 N 2 5 W 3687,74 N 2 10 W 3752,78 N 2 52 W 3816,84 N 4 31W 3882,]8 N 3 38 W 3948 22 N 3 15 W 4014~93 N 2 57 W ~082'52 N 2 56 W 4150~49 N 2 5 W 4218.85 N 2 5 w 4287 ,23 0,28 0,27 0,~3 0.11 1'89 0 9 0 19 0 49 0 48 0 36 I 07 0 47 0 37 0 19 0 43 0,15 0,94 1,46 1,97 0,47 0,49 0,66 '0 83 I 66 1 16 0 8! 0 54 0 62 2 41 0 55 0 79 3 2O 0 68 2 63 0 95 0 39 0 75 0 O0 0 O0 1621 04 N 334,97 W 1.655 1689 02 N 347,00 h 1724 1'150 43 N 358,88 W 1792 1823 90 N 370 ~0 W 1861 1891 37 N 382 13 W 1929 1958 90 N 391 99 W 1997 2026 51 N 40 9 w 2065 2093 94 N 411 I W 2133 2 28 03 N 431,26 W 127,O0 FT 2294 53 N 44 2361 ~ NN 451 2428 2496 2564 2631 2698 2764 2831 2898 459 N 471 54 N 481 31 N 489 73 N 496 37 N 503 92 N 508 38 W 2330,59 ~ 10 53 W 49 W 2404'14 h 10 49 ~ 90 W 2472,15 N 10 43 W 8 W 2540 06 N 10 35 ~ 4 W 2607 81 N 10 29 W 5 W 2675 31 N 10 ~2 W iSW 32 1.0 6 2742 w 8 w 2809 03 h 10 11 w 57 W 2875 80 N 10 5 W 41W 2943 17 N 9 56 ~ 2967 58 N 510,20 W 301! 3036 26 N 511,16 W 307 8 3104 58 N 512,20 W 3146 3172 15 N 513,09 W 3213 3239 96 N 513,17 W 3280 3309 53 N 513,05 W 3349 3379 64 N 514,63 k 3418 3449 04 N 516,69 k 3487 3517 08 N 518,91 W 3555 3584 41 N 521,27 W 3622 12 ~ 9 45 ~ 99 N 9 33 W 65 N 9 22 W 37 h 9 11 W 06 h 8 48 ~ 60 k 8 39 w 53 h 8 31 w 16 k 8 23 w 11 N 8 lU w 3650,46 N 523,56 W 3087,81 N 8 9 W 3715,86 N 526,00 W 3752,90 ~ 8 3 W 3780,26 N 528,51 W 3817,02 N 7 57 W 3845,82 N 533,19 w 3882,60 N 7 53 w 3911 07 N 538 06 W 3948,50 N 7 49 w 3978 56 N 541~87 ~ 4015,29 N 7 45 w 4046 33 N 545~54 W 4082,95 N 7 40 W 4114 52 N 549,23 W 4151,01 N 7 30 W 4183 19 N 552,35 W 4219,50 N 7 31 W 425195 N 554,86 W 4288,00 N 7 26 W CO~iPOTATiOI4 O ~'I'E ~; PAGE 3 ARCO ALASKA, 'INC. 2[).-, 3 [~UPARUK NO~TH ~l, OP£, A6AS~(A DATE OF SURVEY: 4-NOV-B4 KEL6Y BUSHING EbEVA~IUN~ 127,00 F~ INTF, RPObATED VALUE5 FOH b~VEN 100 FEEl' OF MEALURED DEPTH TRUE SUB-SEA COURSE EA$I,IRED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE SECTION SEVERITY NORTH/8OUTH ~jAST/WEST DIST, AZIMUTH FEET DEG/100 FEET FEET FgET DEG 7923,00 628b,83 6158,83 43 28 N 2 5 W 4302.96 0,00 4267,76 N 555,44 W 4303,76 N 7 24 W ARCO ALA~KA~ TNC, 2D-3 NO~Ti"I SLOPE~ ALASKA COP1PUTATION DA'rE{ 4,,DgC-84 PAGE 4 DATE OF SURVEY: 4-NOV-84 KILLY BUSHING £LEVA~ION~ 127,00 FT ENGINEER: HCBRIDE INTEHPOLATED VALUES FOA EVEN 1000 FEET OF HEASURED DEPT ~RUE SUB-SEA COURSE lEAS[IRED VERTICAl, VERTICAL DEVIATION AZINUTH DEPTH DEPTH DEP'Y'H DEG A~N DEG ~I~ 0 O0 0,00 -127,00 0 0 1000~00 1000 O0 873,00 0 23 2000i00 i937 98 1810 98 31 47 3000 O0 2688 34 2561 34 44 51 4000,00 3402 54 3275 5000,00 4134 51 4007 6000.00 4870 52 474] 7000.00 5600 70 5473 7923,00 6285 83 6158 VERTICAl, DOGbEG REiCTANGULAR COORDINATES [tORIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST Di$~, AZ~NUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 54 43 6 51 42 70 41 10 83 42{ 28 0 O0 N 0 OE N 37 9 W 0 N 14 32 W 298 N 10 27 W 953 N lO 6 W 1653 N 8 43 W 2334 N 0 45 W 3010 N 2 5 W 368 7 N 2 5 W ~302 75 85 59 42 74 96 0 O0 0 42 0 28 0 47 0 55 0 O0 0 O0 N 0 290 932 lb21 2294 296 365~ 4267 0 O0 E 76 N 0 22 N 78 74 N 21 64 N 33~ 53 N 44 58 N 516 46 N 523 76 N 555 0 O0 N 0 0 E; 04 W 0 92 W 300 98 W 956 97 w lb55 38 W 2336 20 W 301 56 W 368~ 44 W 4JOJ 76 ~ 3 7 W 76 h 15 12 W 53 a i2 48 W 4O W 87 N 11 59 N 10 5~ ~ 12 ~ 9 4 81 N 8 9 w 76 ~ 7 24 w ARCO AbASKA~ NORTH ~I,,OPE~ AbASKA COM. PUTATIrlN DATE: 4-DEC-84 DATE OF SURVEY: 4-NOV-84 KgbbY BUSHING EbEVATION{ ENGINEER{ MCBRIDE INTERPOLATED VALUE5 FOR EVEN 100 FEET DF SUB-SEA DEPTH TRUE SUB-SEA COURSE IEA6I.IRED VERTICAL VERTICAb DBVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0 O0 27 O0 127 O0 227 O0 327 O0 42~ o0 52 O0 627 00 727 00 827 O0 0 0 N 0 0 E 0 2 S 73 27 E 0 9 S 87 55 W 0 3 $ 46 42 W 0 0 N 54 16 g 0 5 N 29 41 E 0 9 N 16 25 E 0 7 N 29 9 E 0 4 N 9 57 E 0 ] N 49 33 E 832 2 W N 37 7 w N 1.9 55 W N 19 3 W N 16 26 W N 12 10 W N 13 50 W N 15 22 W N ~5 38 W N t5 1! W PAGE 927 O0 1027 127 227 1329 143~ 1757 1871 127,00 F% 3337,91 2927,00 2800,00 45 12 3479.60 ]027.00 2900,00 44 56 ~620,41 3127,00 3000,00 44 29 3759,42 3227,0o 3100.00 43 41 3896,64 ]3~7,00 3200,00 42 56 4033,52 3427,00 3300,00 43 1o 4170,75 ]527,u0 3400,00 43 11 4307,93 3527,00 3500.00 43 11 4444.97 3727,00 3600.00 43 3 458],86 ]827,00 3700.00 43 2 N 10 7 W 1192,94 N 9 57 W 1293,28 N 9 53 W 1392,38 N 9 59 W 1488,91 N 9 57 W 1582,84 N ~0 6 W 1676,28 N 9 57 W 1770.21 N 9 50 W 1864,i0 N 8 14 W 1957,79 N 8 6 W 2051,26 1987 11 1927,00 1800.00 31 33 2105~96 2027.00 1900,00 33 58 228,75 2127,00 2000,00. 36 55 ~356, 13 2227,00 2100,00 39 36 2489,06 2,327,00 2200,00 42 47 628 62 2427.00 2300,00 45 22 ]771::28 2527i00 2400.00 45 20 2913 26 2627 O0 2500,00 45 4 3054 48 2727 O0 2600,00 44 47 3196,00 2827,00 2700,00 45 11 800,00 0 1 900,00 0 51 O0 1000,00 4 5 O0 1100,00 '; 53 O0 1~00,00 11 36 O0 1300,00 16 4 O0 1400,00 20 9 O0 1500,00 24 44 O0 1600,00 27 25 O0 1700,00 29 27 927,00 O0 1027 O0 10 112 66 122~ 18 1327 16 1427 40 1527 71 1627 30 1727 OI 1827 0.00 127,00 27.00 :100,00 oo o.oo O0 1.00,00 327 O0 200,00 427 O0 300,00 527 O0 400,00 627 00 500,00 727 O0 600,00 827 O0 700,00 N 10 23 W 1092,29 N 14 35 W 292,00 N 13 57 W 355,88 N 12 52 W 426,85 N 12 16 W 505,55 N 11 40 W 592,94 N iO 57 W 690.15 N 10 25 W 791.81 N 10 16 W 892 56 N 10 30 W 992:22 0 O0 0 02 0 17 0 10 0 03 0 09 0 06 0 03 0 06 0 07 0 O0 N 0 O0 N 0 06 S 0 08 S 0 11S 0 04 $ 0 18 N 0 39 N 0 54 N 0 64 N 0 O0 E 0 O0 E 0 12 W 0 33 W ,0 33 W 0 28 W 0 ~9 W 0 0 W 0 04 W 0 O1 E 0 O0 N 0 0 E O0 N 90 0 E 13 $ 64 18 W 7 6 4 W 72 25 W 35 ~ 28 S 82 21 W 26 N 47 40 W 40 N 14 43 w 54 N 4 21 w 64 h 0 48 E 0 97 4 96 15 14 32 24 56,64 89,26 130,52 179 66 233~39 021 2 38 3 21 4 24 3 79 4 36 4 50. 3 91 1 53 I 86 0,63 N 0 95 N 4 72 N 14 51 N 30 99 N 54 79 N 86 71 N 125 83 N 174 54 N 226 70 N 0,05 E 0,20 W 0 1,93 W b 5,33 W 15 10 78 W 32 16 59 W 57 23 69 W 89 34 40 W 131 47 61 W 180 62 0 63 N 4 le E 97 N 11 52 ~ l O N 22 11 W 6 h 20 11 W 81 N 19 iOW 24 N 16 50 ~ 89 N .15 16 W 41 ~ 15 10 w 91 a 15 15 W 09 ~ 235'05 ~ 15 19 ~ 1 81 2 35 2 33 2 43 2 51 0 94 0 21 0 34 0 21 0,12 283 69 N 77 22 345 90 N 93~11 W 35~ 415 20 N 109 63 W 429 492 21N 126 72 W 508 577 86 N 144 87 W 595 673,29 N 163 98 W 692 773,25 N 182 ~9 W 794 872,42 N 200 96 W 895 970,49 N 21~ 99 W 994 1068,96 N 237,17 W 1094 W 294 01 N 15 13 W 22 n 15 3 W 43 h 14 47 W 26 h 14 26 W 74 ~ 14 4 W 97 h 13 41 w 59 h 13 18 W 26 h 12 58 W 89 N 12 42 W 95 ~ 12 3O ~ 0,15 0,31 0,92 0,55 0,52 0,16 0,49 0,08 0,75 0,23 1168 04 N 255.10 W 1195,57 h 12 19 w 1266 87 N 272~63 W 1295,88 h 12 8'W 1364 53 N 289 67 W 1394,94 N 11 59 w 1459 63 N 306,37 W 1491,44 a 11 51 w 1552 17 N 322,70 W 1585,36 h 11 '44 W 1644 21N 339,00 W 1678'79 h I1 38 W 173o 72 N 355 44 W 1772,72 h 11 33 W 1829 25 N 371:53 W 1865,60 N 11 28 w 1.921 71N 380:71 W 196o 23 ~ 11 22 ~ 2014 26 N 399 84 W 2053~56 N 11 13 W 0 62 0 O0 0 O0 -0 04 -0 03 -0 06 0,00 §:s4 V~RI'ICA{., DOGI, EG RECTANGULAR COORDINATES hORIZ, DEPARIURE ECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMU H FEET DEG/iO0 FEET -FEET FEET DEG MIN CONPUTATiO~ DATE~ 4-DEC-~4 PAGE 6 ARC(',) ALASKA, TNC, 2D-3 KUPARUK NORTH SLOPE, AbASKA DATE OF SURV'E¥: 4-NOV-84 K£LLY BUSHING EbEVATIONI ENGINEERS McBRiDE 127,00 FT iNTERPOLATED VAbUE~ FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COUR~E EAfURED VERT1CAL VERTICAb DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG ~IIN DEG VERTICAL DOGI~EG RECTANGUbAR COORU,INATES HORIZ, D~PARTURE SECTION SEVERITY NORTH/SOUTH EA~T/WE~ DI~T AZIMUTH . ~ FEET D~G/IO0 FEET FEET FEET D~G ~IN 4718 46 ]92'?,00 BSUO.O0 42 51 4854 62 4027.00 3900.00 42 29 4989 8'7 4127,00 4000,00 42 11 5125 63 4227,00 4100,00 42 51 5262 ]3 4327'00 4200,00 42 54 5398 70 4427,00 4300.00 42 42 5534 41 4527.00 4400,00 42 18 5669.08 4627 00 4500.00 41 56 5803 66 4727:00 4600,00 42 10 5940~01 4827,00 4700,00 43 21 N 8 21 W 2144.33 N 8 30 W 2236;72 N 8 43 W 2327 79~ N 7 40 W 2419 61 N ~ 5 W 2512 75 N 6 19 W 07 N 6 28 W 2787 20 N 4 57 W 2877 17 N I 30 W 2969 49 0 34 0 41 0 27 2 04 0 28 0 19 0 50 0 31 1 62 2 84 2106,37 N 413.13 W 2146,50 h 11 5 w 2197,75 N 426 77 W 2238 80 N 10 59 W 2~87, 80 ~ 10 53 W 2378,62 N 453 93 W 2421 54 N 10 4~ W 80 N 440 ~5 W 2329 247! 21N 464 44 W 2514 2563 39 N 474 44 W 2606 2654 59 N 484,50 W 2698 2744 22 N 494,54 W 2788 2833 81N 503,79 W 2878 2926 30 N 509,56 W 2970 48 ~ 10 38 W 93 N 10 29 w 44 a 10 20 ~ 42 N 10 12 W 24 N 10 4 . 33 ~ 9 52 W 607~] 621 6350 6488 6766 6901 7034 7166 7298 75 4927 O0 4800.00 43 19 71 5027 O0 4900,00 42 42 32 5127 O0 5000.00 42 44 42 5227 O0 5100,00 44 33 56 5327 00 5200,00 44 15 42 5427 O0 5300,00 42 33 81 5527 O0 5400,00 41 57 91 5627100 5500,00 41 2 27 5727'00 5600,00 39 58 51 5827,00 5700.00 41 9 N 0 51 W 3063 37 N 0 54 W 3156 12 N 19 30 W 3246 82 N 0 8 W 3340 98 N 1 43 W 3438 37 N I 50 W 3532 60 N 1 54 W 3623 28 N 2 8 W 3710 55 N 2 11 W 3795,20 N 4 31 ~ 3881.40 0 58 I 12 0 77 0 93 0 49 0 39 2 39 0 52 1 13 0,68 3206 3301 3399 3494 3585 3673 3758 3844 02 N 510,94 W 3063 92 N 9 35 w ~470N 513' N . '03 W 8 49 W 59 N 512 37 W 3156 22 W 3246 513 55 N 515 40 N 518 61N 521 40 N 524 51 N 527 84 N 533 3341 24 W 3438 15 k 3532 31 W 3623 42 W 3710 60 W 3795 12 W 3881 45 h 9 20 W 99 h 9 5 W O3 N 37 i~ 8 37 a 61 i~ 8 26 W 31 ~ 8 lb w 64 N 8 7 W 36 ~ 7 59 ~ 62 ~ 7 53 W 7431 85 5927.00 5800,00 42 0 7567 37 6027.00 5900.00 42 52 7704 19 6127,00 6000.00 43 17 7841 92 6227.00 6100,00 43 28 7923 O0 6285.83 6158,83 ' 43 28 N 3 18 W 3969.3~ N 3 4 W 4060.40 N 2 56 W 4153,35 N 2 5 W 4247,52 N 2 5 W 4302.96 1,38 0 74 0i54 ' O0 ~,00 3932 83 N 539,j2 W 3969 63 a 7 4~ w 4024 14 N 544.50 W 4060 81 m 7 42 W 4~11;, 39N 549 37 W 4153 88 ~ 7 35 w 4..1 O1 N 553:40 W 4248 21 N 7 29 ~ 4267 76 N 555,44 W 4BO~ 76 N 7 24 ~ ARCO ALASKA, INC, 2D~3 Ki,IPARUK NOETH SLOPE, ALASKA ~ARKER TOP UPPER SAND BASE UPPER SAND BASE LOWER SAND PBTD ~OTAb DEPTH COMPUTATION DATE; 4-DEC-84 PAGE 7 DATE OF SURVEY1 4-NOV-84 KELLY BUSHING EbEVATION; 127,00 FT ENGINEER; MCB~IDE INTEHPOLATED VALUES FOR CHOSEN HORIZONS MEASURED DEPTH BELOW KB SURFACE LOCATION AT ORIGIN= 65' FNL, 717' EEL SEC ~6 TIIN RgE~ UM WVD RECT~NGULA. ~OORDI~ATE$ FROM KB SUB-SEA NORTH/SOJI EAST/WEST 741~ O0 7480 O0 7540 O0 7700 O0 7825 O0 7923 O0 5916 5962 6006 6123 6214 6285 67 93 96 72 83 5789 73 5835 67 5879 93 5996 96 6087 ~2 6158 3' 3923 55 N 3965 11N 4005 56 N 4267 76 N 538 78 ~ 54~ 4 54 b ~ 549 23 W 552 98 ~ 555 4~ ~ COMPUTATION DATE: 4~,DEC-84 PAGE 8 ARCO ALASKA~ INC, 2D'3 KUPARUK NORTH 6[,,OPE~ ALASKA DATE OF SURVEY1 4-NOV-84 KELLY BUSHING EbEVA'fIONI ENGINEERI MCBRIDE 127.00 FT MEASURED DEPTH BELOW KB ORIGIN: 65' FNL, 717' TVD FROM KB SUB-SEA UM TOP UPPER SAND BASE UPPER SAND TOP LOWER SAND BASE LOWER SAND PBTD TOTAL DEPTH 7418 O0 7480 O0 7540 O0 7700 O0 7825 O0 7923 O0 5916 73 5962 67 6006 93 14 72 6285 83 5789 73 5835 67 5879 93 5996 96 6087 72 6158 83 3923 3965 4005 4114 42 N 56 N 52 N 38 N 76 N 538 7a W 541 t2 W 543 ~6 W 549 3 ~ 562 98 W 565 44 W FINAl,, WELL bOCATION AT TRUE SUB-SEA MEASURED VERTI, CAL VERTICAL DEPTH DEPTH DEPTH HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET bEG MIN 7923,00 b285,83 6158,83 4303,76 N 7 24 W SCHLUMBERGER ARCO ALASKA. INC. KUPARUK NORTH SLOPE. ALASKA NOVEMBER 4. !S84 TVW PLOT FROM C-CT DATA JOB REFERENCE 69804 WELL: 2D-3 SURFACE LOCATION: 65' FNL, 717' FEL, S26, T11N, R9E, ~ VERTICAL PROJECTION -2000 - 1000 0 0 ! 000 2000 ' ~-~-~'~-' ~! ~ f -'~~~-~?"~-~'t']]'~"f'~"f---t-~f+'~-~'~ -t'"f"f"f"~-~-f-b-b~HbbA'bbb -..i-~-.' ~'-~-~' ' ' ~-~-' : : ~ ~.~.-~: ' ~ ' : : :4 -~ i ~ .... t4'..Tt-[-.t.t++..-f-~-~q-?e-.u. ~t~+, -t~--t-. i+.H_~ : +H~_._~+ ~ ~ ~ i ~~~- .... 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T .......... ~,.,~ ........... ~'''=''~'''?''~'"''--H'~--~'"'----'''~"~'~'='"t--~"%l "~--~'~'~'. ~--~'''~ : '~e--~--I ] :. ''--~--~"~+%~''4--': :' ~'~'~--'L~.~--~Z..----~--Z--=.li...~..4 ::::::::::::::::::::::::::::::::::: =========================================== ~::'h([:~~2}-t-~D ...:...;...;...4...i,..;...;.....=.,_LrEL~L.;~_Z_E~ '~'~ i ~ ~i ~1 i ~ ({ "~ i i: i i i ~ i d'd'"y'~"t'7'~"~?"~"7-t'"ft'~'-~-~ ' ~ ~) j~ , ~'~-~ ~ ~~--~-~ :::::::::::::::::::::::::::::::::::::::::::::::::::::::: ~ '-r~:~ ~ ~r~i--~-r~-~-~'--~--~-'~-.~-.~-.~-r-~-.~ I...i_.L.:_Z~...:..X_ZL......LX..~L~ .%.L.L.T i %* *~! ~ ~ _ I_¢ ~ ~%-%%~'%~%/ ~ ~ F"T-, PROJECTION ON VERTICAL PLANE OF AZIMUTH 9S1 ,~..EO IN VERTICAL DEPTHS HORIZ SCALE = 1/1000 IN/FT WELL: 2D-3 SURFACE LOCATION: 65' FNL, 717' FEL, .S26, T11N, RgE, UM NaR?~ ~_~,000 lIEF 69804 2OOO -1000 -2000 sou~-~000 ~ST HORIZONTAL PROJECTION ~I;RI.E -- I/I000 IN/FT --'~?- * I I ' : ? ~ ': ~ ~ [ ~ ~ '~ ': : ? r ': [ ~ '~ i .: i i ~ f [ ; ~ .-' ~ ? ; -'"-~: 'b'-'~-~-~.: ? ~ : ~-~-.~-~-m-.~.'? 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H-~.'-'-H~--H~.% .-f.~-f..H-+-HHH ~--f.-f-F-f--~--?-- · 4-;--*--;.-~-H--.;-.., ...... ;--L+-t-~-.~.--L.~----*-~-H-+ :4-~ '~-f-*-~-t'-l-+-.~5-f-F't-'H'--f--f-H~-f-t'-H-?q'-';-f'-f--~-f-'~q~- ..;.,...;.;-..-4...;.--.-.: ....... -"-~ ...... ,L;--'...i...,-r-H~-;~-.t-.4.. ~ ~ ~ i ~ ~-~ `..-~-?-~..*--H?-+-?.~...t-..`~...T:"i-..~-f-?."7..t."~-;...~..1..i...~..~..t...f-?.~.~7. ...!..L-.:...i...i...~...H ......... ;..;...%T+-~.~.~H-..=i-,.++-t-q-~: t-.~.+-?=-~H-t-!.-=lF-~-i--+--.: ........ ?.77i-m...i--tl..~.-~-=T.t-t.~-~ -6000 -SO00 -4000 -~000 -2000 - 1000 0 I Suggeste :.tm to be inserted in each "Ac~-~.~'' woll folder to d]eck for timely ccmpliance with otu _~gulations. - ' t0r ...... Numker and Materials to be received by: /~-.~--~'~:~ Reports Date Required Date Received Remarks L · · '~ Well , History Yes,. ~ .~_/.~;. ~~ ".~~ ,. · . ..~a .i ' . . Core ~scrip~on . 4/~~~" ..Inclina~on S~ey . Dire~ional ~ey Drill St~ Tes. t~.~e~s dn T~t R~ , . ., .,/ ARCO Alaska, Inc. Posl Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 4, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' Commi ss i on Attached in duplicate are subsequent notices on the following wells at the Kuparuk River Field- Well Action Date Performed 1E-15 Fracture 12/17/84 1F-6 Stressfrac 1/11/85 1L-4 Fracture 1/9/85 1L-5 Fracture 1/10/85 2C-5 Perforate 12/22/84 2C-6 Perforate 12/25/84 2D-1 Perforate 1/13/85 2D-2 'Perforate 12/15/84 ~~,~- Perforate 12/16/84 2D-8 Stressfrac 1/9/85 .If you have any questions, please call me at 263-4253. Mike L. Laue Kuparuk Operations Coordinator MLL/kmc Attachment (Duplicate) RECEIVED FEB 0 6 19B5 Alaska 0]1 & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichlieldCompany ' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL~3 OTHER [] 2. Name of Operator ARCO ALASKA, INC. 3. Address P. O. BOX 100360, 4. Location of Well SURFACE LOCATION' T11N, R9E, UM BOTTOMHOLE LOCATION' 23, T11N, RgE, 5. Elevation in feet (indicate KB, DF, etc.) 127' (RKB) 12. ANCHORAGE, ALASKA 99510 65' FNL, 717' FEL, SEC. 26, 1071' FNL, 1357' FEL, SEC. UM 6. Le~se Designation and Serial No. ADL 25653 7. Permit No. 84-153 8. APl Number 5o-029-21178 9. Unit or Lease Name KUPARUK RIVER 10. Well Number 2D-3 UNIT 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations X [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On December 16, 1984, the "A" sands of Kuparuk well 2D-3 were perforated for production. After testing the lubricator to 2500 psi, the well was shot with a wireline conveyed gun. Interval (MD)' 7559-7561' (lSPF) 7589-7592' 7595-7597' 7601-7603' 7611-7616' RECEIVED AiaS~ Oil & Gas Cons. commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below for Commission use 2/4/85 COORDINATOR Conditions of Approval, if any: Approved by COMMISSIONER By Order of the Commission Date__ Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicat'e and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. ~ Post Office' J Anchor~,ge, Alaska 99510 Telephone 907 277 5637 Date: 1/3i/85 Transmittal No: 5014 RETURN TO: PAGE 1 of 3 ARCO ALASKA, INC. ATTN: Records Clerk ATO-11t5B P.O. Box 100360 Anchorage, AK 99510 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. OH FINALs Schlumberger 0~ensity Neutron "Poro" 10/16/84 Run 1 10/16/84 " 7100 - 7733 2"/5" 7100 - 7733 2"/5" ,, DILiSFL/GR 10/16/84 " 3276 - 7758' 2"/5" " BHCS/GR 10/16/84 " 7100- 7759 2"/5" " CPL Cyberlook 10/16/84 " 7100 - 7700 CPL Cyberlook " Density Neutron "Poro" " " " "Raw" 10/03/84 Run 1 _. -- - 10/03/84 " 10/03/84 " I0/03/84 " 6400 - 7050 6400 - 7048 2"/5" 6400.-- 7048 2"/5" 2805 - 7074 2"/5" ~~~"~ Cyberlook " Density Neutron "Poro" ,, ,, ,, ,,Raw', 10/07/84 Run 1 10/07/84 " 10/07/84 " 7200- 7710 7200 - 7878 2"/5" 7200- 7878 2"/5" " DIL-SFL/GR /cat Receipt Acknowledged: B. Currier BPAE Chevron lO/O8/84 ;' DISTRIBUTION Drilling W. Pasher FGeology~ ' O. Phillips Mobil Phillips Oil 3624- 7910 2"/5" Alaska 0[I & Gas Cons. Com~nission State of Sohio Union D&M NSK Ops. J. Rathmell Well Files ARCO Alaska. Inc. is a subsidiary of AtlanticRich'fielaCompa.y ARCO Alaska, Inc~ ~ Post Offic~ .,0 Anchorage, Alaska 99510 Telephone 907 277 5637 Date: 1/31/85 Transmittal No: 5014 RETURN TO: PAGE 2 of 3 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 signed copy of this transmittal. ~,,~ 1L-1 CPL Cyberlook 10/08/84 Run 1 --- '" 2"/5" DIL-SFL/GR '10/08/84 " 2359 - 7470 " 2"/5" Density Neutron "Poro" 10/08/84 " .. 2359 - 7447 " 2"/5" " " "Raw" 10/08/84 " 2359 - 7447 " 2"/5" BHCS/GR 10/08/84 " 6750 - 7473 2W-6 CPL Cyberlook " 11/06/84 Run 1 3198 - 7286 2"/5" DIL-SFL/OR 2"/5" Density Neutron "'Poro" 11/06/.84 " 3198- 7286 11/06/84 " 6600- 7261 " 2"/5" " " "Raw" 11/06/84 " ~' .~ "DIL-SFL/SR, ~DC-CNL/GR" /T/v~~~-~"~ ~L Cyberl o~ .. ~" 2"/5" Density Neutron "Poro" / " 2"/5" " " "~w" ' " 2"/5- DIL-SFL/OR /cat Receipt Acknowledged: 11/07/84 " 5600 - 7261 10/31/84 Run 1 7350 -'.8050 10/31/84 " 3757 - 8080 10/31/84 " 3557 - 8050 10/31/84 " DISTRIBUTION B. Currier DYilling W. Pasher BPAE ~Geology ~----~ G. Phillips Chevron Mobil Phillips 0il D & M NSK Ops. J. Rathmell 3757 - 8080 Alaska Oil & Gas Dons, Oommissior, State of ~'~:~/~ Sohio Union Well Files ARCO Alaska. Inc. if, a ,~ubsidiary of AtlanticRich'lieldCompeny ARCO Alaska, Inc.~-~--'-" Post Office _ .0 Anchorage, Alaska 99510 Telephone 907 277 5637 Date: 1/31/85 Transmittal No: 5014 RETURN TO: PAGE 2 of 3 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 signed copy of this transmittal. ¢~iL-1 CPL Cyberlook 10/08/84 Run 1 --- ~ · '" 2"/5" DIL-SFL/GR '10/08/84 " " 2"/5" Density Neutron "Poro" 10/08/84 2359- 7470 2359- 7447' " 2"/5" " " "Raw" 10/08/84 " 2359- 7447 " 2"/5" BHCS/GR 10/08/84 " 6750 - 7473 2W-6 CPL Cyberlook : 11/06/84 Run 1 3198 - 7286 " 2"/5" DIL-SFL/GR 11/06J84 " 3198 - 7286 · "' 2"/5" Density Neutron "Poro" 11/06/84 " '6600 - 7261 " 2"/5" " " "Raw" 11/06/84 " 5600- 7261 i, RFT "DIL-SFL/GR, FOC-CNL/OR" 11/07/84 " /,9~~~~ CPL Cyberloo~~ 7, .. ~'" 2"/5" Density Neutron "Poro" " " "Raw" I1 /cat -- Receipt Acknowledged: 2"/5" " 2"/5" DIL-SFL/GR 10/31/84 10/31/84 10/31/84 10/31/84 DISTRIBUTION B. Currier DYilling W. Pasher BPAE ~Geology ~~ G. Phillips Chevron Mobil Phillips Oil Run 1 7350 -'.8050 3757 - 808O " 3557 - 8050 " 3757 - 8080 Alaska Oil & Gas Cons. [:omrnissior,, State of ~h~/~ Sohio Union D & M NSK Ops. J. Rathmell Well Files ARCO Alaska, Inc. is a subsidiary of AllanticRich'lieldCompany ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 12, 1984 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation 3001 Porcupine Drive Anchorage, AK 99501 Commission Dear Mr. Chatterton' Attached are our notices of following Kuparuk Field wells' 2D-1, 2D-2, 2D-3 Intention If you have any questions, please call me to perforate the at 263-4253. Mike L. Laue Kuparuk Operatlons Coordlnator MLL/kmc Attachment (in Trlplicate) RECEIVED 2 Alaska Oil & Gas Cons. Commission Anc/~orage ARCO Alaska, Inc. is a Subsidiary ot AtlanlicRichlieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 84-153 3. Address 8. APl Number P. O. BOX 100360, ANCHORAGE, ALASKA 99510 50-029-21178 OTHER [] 4. Location of Well SURFACE LOCATION' 65' FNL, 717' FEL, SEC. 26, T11N, R9E, UM BOTTOMHOLE LOCATION' 23, T11N, R9E, 5. Elevation in feet (indicate KB, DF, etc.) 127' (RKB) 12. 1071' FNL, 1357' FEL, SEC. UM 6. Lease Designation and Serial No. ADL 25653 9. unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 2D-3 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate ~[] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is proposed that the "A" sand in Kuparuk well 2D-3 be perforated for production. Procedures call for the well to be perforated with a wireline conveyed gun under a lubricator. Proposed Intervals (MD)' 7589-7592 (1 SPF) 7595-7597' 7601-7603' ANTICIPATED START DATE' December 15, 1984 RECEIVED DEC 121~ Alaska Oil & GaS G0[lS. Commission Anch0racje 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed __, Title OPERAT IONS The space below for Commission use COORDINATOR Date 12/12/84 Conditions of Approval, if any: Approved by 8T [~![ C. $~tlTIl .Approved ILeturnec~ By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, post Olfice Box 100360 Anchorage, Ataska 99510 Telephone 907 276 1215 November 21, 1984 Mr. C. V. Chatterton Co~i ssi oner state of Alaska Alaska Oil & Gas Conservation commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Monthly ReportS · Dear Mr. Chatterton: Enclosed are the Monthly state ReportS for the following wellS 2G-14 1L-1 2D-3 2X-16 WSP #2 2G-15 1L-16 2D-2 2X-15 1L-15 2D-1 2)~-14 2G-16 2W-5 2E-16 Sincerely, /~A;~a Drilling Engineer jBK/SH/tw' HILL/05 Enclosures RECEIVED 2 6 ]984 Alaska Oil & G~s Cons. Commlsslo~ Ar~chorage i= c;,,h~i,412rv n{ AttanticRichtielCl C°nll:)an¥ ~' STATE OF ALASKA '-' ' ALASK...3~- ~ND GAS CONSERVATION L...,iv,,v,,SSlON MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well I-~ X Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 84-153 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21178 4. Location of Well atsurface 65' FNL, 717' FEL, 5ec.26, T11N, R9E, UN 5. Elevation in feet (indicate KB, DF, etc.) 127' RKB, PAD 90' Lease Designation and Serial No. ADL 25653 ALK 2579 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 2D-3 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 ~ 0445 hfs, 10/01/84. Drld 12-1/4" hole to 3650'. Ran, cmted & tested ~_----- 9-5/8" csg. Performed top job w/lO0 sxs AS I. Drld 8-1/2" hole to 7923'TD as of 10/07/84. Ran logs. Ran, cmtd & tstd 7" csg. Secured well + RR ~ 0900 hfs, 10/09/84. Performed Arctic pack. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 9-5/8", 36#, J-55 HF-ERW BTC csg w/shoe @ 3630'. Cmtd w/850 sxs AS Ill "G" cmt. 7" 26#, J-55 HF-ERW BTC csg w/shoe ~ 7907' Cmtd w/481 sxs Class "G" + 500 sxs Class 14. Coring resume and brief description N/A 15. Logs run and depth where run DIL/SFL/GR f/7919' - 3630' Density/GR f/7919' - 7190' Cal f/7919' - 6200' 6. DST data, perforating data, shows of H2S, miscellaneous data N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. /~~~/'~///~~ Area Drilling Engineer SIGNED TITLE DATE ~' 'Z~; ~/~/~/' ................... '~rt...._ ... ~- .~ _~,pl~a~e with the Alaska Oil and Ga~Conservati~ommission by the 15th of the succeeding month, unless otherwise directed. HILL/MR31 Form 10~04 Submit in duplicate ARCO Alaska, inc. -'-'"'- Post Office' J Anchorage, ~iaska 99510 Telephone 907 277 5637 ltET?JRN TO: ARCO ALASKA, INC. - ATTN :.- Records Clerk ~0. Box lOOB60 /Anchorage, AK 99510 ' L//-Transmitted herewith are the following items. and return one signed copy of this transmittal. Date: 11/07/84 Transmittal No: 4~38 Please acknowledge receipt OH LIS TAPES/Schlumberger -~69612 1L-1 10/08/84 Run 1 ~7/69613 1L-2 10/01/84 Run 2 J #69591 2B-13 10/03/84 Run 1 /#69596 2G-12 9/23/84 " /#69594 2G-14 10/08/84 " /'#69595 2D-3 10/08/84 " f #69623 2D-2 10/16/84 " 2317 - 7486.5 2883 - 8148 /cat Receipt Acknowledged: -. B. Currier Drilling BPAE Geology Chevron Mobil D & M NSK Ops. Date: DISTRIBUTION W. Pasher G. Phillips Phillips 0il J. Rathmell State of AK Sohio Union Well Files .. '.P,'" ~.; &la'~k~l IIIC ~', (3 sub$1(JHtr¥ O! ~,llanltcRIch~.e.;cCornpen) MEMORANDUM Sta' e of Alaska ALASKA OIL Ai~D GAS CONSERVATION COI~IISSION TO: C. V.~~t -~ton Chai~h,_~ '- · THRU: Lonnie C. Smith Commi m ~ ioner FROM: Bobby Foster ~.;- ~ ~; Petroleum inspector DATE: October 8, 1984 FILE NO: D. 3I. 6 7 TELEPHONE NO: SUBJECT: Witness BOPE Test on ARCO' s 2D-3, Sec. 26, TllN,R9E,UM, Permit No. 84-153. Wednesday, October 3, 1984: The BOPE test began at 5:30 pm and was ~n'clUded' at '6:30" pm. As the attached BOPE test report shows there were no failures. In summary, I witnessed the BOPE test on ARCO's 2D-3. Attachment 02-001ACRev. 10i79) 5/84 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report ~ ~ J~ Inspector 'ii/ Operator . Well ~ ~ ~ oca o :Sec W j Drillin~ Contractor Location, General ~/C~/[ Well Sign~= General Housekeeping /~ZRig Reserve Pit Mud Systems Visual Audio Trip Tank Pit Gauge Flow Monitor Gas Detectors BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Pressure Date Well ~ - ~ , Representative ~'/~~~? Permit # ~ ~~CasSng Sot O~'~'D Representative ~f. ACC~LATOR SYST~ Full Charge Pressure ~5 ~ P psig. m ~ ~ psig Pressure After Closure Pump incr. clos. pres. 200 psig Full Charge Pressure Attained: Controls: Master ~.~ Remote ~?~> Blinds switch cover(~~ I Kelly and Floor Safety Valves Upper Kelly / Test Pressure ~_~~ Test Results: Failures O Repair or Replacement of failed equipment to be made within min ~' ,. ' sec. min' sec. Commission office notified. / Lower Kelly / Test Pressure Ball Type Test Pressure / Inside BOP Test Pressure Choke Manifold ~c~-~ Test Pressure~~O No. Valves No. flanges Adjustable Chokes ! Hydrauically operated choke / Test Time / hrs. days and Ins'~ector/ Remarks: Distribution orig. - A0&GCC cc - Operator cc - Supervisor August 24, 1984 Mr. J. B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 2D-3 ARCO Alaska, Inc. Permit No. 84-153 Sur. Loc. 65'Fl:IL, 717'FEL, Sec. 26, TllN, RgE, UM. Btmhole Loc. 1071'FNL, 1357'FEL, Sec. 23, TllN, ~gE, Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced weal. 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 for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified a~ important for the spawning or migration of anadromous fish. Operations in 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. Jeffrey B. Kewin Kuparuk River Unit 2D- 3 August 24, 1984 equipment so that a representative of the Commission may be present to witness testing of the equipment before the ~urface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing 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~?n!y yo~u~urs, ~ C. V. ChattertOn Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE C~ISSION be Enclosure cc: Department of Fish & Game, Habitat Section w/o ~ncl. Department of Environmental Conservation w/o encl. ARCO Alaska, Inc. Post Office B~,,, 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 20, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2D-3 Dear Mr. Chatterton: Enclosed are: An application for Permit to Drill Kuparuk 2D-3, along with a $100 application' fee Diagrams showing the proposed horizontal and vertical projections of the wellbore A proximity plat A diagram and description of the surface hole diverter system A diagram and description of the BOP equipment Since we estimate spudding this well on September 30, 1984, your earliest approval will be appreciated'. If you have any questions, please call me at 263-4970. Sincerely, O. B. Kewi~ Area Dril Ting Engineer JBK/JG/tw GRU8/LI07 Attachments RECEIVED AUG 2 2 AlasKa 0ii & Gas Cons. Commisslo~t Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ~" ALASKA fu,L AND GAS CONSERVATION CO~v~MISSION PERMIT TO DRILL lb. Type of well EXPLORATORY [] SERVICE [] S'~ATIGR_~.APH~L la. Type of work. DRILL I~x REDRILL [] DEEPEN [] 2. Name of operator ARCO Alaska, Inc, 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 65' FNL, 717' FEL, Sec.26, TllN, R9E, UN At top of proposed producing interval 1429' FNL, 1304' FEL, Sec.23, TllN, R9E, UM At total depth 1071' FNL, 1357' FEL, Sec. 23, TllN, R9E, UM 5. Elevation in feet (indicate KB, DF etc.) RKB 127', PAD 90' 6. Lease designation and serial no. ADL 25653 ALK 2579 9. Unit or lease name Kuparuk River Unit 10. Well number 2D-3 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool 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 30 mi. NW of Deadhorse miles 65 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 7923' MD, 6256' TVD feet 2560 20. Anticipated pressures KICK OFF POINT 1000 feet. MAXIMUM HOLE ANGLE 44 o (see 20 AAC 25.035 (c) (2) 15. Distance to nearest drilling or completed 2D-4 well 60~ ~ surface feet 18. Approximate spud date 09/30/84 19. If deviated (see 20 AAC 25.050) 2741 _ psig@ ~O°F Surface 3146 _psig@ 6112 ft. TD (TVD) SIZE i Hole Casing Zb~i~ 16" 12'I/ZP' 9-5/8" 8-1/2" 7" Proposed Casing, Liner and Cementing Program Weight 62,5# 36. O# 26. O# CASING AND LINER Grade ] Coupling/ H-40 / Wel~ J-55 HFIERW BTC/ J-55 HFIERW BTC/ Length SETTING DEPTH MD TOP TVD 80' 37' I 37' 3541' 37' I 37' I I 36' I 36' I 7887' M D BOTTOM TV D 117'1 117' 3578' 3127' l 7923' I 6256' I I QUANTITY OF CEMENT (include stage data) ± 200 cf 850 sx Arctic Set III & 500 sx Class G 300 sx Class G 22. Describe proposed program: ARCO Alaska, Inc,, proposes to drill a Kuparuk River Field development well to approximately 7923'MD (6256' 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 2741 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. 2D-3 will be 60' away from 2D-4 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 The space~'el'o~N f~r Comm[ssi~. f CONDITIONS OF APPROVAL DATE Samples required Mud Icg required Directional Survey required APl number 1~3 Y ES ~.~O J [~] YES j~[l~l O ~YES r-]NO 50- ~ L.~-7--// SEE COVER LETTER FOR OTHER REQUIREMENTS Permit number Form 10-401 Approval date ,COMMISSIONER DATE Augu.~t ?4, 1 984 by order of the Commission Submit in triplicate Permit to Drill 2D-3 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 fractured stimulated. RECEIVED AUG 2 219B4 Alaska Oil & Gas Cons. Commission Anchorage ) nnn ; ! , - ! t ~-sl rvr t i I ? 1 TOP UPPR i SNDS '^ROET ~#TR BASEl KUP SNDS 'TD;(LOG PT) ) 000 ' booo ' t i ; · I RECEIVED! ~ r ....... * ..... ~. ) AuG 2 219~ = l , , Alaska Oil & (las Cons. Oommiss)on ^nchorag~ TVD-5880 TMD-T401 DEP=3960 TVD-~i994 TMD-?Q60 DEP-4OTO TI"I~~' DEP=4073 iTVD-6112 TMD-7723 DEP-4184 TVD-6256 T~D-7923 DEP=4322 i ~ ..~_. ! . . i i i, - i - - ~ ....... ~,RCO F, LASKA, INC. - .... ~ ....... ' ' ' L/lb~ t · i .... ?AD 2D. WELL NOr, :3' BEVISED'PROPOSAE: '/4 ii ~' - ~ - . . ....... ; ........ 1 -~; ~ ].-:--KUPARUK-FIELD.-NORTHiSLOPE. -ALASKA---; / !YL. t ~ ,, i. i = ~ :' _ .,__ ~ = ;, .... :. I: ..... ~ ........ --- ~ - t ; . EASTMAN WH[PSTOCK.-[.NC. !-- I j ...... ~ : I i . - i .... t Nil/ ' " I - ..... : - ~ ~ ~ -- _ . : .... WEST_.,' EAS : -* T+ .... I ' ' ' i : ~ i · - ~ :' ' >000 ' ~1000 ~ ' 000 ; .... : ''~ - , ~ I i - ~ ! .4000 i ' I I ' 8 DEB 31,-MII~ W--, . · i ..... J i t · I _ . ~ !..~. icl , .2000-- , ; _ . · · - . ~ . I - ~ - .- t ' ' ' ~ ' ' ' .... ;_ ,~ .. ..~ .......... J .... ..... ~ ......... ~ . - . . _ . i ] nnn + . ;. , D~C~,,4,oro .... i TARGET LOOATIO#,' ' ' _ ' ' ! 1320' FNL. NORTH ,4.C)2~ . ~'~_,01'12,~; 'TI'IN."RgE ............. , · J. : 1 l lm ii Surface Diverter S~.stem 1. 16"-2000 psi Tankco starting head. 2. lankco quick connect assy. 16" X 20" 2000 psi double studded adapter. 20" 2000 psi drilling spool w/lO" side outlets. $. lO" ball valves, hydraulically actuated, w/lO" lines to reserve pit. Valves to open automatically upon c)osure of annular preventer. 6. 20" 2000 psi annular preventer. ?. 20" bell nipple. Maintenance & Operation 1. Upon initial installation close annular preventer and verify ~hat bail valves have opened properly. 2. Close annular preventer and blow air throu9h diverter lines every 12 hours. Close annular preventer in the event that gas or fluid flow to surface is detected. If necessary, manually override and close ball valve to upwind diverter line. Do not shut in well under a~2 cirFumstances. 16" Conductor rmmmmm~ im ANNUI.,~ PR£¥ENTE~ 8 ( D~AGRAM ~! 5000 PSi RSRRA BOP STA~K · 1. 15" - 2000 psi Tankco szarting beau 11" - 3000 psi casing beau 3. 1]" - 3000 psi x 13-5/8" - 5000 psi s~acer SPool 4. 13-5/8" - 5000 psi x 13-5/8" - 5000 psi ~rillin~ spool 5. !3-5/8' - 5000 psi pipe rams 6. 13-5/8" - 5000 psi Orilling spool w/choke anO kill lines 7. I3-5/8" r 5000 psi' pipe rams B. !3-5/8" - 5000 psi blinO rams g. !3-5/8" - 5000 psi annular "~---~ ~ SPOOL '-'h s - kCCUMULATO~ CAPACITY TEST 1. CHECK AND F1LL ACCUMULATD~ RESERVOi~ TD PROPE~ LEVEL Wi,lq HYDRAULIC F'l. UIO. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSi WiTH 1500 PS! DOWNSTREAM OF I'HE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER AJ.L UNITS ARE CLOSED Wi'IH CHARGING PUMP OFF. 4. RECORD ON NADC REPORT. THE ACCEPTABLE LOWER LiM:T IS 45 SECONDS CLOSING TIME AND 1200 PSI RD~AiNING PRESSURE. 13-5/B" BOP STACK TEST .-1. FiLL BOP STACK AND MAJ~IFOLD WiTH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RE'F~CT- ~. PREDETEP~M!NE DEPTH THAT TEST PLUG WILL AND SEAT IN WELLHE~. RUN IN LOCK DOWN SCR~S IN H~, 3. CLOSE .ANNU~R PREVENTER ANO ~'~S~S ~S~~ OF ~S. ~N'T ~ A~AIN~ ~S~ ~S. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES, 5. INC2EASE PRESSURE TO iBOO PSI ~D HOLE FGR ~INUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF ~. ~'P~SS~ ~~ OF ~ I~MTION ¥~S- TO ZERO PSI TO TEST VALVES. TEST : ~ ~ . , R.~..N.NG UNTESTED ~N~FOLD.VALVES, ]F k~Y ~ITH 3COO PSi UPSTRE~ OF VALVE A~D ZE~O DO~NSTRE~. BLEED SYST~ TO ZE~O PSI. 9.OPEN TOP S~ DF PiPE ~S AND CLOSE 50~D~. SET OF PIPE 10. INC~E PRESSURE T0 3000 PS~ AND HOLD FOR iD MINUTES BLE~ T0 ZERO PSi. ~. OPEN BOSOM S~ OF PIPE ~MS. BACK OFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND R~S AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED T0 ZERO PSI. 12. OPEN BLIND ~ ~D RECOVER TEST P.U:. ~KE SURE II ~NIFOLD AND LINES ARE FU,. 0F ARCTIC C':[SEL AND ALL VALVES ARE S~ ~N DRiLLiNG POSiT;ON. 13. TEST STANDPIPE VALVES T0 3000 PSi. 14. TEST KELLY COC~ AND iNSIDE BOP T0 3000 PSi wiTH KO~EY PUMP. 15. RECORD TEST INFORMATION ON BLOWO~ P~EVENTER TEST FORM SIGN AND SEND TO DRILL3NG SUPERVISOR. 16. PERFO~ C~PL~E BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPE~TE ~OPE DAILY. ARCO Alaska, Inc, Post Office vox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 5, 1984 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commi ssi on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plat - 2D Pad Wells 1-4, 13-16 Dear Elaine' Enclosed is an as-built location plat for the subject wells. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU8/L25 Enclosure RECEIVED Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ', DRILL 'TE 2. D CONDUCTORS ' AS- BUILT LOCATIONS ..... WELL I Y: 5,954,0o~5.15 Lot. 70°17'07.882. Z'' _ _ X = 529, t 29.90 Long. 149c45'51.288'' 153' FNL, 656'FEL EL. 89.7',Q~ 86.1' 1~ WELL 2 Y · 5,954,08g.31 Lat. 70°~7'0B.3185'' . X = 5~9~089.2~ Long. I '} 109'FNL, 677'FEL EL Bg.6',O.G. 86.~' i~ ......... , WELL 3 Y = 5,954, i53.4Z L~t. 70°17~08.75~8'' ' X= 5~9~048.58 Long. 149°45'55.648'' ~~ ..... 65' FNL, 717'FEL EL;_89.7', WEL~4 Y= 5;954,]77.42 lot. 70~l?'og. lsSo'' 24' X= 5Z~O0 8,~ L~. Z ZI' FNL~757'FEL EL. X= 52~6~4.74 Lo~. D.S _ .. 69~' FNL, 144' FEL EL. a9.6', 0.~ 86 8 WELL t4 Y ~ 5,953~55z.61 L~t. 70°17'05.0Z0~'' X= 5Z9~584.~ L~. t~9°~5'38, t08 647' FNL~ I~' FEL EL. , ,, WELL 15 Y = 5,953,596.~ L~t. 70el7'03.4564'' X = 5Z9,543.57- Lo~. 603' FNL, 225' FEL EL. 89.6', i ~ELL-~;-; 5,955,640.8i Lat. 70 X= 5Z9,503.~ L~g. 149°45'40.464" 559'FNL,Z65'FEL EL. 89.~', 19th LOCATED IN PROTRACTED SECTION ~6 d~ ~ .~ ~' -~ ~'~*'~'~--~-.~.., IS ~NUMENTS gO NORTH ~ aD SOUTH PER LH0 ~ ~ I H~REBY CERTIFY THAT ! AM PRO~RLY REGISTERE~ = ~2 ~~ m ~ATTHIS ~TREPRESENTS A SURV~ MADE 2, ~~ 4 [1i UN~R -r DIVOT SU~RVIStON ~ THAT ALL DETAILS ARE Kuoeruk ~oject North Slope ~ri~t~n9 - '~ - ' 'DRILL sIYE 2-D ' .s. z-o ~NDUCTOR AS' B U J LT 26 ~ 25 ~ATI ONS , ' - ~ ~ _ D.S. ~-D LOCATION ~_~~ D~l~n~ J-E. ,~ ~.n~ ( 3 (lOLand ' 11) (12 thru 20) (21 thru (6) Add: an permi · , i. poo1 . ..'" .. . ........ proPer.";diStance from prop n" ~ '."',': dist f oth r ell )er ance rom e 'w s ..... ',.~ ........... ~.d acreage available in this pool' ~- . ... ed ':and' is Well bore plat included ':,.~ '"°nlY affected party ' - .... I · ® I'e · ® · · · · · · · ® ® *~ e'e ® ·· .'"· · · · · · · i · · approved.:. before ten-day wait ' · · · · · · · eee~e®eeeee, eee e e e · . . operator ~ihave bond in force ' ~ Does . · · a e®e®®eeeeeeeeee®eeee~eeeeeeee®eeee . Is 'a conservation order needed ~ ' eee®e®®eee®®®eeeeeeeeeeeeee®eeeeeeeeee "<I's., administrative approval needed " fl~ ee®e®eeeee®eeee'eee®®eeeeeeeeeeeeeee 13 14. 15. 16. 17. 18. 19. 20. Is conductor string provided ........... ~ ............ ,~, Is enough Cement used to circulate'on ;~;~;;;o; ;;~ s;;~;~e ... 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, t;;;i~n ;nd burst.. Is this well to be .kicked off from an existing we!lbore ............. Is old wellbore abandonment procedUre included on 10-403 ............ ~/~o Is adequate well bOre separation proposed ................ '...- ........ 21. 22. 23. 24. Is div system req ired ' ~/z~ a' erter u ....................................... _ Are necessa, ry diagrams of diverter and BOP equipment attached ....... Mf~/~ Does BOPE have sufficient pressure rating - Test to ~e~Z) psig ..~ ' Does the choke manifold comply w/API RP-53 (Feb.78) .................. 25. Additional requirement s ............................................. Additional Remarks:/~E%~A o HO 03,-3 Geology: 'Engkn~ing: 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 effod has been made to chronologically organize this category of information. V~RIFICA'rION LISTING VERIFICATION bISTING PAG~ 1 ** REEL HEADER ** SERVICE NA~E :EDIT DATE :84/10/2! ORIGIN : REEl, NA~E : CONTINUATION PREVIOUS R~E[, : COMMENTS : ** TAPE HEADER ** SERVICE NAME :EDIT DATE :84/10/21 ORIGIN :0000 TAPE NAME :9595 CONTINUATION # :01 PREVIOUS TAPE : COMMENTS : ** FILE HEADER ** FILE NAME :EDIT ,001 SERVICE NAME VERSION # : DATE : MAXIMUM LENGTH : 1024 ~ILE TYPE PREVIOUS FILE : ** INFOrmATION RECORDS RECORD TYPE 137 ** ~NEM CONTENTS WN : 2D' 3 FN ~ KUPARUK RANG: qE TOWN': llN SECT: ~6 CTRY) USA ** CO~NTS ** UNIT TYPE CATE SIZE CODE 000 000 O24 0~5 000 000 004 065 000 000 OOB O65 000 000 00~ 065 000 000 004 065 000 000 002 065 000 000 012 065 000 000 006 065 000 000 003 065 SCHLUMBERGER LVP O]~O.HO2 VERIFICATION LISTI~!G PAGE 2 ALASKA DIVISION COMPUTING CENTER COMPANY = ARCO Ai. ASKA INC WELL = 2D-3 FIELD = KUPARtJK COUNTY = N,SLOPE STATE = hLASK SECTION = 26 TOWNSHIP :llN ~ANGE : 9E TAPE DENSITY = 800 BPI JOB ~ 69595 BASE LOG: DIL , RUM ~ ~ .DATE bOGGED 8 OCT ~98 BOTTOM LOG INTERVAL = 79~0 FT, TOP LOG INTERVAL CASING-LOGGER : 9,625 IN, BIT SIZE : 8.500 IN, TYPE HOLE FbUI[) : WT, PObY DENSITY = 9,80 VISCOSITY = 37.00 3624 ET, LVP 0!0,t,,,I02 VERIFICATION LISTING PAGE 3 PH FLUID bOSS RM ~ ~EAS, TE~P, RMF M MEAS, TE~P, R~C ~ MEAS, TEMP, R~ ~ BHT MATRIX g 5O 7:20 3,500 ~ 68 F 4.050 ¢ 68 F 2 200 ,a 68 F ]:726 ~ 145 F SANDSTO~JE LDPt T HALSTEAD ** DATA FORMAT RECORD ** ENTRY BLOCKS TYPE SIZE REPR CODE ENTRY 2 1 66 0 4 1 66 8 4 73 60 9 4 65 ,lin 16 ~. 66 0 I 66 0 DATUM SPECIFICATION BLOCKS ~NE~ SERVICE SERVICE UNIT AP! API API API FILE SIZM SP[., REPR ID DEPT SFbU DIL DIL SP DIL GR, DIL GR FDN CALI FDN RHOB FDN DRHO FDN N'RAT FDN RNRA FDN NPH! FDN NCNb FDN FCNb FDM ORDER ~ LOG TYPE CLASS MOD N'O, CODE (OCTAL) FT O0 000 O0 0 0 4 ! 68 00000000000000 OHMM O0 220 O1 0 0 4 1 68 00000000000000 OH~ O0 ~0 46 0 0 4 1 68 00000000000000 OH~ O0 120 44 0 0 4 ~ 68 00000000000000 MV O0 010 01 0 0 4 1 68 00000000000000 GAPI O0 310 O1 0 0 4 1 68 00000000000000 GAPI O0 3!0 O1 0 0 4 1 68 00000000000000 IN O0 280 O1 0 0 4 1 68 00000000000000 GIC3 O0 350 02 0 0 4 I 68 00000000000000 G/C3 O0 35b O! 0 0 4 ! 68 00000000000000 O0 420 O! 0 0 4 1 68 00000000000000 O0 000 O0 0 0 4 1 68 00000000000.000 Pti O0 ~gO O0 0 0 4 1 68 00000000000000 oo o o I o o § ooooooo CPS O0 3 30 0 0 4 68 0 0 0000000 ** DATA ** DEPT 7762,5000 SFLU 3,2715 ILD 2000,0000 3,0430 VERIFICATION LISTING PAGE 4 SP -48 0000 GR ~HOB ~!4629 DRHO NPHI 51 8066 NCNL DEPT 7700 0000 SYLU SP -5115000 GR RHOB 2 4414 DRHO NPHI 34 52~5 NCNL DEPT 7600 0000 SFLU SP -71:2500 GR RHOB 2.2871 DRHO NPHI 30,7617 NCNL DEPT 7500.0000 SFLU SP -57,5695 GR RHOB 2.3906 DRHO NPHI 29.7852 NCNL DEPT 7400,0000 SFLU SP -54 0313 GR R~OB 2ii4043 DRHO NPHI 43 0664 NCNL D£PT 7300,(.)000 SFbU SP -54,5625 GR RHOB ~.3125 DRHO gPNI 5 .~906 NCNL DEPT 720~,0000 SFLU SP -6 ,5313 GR RHOB 2.3457 DRHO NPHI 45.3613 NCNL 7!oo8.oooo SP . 5 ,0313 GR RHOB 99~.2500 DRHO NP~I -~)9. ,2500 NCNL DEPT 6900 Sp -62 ~PHI -99 00~ SFLU 25 0 DRHO 2500 NCNL DEPT SP RHOB N'PHI 6flO0,O000 %64,~000 -999, 500 -999.2500 SFLU GR DRHO NCNb 41, 0938 GR 963,0000 FCNL 6,6.]28 ILD 9],0000 GR 0,1348 NRAT ~860,0000 FCNL 20.7656 IhD 53.9062 CR 0.0244 NRAT 2738.0000 FCNI., 8.8594 ILD 75,8125 GR 0.0273 NRAT 2560,0000 FCNL 2,1758 ILD 130,2500 GR 0,0317 NRAT 1898.0000 FCNL 4 4297 ILD 213,t250 GR 0,0513 NRAT 17~7.0000 FCNL 4,~398 IhD 239, 000 GR 0,0000 NRAT 1821.0000 FCNL 3,9297 250,5000 -999,2500 NRAT '999'2500 3,8320 ILD 152,1250 GR '999,2500 N'RAT -999,2500 FCNL 3 2637 ILl) 123,t875 g~ , 5 6016 ILD 108,,9375 GR ~999,2500 N'RAT -999,2500 FCNL 41 0938 3:9707 219.8750 4,9883 93.0000 3,0957 559.5()00 23.78t3 53.9062 2 8379 889:5000 7,4063 75,8125 2,8027 797,5000 2,1738 130,2500 3,6719 453,2500 2,9043 213,1250 4,0508 402.5000 3,4023 239.,5000 3.7832 426,2500 2 9648 25 :sooo -9999 2500 -99 ; 2500 3,0605 '999.2bu -999,2500 ~,9668 1.23,1~75 '999 -999~ 500 3,8789 .108,9375 999~2500 -999.2500 CALl RNRA IbM CALl RNRA IbM CALI IbM CAI, 1 RNRA ILM CALl R M R A CA L,I RNRA CALI RNRA ,I L !~ CALl RNRA I LN CALl RNRA I LM CALI RNRA CALl RNRA 8,5000 4,3789 5,4B05 9,3359 3,3242 24.3750 9,0703 3,0781 8,2891 9,4219 3,2090 2,2051 0 6953 14:1875 3,0801. 10,4219 4,2891 3,5078 1,~5156 .2695 3,1309 9.8125 -999.2500 3,0742 10,~437 -999. 500 2,9746 10,1328 '999,2500 3,9043 1~,5547 '99 .2500 bVP 0!0,H02 YERIFICATION LISTING PAGE 5 OEPT RHOB NPHI DEPT SP ~HO8 NPHI DEPT SP RHOB NPHI DEPT 8P RHOB NPHI DEPT SP RHOB NPHI ,OEPT SP NPHI DEPT BP RHOB NPHI SP RHOB NPHI DEPT SP RHOB NPHI DE T SP RHOB NPHI DEPT SP RHOB MPHI 6700 0000 SFLU -6~i5313 GR -999 2500 DRHO -999 2500 NCNb 6,0430 ILD 123,6250 GR '999,2500 NRAT '999.2500 FCNL 6.600i0000 SFLU 28 1250 GR -999 2500 DRHO -999,2500 NCNL 3,1074 IbD 146,5000 CR -999,2500 NRAT -999,2500 FCNL 6500 0000 SFLU -37:5938 GR -.999,2500 DRHO 999.2500 NCNb 3,8418 ILD 122,1875 GR -999'2500 NRAT -999,2500 FCNL 6400.0000 SFLU ~40,7813 GR - 99,2500 DRHO -999,2500 NCNL 3,9883 ILD 126,8750 GR -909.2500 NRAT -999,2500 FCNL 6~0 0000 SFLU 5~969 GR "999.2500 DRHO -999,2500 NCNb 2.1250 ILl) 207.5000 GR -999,2500 NRAT -999,2500 FCNI, 200,0000 SF[,U -26,0625 GR 999.2500 DRHO -999.2500 NCNL I 6494 148:sooo GR T -999,2500 NRA -999,2500 FCNL 6i.~0,0000 SFLU 84, GR -999,2500 NRAT -999,2500 FCNL 6000 -34 -999 -999 0000 SFLU 4063 GR ~500 DRHO 2500 NCNL 2,5234 ILD 110,8125 GR -'999 2500 NRAT .{)09:25oo 1.9oo. 999,2500 999, ~500 SFLU ~R DRHO NCNL 3,4102 IbD 96,0625 (;R 9. ,2500 FCNL 5800 0000 SFLU 3,3281 'IbD -38:8125 GR 92,1250 GR '999,2500 DRHO "999,2500 NRAT '999,2500 NCNb '999.2500 FCNL 5709,0000 -3.,8125 -999,~500 -909. 500 SFLU GR DRHO NCNL 2,~133 :ILO 1o8, 875 UR -999,~500 NRAT ~999, 500 FCNL 3,8457 123.6250 2999,2500 999.2500 3,328! 146 5000 -999~2500 -999,2500 3 8203 1.22:1875 -999,2500 '900,2~00 3.6270 126,8750 -999.2500 -999,2500 1,6699 207,5000 '999,2500 '999.2500 1,34~B ,5000 '9 , 500 -999,2500 2 ~008 ~999' 500 999'2500 -999.2500 ~ 5684 -999,2500 -999,~500 -999,2500 3.~766 -999, 500 ,2500 3,3359 '999,2500 '999,2500 -999.2500 .99~ ,6445 ,2500 -999,2500 -999.2500 ILM CALI R!IRA IL~ CAhI R~,~RA CALI RNRA IbM CALI RNRA IbM CALi RI'~RA IbM CALI RNRA I LM CA£,I RNRA I CAbI RNRA I CALl R NRA IL~ CALI RNRA I[,,M CAbI R N R A 3,9863 9,9141 '999,2500 3,2402 10.9766 '999,2500 3 8770 11i6484 -999 2500 3,6426 10.8203 -999,2500 1,7539 9,6641 -999,2500 1,4297 10'I~19 -999. O0 2,~848 :999,2500 999,~500 2 6074 -999!2500 -999 2500 3,4590 -999,2500 -999,2500 3,3398 -999,2500 '999.2500 2,6367 -999,2500 -999.2500 LVP 010,H02 VE~IFIChT]'.ON LISTING PAGE 6 DEPT 5600 0000 SFLU SP -41:5625 GR RH~R -999,2500 DRH(') NPMI -999,2500 NCNL DEPT 5~00,0000 SFLU SP 39.0313 GR RHOB -999,2500 DRHO NPHI -999,2500 MCNL DEPT ~400,0000 SFbU SP -41,5625 GR RMOB g99.2500 DRHO NPHI -999,2500 NCNb DEPT 5300. 0000 SFLU SP -42.5313 GR RHOB 999 2500 DRHO P.z :o99:.25oo DEPT 5200 0000 SFLU SP 38' - 7813 GR RHOg 999' - 2500 DRHO NPHI -999,2500 NCNL DEPT 5100 O000 SFLU SP -36:2813 GR RHOB -999,2500 DRHO NPHI -999.2500 NCNb DEPT 5000 0000 SFLU , SP -38,5625 GR RHOB -999,2500 DRHO NPHI -999,2500 NCNL DEPT SP RHOB NPHI DEPT SP RHOB NPHI DEPT SP RHOB NPHI DEP'I SP 4~00 O0O0 35 5313 -999 2500 -999 2500 SFLU GR DRNO NCNb 4800,0000 SFLU -44,7813 GR '999,2500 DRHO -999.2500 NCN]] 4:00,0000 SFLU .45.0313 GR 999,2500 DRHO -999,2500 NCNL 4600,0000 SFLU -45,7813 GR -999.2500 DRHO 2.5410 1ED 112.5000 GR -999,2500 NRAT -999,~500 FCNL 2,8164 ILD 1.02.8125 GR '999.2500 NRAT '999.2500 FCNL 2,5371 ILD 108,1250 GR -999,2500 NRA'I' -999,2500 FC.Nb 2,2852 II.,O 101.3750 (;R '999.2500 NRAT -999.2500 FCNL 4 8594 70,2500 GR "999,2500 NRAT '999.2500 FCNL 2 5137 , 111,7500 GR '999,2500 NR. AT " N '999,2500 FC b 2 4805 I'LD 88i9375 GR '999 2500 NRA~' -999,2500 FCNL ,I 035 ILl') 8 , 375 GR '99q,2500 .NRAT -.999.2500 FCNL 2,3555 ILO '99q, NRAT -999. 2500 FCNL 2,~695 102. 875 -999,2500 NRAT -999.2500 FCNL 3 3926 ILD 82i9375 GR -9'99 2500 MRAT 2 6465 -999:2500 -999.2500 -999.2500 2.8203 -999,2500 -999,2500 -999,2500 2,6660 -999,2500 -999,2500 -999,2500 2.4844 -999.2500 :§ 9. soo 99.~500 3,~055 '999,2500 '999,2500 '999.2500 2.7148 '999,2500 '999.2500 '999,2500 2,4336 -999,2500 -999.2500 -999,2500 2,2988 -999.2500 -999,~500 -999, 500 2 6328 -999 2500 -999 2500 -999 2500 2,4551 -999.2500 -999,2500 -999.2500 3,6()55 -999,2500 '999.2500 ILM CALl IbM CALl RNRA I LM CALI IbM CALI RNRA I LM CALI R N'RA CALI RNRA ILM CALI RNRA I LM CAt, I RNRA CALI RNRA I LM CALl R t, iRA I b M C A L I R i~i R A 2 6582 -999i2500 -999 2500 2,8203 -999.2500 -999,2500 2.6621 -999.2500 -999.2500 2,4707 -999,2500 '999.2500 3,5137 =999,2500 -999,2500 2,6465 :999.2500 999,2500 ,2500 99,2500 2,248(3 -999,2500 -999,2500 2,5605 -999,~500 '999, 500 ,2500 -'999,250(') 3.4902 -999~2500 -999,2500 [,VP 010.H02 VERIFICATIrlN LISTIN(; PAGE 7 NPHI -999.2500 NCNb -999 DEPT 4500. 0000 SFLU 4 SP -34,5313 GR 91 RHOB -999. 250u DRHO -999 NPHi -q99.2 500 NCNb '999 DEPT 4400,0000 SFI..U 5P -45,8125 RHOB '999.~500 DRHO '999 NPNI -999.2500 NCNL -999 DEPT 4300 0000 SFLU BP -47i5625 G~ ~HOB -999'2500 DRHO NPHI -999.~500 NCNb 2 107 -999 -999 DEPT 4200.0000 SFI..,U 3 SP -53.2813 GR. 106 RHOB -999.2500 DRHO -999 NPH1 -999.2500 .qCNL 99 DEPT 410{) 0000 SFLU BP -53:281,3 GE RHOB -999.2500 DRHO NPHI -999,2500 NCNb DEPT 4000 0000 SFLU SP -57,7500 GR RHOB -999,2500 DRHO NPHI. -999,2500 NCNb DEPT 3~00,0000 SFLU SP 61.0313 GR RHOB -999,2500 DRHO NPHI -999.~500 NCNb DEPT ]~00,0000 SFLU SP '62,0313 GE RHOB -999.2500 DRHO NPHI -999.2500 ,'JCNL 3 -999 -999 3 94 -999 -999 4 ~5 -999 -999 6 73 -999 -999 DEPT 3100 0000 SFLU 24 RHOB -999 2500 DRHO 999 NPHI -999: 2500 MCN[., ~999 OEPT 3600.0000 SF[,U SP -25,8281 GR RHOB 999,2500 DRHO NPHI 2999,2500 NCNb DEPT 3~91 5000 SFb[J SP 26:a437 GR !2 48 -999 -999 17 5! .2500 500 ,2500 .2500 .4883 ,6250 .2500 .2500 959O ,2500 ,2500 ,2500 3359 ,0625 ,2500 ,2500 0488 : ooo , 5 00 ,2500 9707 3125 25OO .2500 7852 '6250 . ,2500 .2500 4336 ,9375 ,2500 .2500 ,1094 ,6250 2500 :2500 ,9531 ,6563 ,2500 ,2500 ,4375 ,0625 FCNL ILD NRAT FCNL ILO GR NRAT FCNI I LD GR NRAT FCNL ILD GR NRAT F C N .b I I..,D GR NR AT FCNI, ILO GR NRAT FCNL I bD GR NRAT FCNL ILO G~ NRAT FCNL IbD GR NNAT FCNL It, O GR NRAT FCNL G~ -999.2500 5,2266 '99912500 '999,2500 -999.2500 5.8711 -999,2500 '999,2500 -999.2500 3,9711 -.999. 500 -999,~500 -999. 500 3,7617 -999 ~500 -999:500 -999,2500 g,4219 '99 '2500 -999,2500 -999,2500 4,5547 2999,2500 999.2500 '999,2500 5,2773 '999.2500 '999 2500 '999;~500 6,8203 -999,2500 -999,2500 -999,2500 15.2656 -099.2500 -999,2500 -999.2500 10.8594 -999.2500 -999,2500 -999,2500 10,9375 '999.2500 CAhl R~RA I h~ CALI R N R A. I l.,,N C .;% b ,I RNR A IbM CALI RN'R A IbM CA. bI RNRA I I.,M CgI, I R NRA IbM CALI RNRA CAi, i RNRA IbM CALl RNRA CALI RNRA 4,9727 .-999,2500 999.2500 :2383 -99 2500 -999,2500 3,2695 '999,2500 '999,2500 3,6074 -.999 2500 §99'2500 . 3,2773 -999.2500 -999,2500 4.25O0 :999,2500 999.2500 5,1797 99,2500 6,5664 -999.2500 -999,2500 ~7.5000 -999.2500 -999.2500 2000,00O0 -999.2500 -999,250O ~000,0000 999.2500 bVP OlO.H02 VERIFICATION LISTING PAGE 8 RHOB 999,2500 Da. HO -999,2500 NRAT -999,2500 NPWI :q99.2500 NCNI, -999.~500 FCNL -999.2500 ** FILE TRAIt, ER ** FIbE NA~E :EDIT .0ol SERVICE NAME : VERSION # : DATE : WAXI~U~ LENGTH : 1024 FILE TYPE : NEXT FILE NA~E : ** R~;CORD TYPE 137 RNRA -999,2500 ** TAPE TRAILER ** SERVICE NAME :EDIT DATE :84110/2l ORIGIN :0ooo TAPE NA~4E :9595 CONTIMi,~ATION ~ :0~ NEXT TAPE NAME : COMMENTS : ** REEt, TRAILER SERVICE NAME DATE ORIGIN : REEL NAME CONTIWUATION NEXT REEL NA.ME COMMENTS : ** RECORD TYPE 137 ** ** RECORD TYPE 137 ** ********** EOF ********** ********** EOF **********