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Home My WebLink About195-1481. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Tubing Patch Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 9480'feet None feet true vertical 6235' feet 7711', 9215'feet Effective Depth measured 9170'feet 7717', 7741', 7777'feet true vertical 6068' feet 5268', 5281', 5303'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" J-55 7780' MD 5316' TVD Packers and SSSV (type, measured and true vertical depth) 7717' MD 7741' MD 7777' MD 519' MD 5268' TVD 5281' TVD 5303' TVD 519' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 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: N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 864 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: P2P Patch Packer Packer: P2P Patch Packer Packer: Baker H Liner Top Iso Packer SSSV: Camco DS Landing Nipple Katherine O'Connor katherine.oconnor@conocophillips.com (907) 263-3718Senior Well Intervention Engineer 8814-8842', 8849-8964', 8976-8980', 8996-9001', 9220-9250' 5867-5883', 5887-5953', 5959-5962', 5971-5973', 6095-6112' measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 219 Gas-Mcf MD 792 Size 118' 2371 1295781 73 1871310 183 measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 195-148 50-029-21380-01-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A ADL5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025653 Kuparuk River Field/ Kuparuk River Oil Pool KRU 2Z-12A Plugs Junk measured Length Production Liner 7909' 1710' Casing 5398' 3-1/2" 7942' 9480' 6235' 4393' 118'Conductor Surface Intermediate 16" 9-5/8" 83' 4428' 3357' Burst Collapse Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Samantha Carlisle at 3:39 pm, Feb 09, 2023 Digitally signed by Katherine O'Connor DN: CN=Katherine O'Connor, O=ConocoPhillips, OU=Wells Group, E=katherine.oconnor@conocophillips.com, C=US Reason: I am the author of this document Location: Date: 2023.02.09 14:34:49-09'00' Foxit PDF Editor Version: 12.0.1 Katherine O'Connor DTTMSTART JOBTYP SUMMARYOPS 12/12/2022 OPTIMIZE WELL DRIFT W/ 2.75" DMY CA-2 PLUG DOWN TO 7772' RKB; SET 2.75" C-LOCK W/ ROCKSCREEN (6.6' OAL / 3- 1/8" SLOTS) @ 7772' RKB. READY FOR PATCH 1/1/2023 OPTIMIZE WELL SET 2.725" LOWER PIIP PACKER W/ MOE @ 7743' RKB CCL TO MID ELEMENT 10.3' CCL, CCL STOP DEPTH @ 7732.7' RKB CCL LOG CORRELATED TO TBG TALLY DATED 11/7/1995. JOB IS READY FOR SL SERIAL #: CPP35192 1/14/2023 OPTIMIZE WELL RAN 3 1/2" TTS TEST TOOL TO LOWER 2.725 P2P @ 7740' RKB & CMIT TBG X IA TO 2500 PSI (PASS); SET 2.725" P2P (CPP35350) MID ELEMENT @ 7720' RKB, SPACER PIPE, & ANCHOR LATCH (CPAL35191) @ 7717.5' RKB; RAN 3 1/2" TTS TEST TOOL TO UPPER 2.725 P2P @ 7717' RKB & MITT TO 2500 PSI (PASS); CMIT TBG X IA TO 2500 PSI (PASS). JOB COMPLETE. 2Z-12A Tubing Patch Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 9,170.0 2Z-12A 11/23/2022 fergusp Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set Patch 2Z-12A 1/14/2023 zembaej Notes: General & Safety Annotation End Date Last Mod By NOTE: 2Z-12A SIDETRACK (1/1/96): Old wellbore/completion/fish abandoned. 3/11/1998 WV5.3 Conversio n General Notes: Last 3 entries Com Date Last Mod By LEAK FOUND IN TBG BETWEEN 7720''-7651'' SLM - APPEARS TO BE @ GLM #3 9/10/2004 Admin SET DOWN W/ELINE @ 8035'' ELM. COULD NOT MOVE PAST OBSTRUCTION 7/23/2001 Admin Pressure tubing & Casing 3000 psi 6/24/1998 Admin Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 34.9 118.0 118.0 62.58 H-40 WELDED SURFACE 9 5/8 8.92 34.9 4,428.0 3,356.8 36.00 J-55 BTC PRODUCTION POST S/T 7 6.28 32.5 7,942.0 5,398.1 26.00 J-55 BTC LINER 3 1/2 2.99 7,769.8 9,480.0 9.30 L-80 EUE-ABMOD Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 21.2 Set Depth 7,799.6 Set Depth 5,315.7 String Ma 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade J-55 Top Connection ABM-EUE 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) 21.2 21.2 0.16 HANGER 8.000 FMC GEN IV TUBING HANGER 3.500 519.9 519.5 4.62 NIPPLE 4.540 CAMCO DS LANDING NIPPLE (2.856"NO GO) 2.900 3,351.0 2,727.7 55.09 GAS LIFT 5.312 MMH FMHO 2.867 5,963.0 4,238.4 54.28 GAS LIFT 5.312 MMH FMHO 2.867 7,726.6 5,273.4 54.73 GAS LIFT 6.018 CAMCO MMM 2.920 7,772.2 5,299.8 54.62 NIPPLE 4.540 CAMCO D NIPPLE NO GO 2.750 7,775.0 5,301.4 54.61 SEAL ASSY 5.000 BAKER LOCATOR SEAL ASSEMBLY FULLY STABBED INTO LINER HANGER ASSEMBLY 3.937 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 7,711.0 5,264.4 54.76 FISH 1 DOG FROM THE GS LEFT IN HOLE .5" X .2" 10/5/2021 0.000 7,717.5 5,268.2 54.75 PACKER - PATCH - UPR 2.725" P2P (MID ELEMENT @ 7720'), SPACER PIPE, & ANCHOR LATCH (23.86' OAL) TTS 2.725" P2P CPP3 5350 1/14/2023 7,721.1 5,270.3 54.74 ANCHOR LATCH ON SPACER PIPE SPACER PIPE & ANCHOR LATCH ATTATCHED TO UPPER P2P TTS CPAL 35191 1/14/2023 1.600 7,737.0 5,279.5 54.70 LEAK LDL WITH MULTIFINGER CALIPER: FOUND TUBING LEAK AT 7737' 12/4/2004 2.992 7,740.6 5,281.5 54.69 PACKER - PATCH - LWR 2.72" PARAGON II LOWER PACKER W/ MOE @ 7743' RKB, OAL = 4.01' TTS 2.72" P2P CPP3 5192 1/1/2023 1.625 7,772.0 5,299.7 54.62 SCREEN 2.75" C-LOCK W/ ROCK SCREEN (9.25' OAL) 12/12/2022 0.000 9,215.0 6,092.6 56.76 FISH 2.5" GUN 2.5" GUN, 1-11/16" TOOLS, 37.2' LENGTH - LOST 6/1998 6/1/1998 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) 3,351.0 2,727.7 55.09 1 GAS LIFT GLV BK 1 1,293.0 11/21/2020 0.188 5,963.0 4,238.4 54.28 2 GAS LIFT OV BK 1 0.0 11/21/2020 0.188 7,726.6 5,273.4 54.73 3 GAS LIFT DMY RK 1 1/2 9/26/2004 COVE RED BY PATC H 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,769.8 5,298.4 54.62 TIEBACK SLEEVE 5.750 BAKER TIEBACK SETTING SLEEVE 5.250 7,777.3 5,302.8 54.61 PACKER 5.875 BAKER H LINER TOP ISOLATION PACKER 4.312 7,787.9 5,308.9 54.58 PBR 5.000 BAKER PBR 4.000 9,382.6 6,183.5 57.61 LANDING COLLAR 3.500 BAKER LANDING COLLAR 2.992 2Z-12A, 2/9/2023 11:02:39 AM Vertical schematic (actual) LINER; 7,769.8-9,480.0 APERF; 9,239.0-9,249.0 IPERF; 9,220.0-9,250.0 APERF; 9,230.0-9,240.0 APERF; 9,220.0-9,230.0 FISH; 9,215.0 IPERF; 8,996.0-9,001.0 IPERF; 8,976.0-8,980.0 IPERF; 8,929.0-8,964.0 IPERF; 8,849.0-8,929.0 IPERF; 8,814.0-8,842.0 PRODUCTION POST S/T; 32.5-7,942.0 SCREEN; 7,772.0 PACKER - PATCH - LWR; 7,740.5 LEAK; 7,737.0 GAS LIFT; 7,726.6 ANCHOR LATCH ON SPACER PIPE; 7,721.1 PACKER - PATCH - UPR; 7,717.5 FISH; 7,711.0 GAS LIFT; 5,963.0 SURFACE; 34.9-4,428.0 GAS LIFT; 3,351.0 NIPPLE; 519.9 CONDUCTOR; 34.9-118.0 KUP PROD KB-Grd (ft) 30.89 RR Date 7/21/1985 Other Elev 2Z-12A ... TD Act Btm (ftKB) 9,480.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292138001 Wellbore Status PROD Max Angle & MD Incl (°) 65.13 MD (ftKB) 8,097.70 WELLNAME WELLBORE2Z-12A Annotation Last WO: End Date 11/4/1995 H2S (ppm) 100 Date 12/5/2018 Comment SSSV: NIPPLE Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 8,814.0 8,842.0 5,866.8 5,882.9 C-4, 2Z-12A 3/18/1996 4.0 IPERF 2 1/8" HC, 0 deg. ph 8,849.0 8,929.0 5,886.9 5,932.7 C-4, C-2, C-1, C- 2, 2Z-12A 4/7/1996 4.0 IPERF 2 1/8" HC, 0 deg. ph 8,929.0 8,964.0 5,932.7 5,952.6 C-4, C-2, C-1, 2Z-12A 3/18/1996 4.0 IPERF 2 1/8" HC, 0 deg. ph 8,976.0 8,980.0 5,959.4 5,961.6 UNIT B, 2Z-12A 3/18/1996 4.0 IPERF 2 1/8" HC, 0 deg. ph 8,996.0 9,001.0 5,970.7 5,973.5 UNIT B, 2Z-12A 3/18/1996 4.0 IPERF 2 1/8" HC, 0 deg. ph 9,220.0 9,230.0 6,095.3 6,100.8 A-4, 2Z-12A 1/1/1996 2.0 APERF 2.5" Titan BH, 0 deg pH, 90 deg CCW lowside 9,220.0 9,250.0 6,095.3 6,111.8 A-4, 2Z-12A 12/13/1995 2.0 IPERF 2 1/8" EJ/BH, 90 deg. low side 9,230.0 9,240.0 6,100.8 6,106.3 A-4, 2Z-12A 1/1/1996 4.0 APERF 2.5" Titan BH, 0 deg ph, +/- 90 deg lowside 9,239.0 9,249.0 6,105.7 6,111.2 A-4, 2Z-12A 1/1/1996 2.0 APERF 2.5" Titan BH, 0 deg ph, 90 deg CCW lowside 2Z-12A, 2/9/2023 11:02:39 AM Vertical schematic (actual) LINER; 7,769.8-9,480.0 APERF; 9,239.0-9,249.0 IPERF; 9,220.0-9,250.0 APERF; 9,230.0-9,240.0 APERF; 9,220.0-9,230.0 FISH; 9,215.0 IPERF; 8,996.0-9,001.0 IPERF; 8,976.0-8,980.0 IPERF; 8,929.0-8,964.0 IPERF; 8,849.0-8,929.0 IPERF; 8,814.0-8,842.0 PRODUCTION POST S/T; 32.5-7,942.0 SCREEN; 7,772.0 PACKER - PATCH - LWR; 7,740.5 LEAK; 7,737.0 GAS LIFT; 7,726.6 ANCHOR LATCH ON SPACER PIPE; 7,721.1 PACKER - PATCH - UPR; 7,717.5 FISH; 7,711.0 GAS LIFT; 5,963.0 SURFACE; 34.9-4,428.0 GAS LIFT; 3,351.0 NIPPLE; 519.9 CONDUCTOR; 34.9-118.0 KUP PROD 2Z-12A ... WELLNAME WELLBORE2Z-12A C:\Users\mdguhl\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\LCF4WGUY\2022-11-23_22060_KRU_2Z-12A_CaliperSurvey_LogData.docx DELIVERABLE DISCRIPTION Ticket #Field Well #API #Log Description Log Date 22060 KRU 2Z-12A 50-029-21380-01 Caliper Survey w/ Log Data 23-Nov-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 ______________________________ ______________________________________ 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 By Meredith Guhl at 9:59 am, Nov 29, 2022 195-148 T37318 Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.11.29 10:02:23 -09'00' \J ConacoPhillips a~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 17, 2010 Mr. Dan Seamount Alaska Oil & Gas Commission 333 West 7~` Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Dan Seamount: ~~j r.., ~,. = ~~ ~~j,.t ~ ~~ ~~ ~~-~ ~~~a~~' .. APR 2 ~~ 2010 '+aska %ui~ ~ has fans. ~:amm~ssio~ . anchorage ~o~s-i~-~a~ a~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRTJ). 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 January 16, March 21, 2010. The corrosion inhibitor/sealant was pumped April 15, 16 and 17, 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Projects Supervisor ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field 4/17/2010 2B_ 2E. 2G_ 2H_ 2K_ 2M_ 2V_ 2W_ 2X_ 2Z & 3S PAD's 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 2B-05 50029210670000 1840040 24" n/a 24" Na 4.2 4/16/2010 2B-08 50029210790000 1840260 21" 3.30 7" 1/16/2010 2.5 4/16/2010 2B-16 50029211460000 1841140 92" 0.65 3/21/2010 2.5 4/16/2010 2E-10 50029212460000 1842300!. SF Na n/a n/a 5.9 4/16/2010 2E-17 50029224190000 1531740 8'9" 1.50 19" 1/16/2010 3.4 4/16/2010 2G-13 50029211600000 1841290 SF n/a 22" n/a 3.4 4/16/2010 2H-07 50103200450000 1851700 SF n/a 17" Na 2.1 4/15/2010 2H-09 50103200500000 1852590 SF Na 17" n/a 2.5 4/15/2010 2H-15 50103200340000 1840860 SF n/a 17" n/a 2.5 4/15/2010 2H-16 50103200350000 1840870 SF n/a 17" Na 2.5 4/15/2010 2K-19 50103201180000 1891090 53" 0.50 9" 1/16/2010 2.1 4/15/2010 2M-07 50103201780000 1920800 SF n/a 17" Na 3.4 4/15/2010 2M-08 50103201840000 1921010 SF n/a 17" Na 2.1 4/15/2010 2M-20 50103201690000 1920480 SF n/a 17" Na 2.5 4/15/2010 2M-22 50103201700000 1920490 SF n/a 17" Na 2.5 4/15/2010 2M-28 50103201740000 1920700 SF Na 18" Na 2.1 4/15/2010 2V-06 50029210540000 1831790 SF Na 19" Na 7.6 4/16/2010 2V-10 50029213100000 1850480 SF n/a 19" Na 2.5 4/16/2010 2V-16 50029212960000 1850330 SF Na 21" Na 5.1 4/16/2010 2W-03 50029212740000 1850110 SF Na 37" Na 4.2 4/16/2010 2X-11 50029211880000 1841640 SF Na 17" n/a 6 4/17/2010 2Z-11 50029213790000 1851380 SF n/a 19" n/a 2.5 4/15/2010 2Z-12A 50029213800100 1951480 SF Na 19" Na 2.5 4/15/2010 ZZ-13A 50029213600100 2061700 SF Na 22" n/a 4.25 4/15/2010 2Z-19 50029218820000 1881300 SF n/a 16" n/a 2.1 4/15/2010 3S-o9 50103204320000 2022050 SF Na 45" Na 23 4/17!2010 'Rt:r't:\\Jì=D \. 1- '>t.w:! i- I ~ i ¡I ¡ 0~ .') ,.~ "'!lO.6 '.. \.,;" ~ tJ ¿'oJ Schlumbel'gel' -"'; .-...... ·~r-mmi~~¡rJ1 .\~ ¡'';~;~ ~\....Gns. \.;V1!!1"~" And'!Craqe Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth ~1 C\{ -- \ \ SCANNED JUN 2, 3 ZGGB Well Job # Log Description Date 1 F-06 11249918 PRODUCTION PROFILE W/DEFT 06/13/06 1 F-20 11320984 PRODUCTION PROFILE W/DEFT 06/12/06 1A-15 11249917 INJECTION PROFILE 06/12/06 2T -40 11249919 SCMT 06/14/06 2M-20 11235372 PRODUCTION PROFILE 06/18/06 3G-12 11320978 INJECTION PROFILE 06/01/06 1Y-27 11235341 PRODUCTION PROFILE WIDEFT 02/26/06 3M-21 11213734 INJECTION PROFILE 04/04/06 2Z-12A 11216199 MEMORY PRODUCTION PROFILE 06/04/06 1 A-22 11213761 PRODUCTION PROFILE W/DEFT 06/15/06 06/22/06 NO. 3858 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk BL Color CD 1 1 1 1 1 1 1 1 1 1 .- 'D Please sign and return one copy of this transmittal tCi~ above address orfax to (907) 561-8317, Thank you, Schlumberger Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # RECE1\/ED ; ! \~ HQ '7rnR ,,"-,... ''''; ;_"-J";U ... ¡ .....,.....~ c. ..ö~~(,.;;;;. ,ì (}as Cens. C.crruri$SlCO \.r.{:x..~çß ~. {: 20(\: Date NO. 3831 Company: Field: BL 06/02/06 Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 d Anchorage, AK 99501 . ~. '0 (] [....\ Kuparuk \_, 0 e Log Description Color CD 1Y-12 i"'iS"~-f~'~( 11235362 INJECTION PROFILE OS/20/06 1 1L-06 i~4- ¡::\Z 11213748 PRODUCTION PROFILE W/DEFT 05/19/06 1 1Q-24 }C;Ç-- liJi 11213849 INJECTION PROFILE OS/20/06 1 1H-04 11),:)-I~~ 11213752 INJECTION PROFILE OS/23/06 1 1H-08 J~":)-(-A 11213751 RST/WFL OS/22/06 1 22-02 /'7r? - ~'Xè 11235362 INJECTION PROFILE 05/28/06 1 1 H-16 ¡<~~ - i~f 11235365 PRODUCTION PROFILE W/DEFT 05/24/06 1 2A-04 ¡ 15«- cS" 11213755 CROSSFLOW DETERMINATION 05/26/06 1 31-10 /¡{<7 -r'~1 11213759 PRODUCTION PROFILE W/DEFT 05/30/06 1 1H-19 ,.Cì.':)-I;J~ 11320975 INJECTION PROFILE OS/29/06 1 2A-13 i4-~ -1'1'- 11320976 LDL 05/30/06 1 22-04 1*3-¿~ 11213757 INJECTION PROFILE OS/28/06 1 q.-S. - N~ 1123568? GLS 05/27/06 1 3F-02 / t:J(~~ -.:J~( 11213758 PRODUCTION PROFILE W/DEFT 05/29/06 1 c-M -- e Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Schlumberger Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Well Job # 181- 7-/1 1F-02 /95 ~Ð1.'L 2T-23 :;;- 2W-12 1~'f22-cf 2Z-19 IfS-I'j[) 1C-111 ~/'l2.. <6 1C-117 ~Ð{- /-¿ { 3F-14 / 8'5- ~..72 2K-07 Q 2Z-12A I 07.., 07 ( f 15-/rfð 10922513 10952507 10942806 10922502 10922504 10922505 10922499 10922503 10922501 Log Description Date INJECTION PROFILE LEAK DETECTION LOG PRODUCTION PROFILE LEAK DETECTION LOG INJECTION PROFILE INJECTION PROFILE PRODUCTION PROFILE PRODUCTION PROFILE LEAK DETECTION LOG 12/14/04 12/08/04 12/15/04 12/04/04 12/06/04 12106/04 12/03/04 12/05/04 12/04104 ) r ~ '~C ' N" ·~i==· i} PO -; RÕ, 2005 j))W~ :;¡ .A,~l::t,.." do NO. 3292 Company: 12/23/04 tq~-Ilfr Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk BL 1 1 1 1 1 1 1 1 1 DATE: ~. Color CD ~ TI-IF, MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON 'OR BEF.ORE JANUARY 03,2001 M PL A T E E W IA L UNDER T H IS M ARK ER C :LORI~'IF~M.DOC MEMORANDUM TO: Julie Huesser, Commissioner State of Alaska Alaska Oil and Gas Conservation Commission DATE: December 1, 2000 THRU' Maunder, Tom P. I. Supervisor. FROM' Chuck Scheve; SUBJECT: Petroleum InspeCtor Safety Valve Tests Kuparuk River Unit 2Z Pad Friday, December 1, 2000: I traveled to the Kuparuk River Field and witnessed the semi annual safety valve system testing on 27_ Pad. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 12 wells and 24 components with two failures observed. The surface safety valve on wells 2Z-7 and 2Z-10 had slow leaks when pressure tested. These two valves will be serviced and retested by the operator. ' Earnie Barndt conducted the testing today he demonstrated good test procedure and was a pleasure to work with Summary:. I witneSsed the semi annual SVS testing at 2Z Pad in the Kuparuk River Field, KRU 2Z Pad, t2 wells, 24 components, 2 failures 8.3% failure rate Attachment: SVS KRU 2Z Pad 12'1-00 CS X unclassified Confidential (Unclassified if doc. Removed) sVs KRU 2Z Pad 12-1-00 CS.doc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Operator Rep': Ernie Bamdt AOGCC Rep: Chuck Scheve - Submitted By: Chuck Scheve Date: Field/Unit/Pad: Kupauk / KRU / 2Z Pad Separator psi: LPS 100 HPS 12/1/00 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE 2Z-01 1830730 100 . 70 I- 70 P P OIL! 2Z-02 1830800 2Z-03 1830850 2Z-04 1830860 2Z-05 1830760 100 · 70 70 P P OIL 2Z-06 - 1830770 3700 2000! 2000 P P WAG 2Z-07 1830640 100 701 65 P 4 OIL 2Z-08 1830380 2Z-09 1851360 2Z-10 1851370 100 70 70 P 4 OIL 2Z-11 1851380 2Z-12A 1951480 100 70 50 P P OIL 2Z- 13 1851060 2Z-t4 1851070 2Z-15 -1851080 3700 2000 1700 P P WAG · 2Z-16 1851090 2Z-18 1881330 100 70 65 P P OIL 2Z-19 1881300 100 70 65 P P OIL 2Z,20 1881240 100 70 100 P P OIL! 2Z-21 1881250 100 70 70 P P OIL i2Z-22 . 1941470 12Z-23 1950100 2Z-29 1881290 100 70 70 P P OIL 2Z-WS1 1851580 Wells: 12 Components: 24 Failures: 2 Failure Rate: 8.3% [290 oar Remarks: -Surface Safety Valves On wells 7 & 10 had slow leaks when pressure tested. They ar serviced and retested by the Operator. · 19M/fWi Page 1 of 1 SVS KRU 2Z Pad 12-1-00 CS.xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate X Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development X. 97' RKE 3. Address: Exploratory__ 7. Unit or Property: P.O. Box 100360 Stratagrapic__ Anchorage, AK 99510-0360 Service __ Kuparuk River Unit 4. Location of well at surface: 8. Well number: 1298' FSL, 75' FWL, Sec 12, T11N, R9E, UM 2Z-12A At top of productive interval: 9. Permit number/approval number: 1586' FSL, 1984' FEL, Sec 13, T11N, RgE, UM 95-148 At effective depth: 10. APl number: 1159' FSL, 1703' FEL, Sec 13, TllN, RgE, UM 50-029-21380-01 At total depth: 11. Field/Pool: 1026' FSL, 1638' FEL, Sec 13, TllN, RgE, UM Kuparuk River Field / Oil Pool 12. Present well condition summary Total Depth: measured 9480 feet Plugs (measured) None true vertical 6235 feet Effective Deptt measured 8617 feet Junk (measured) None true vertical 5753 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 255 Sx PFC 118' 118' Surface 4393' 9-5/8" 1300 Sx CS III & 4428' 3357' 500 Sx CS II Production 7909' 7" 375 Sx Class G & 7942' 5398' 250 Sx PFC Liner 1710' 3-1/2" 330 Sx Class G 9480' 6235' Perforation Depth measured 8814'-8842'; 8849'-8964'; 8976'-8980'; 8996'-g001'; 9220'-9250' true ved'ical 5867'-5883'; 5887'-5953'; 5959'-5962'; 6+82'-5974'; 6095'-6112' Tubing (size, grade, and measured depth) 3.5", 9.3 lb/*, J-55 @ 7775' ~"~'" Packers and SSSV (type and. measured depth) Packer: Baker H @ 7777'; SSSV: None, Camco DS Nipple @ 520' () '.;'-~ % © '? .... 13. Stimulation or cement squeeze summary Fracture stimulate "C" sand on 6/27/98,- . ~j Intervals treated (measured) ' 8814'-8842'; 8849'-8964' Treatment description including volumes used and final pressure Pumped 221,363 lbs of 16/20, 12/18, & 10/14 ceramic proppant into formation, fp was 8050 psi. 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 16 4 327 1270 206 Subsequent to operation 197 204 1993 1414 248 15. Attachments MIT form 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations_ZX Oil X Gas Suspended Service 17. I hereby/~_/~ J~ ~certify tlat the foregoing is true and correct to the best of my knowledge. /_ / Signed ~d~T Title: Production Engineering Supervisor Date SUBMIT IN DUPLICATE%~ .-.. KUPARUK RIVER UNIT /ELL SERVICE REPORT 2Z-12A(4-1)) _ JOB SCOPE JOB NUMBER _-12A FRAC, FRAC SUPPORT 0608980933.2 UNIT NUMBER Inc. DATE O6/27/98 DAY 11 FIELD ESTIMATE DALLY WORK REFRACTURE C4/C2 SANDS OPERATION COMPLETE ISUCCESSFUL IKEYPERSON ~_~ Yes O No ~ Yes O No DS-GALLEGOS AFC# ICC# I DAILY COST ACCUM COST KD2292 230DS28ZL $146,576 $222,410 InitialTbg IFinalTbg IlnitiallA IFinallA [InitialOA IFinalOX ITTLSize 1710PSll 1500PSII 900PSI 500PSI 850PSII 900PSI 0.000 " SUPERVISOR JONES Signed Min ID [ Depth 0.000" ] 0 FT DALLY SUMMARY C4/C2 SAND REFRAC SCREENED OUT DURING FLUSH. 221,363 LBS PROPPANT PLACED IN FORMATION, 14014 LBS PROPPANT LEFT IN TUBING. MAX TREATING PRESSURE 8050 PSI. [Frac-Refrac] TIME LOG ENTRY 06:00 MIRU DS FRAC UNIT - GALLAGOS, LRS, APC. HELD TGSM. PT @ 10,000 PSI. 08:15 PUMP BREAKDOWN/CONDITION STAGES PER PROCEDURE, STEPDOWN TEST & SHUT DOWN. OBTAINED IS 2407 PSI. 09:15 PUMP DATA FRAC. SHUT DOWN & OBTAIN ISIP 2361 PSI. ADJUST PAD. 11:00 PUMP MAIN FRAC PER PROCEDURE, PUMPED ADDITIONAL 26,510 LBS PROPPANT. FRAC SCREENED OUT 28.2 BBLS INTO FLUSH. MAX PRESS 8050 PSI. TOTAL PROPPANT PUMPED 235,377 LBS, TOTAL IN FORMATION 221,363 LBS & 14014 LBS LEFT IN TBG. 14:00 RDMO DS FRAC UNIT. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $3,292.00 APC $6,520.00 $16,020.00 BIOZAN $0.00 $0.00 DIESEL $0.00 $0.00 DIESEL GEL $0.00 $0.00 DOW ELL $135,876.70 $145,876.70 HALLIBURTON $0.00 $26,644.00 LI-I-FLE RED $4,180.00 $26,480.00 PETREDAT $0.00 $0.00 SCHLUMBERGER $0.00 $4,098.00 ~ TOTAL FIELD ESTIMATE $146,576.70 $222,410.70 F' [: R H 1~ T ::, :., T,6., '7 i:)A T A F' L I.! '.:i: [.it ii'...]F::: r: ,::; ',./L, · i 0 -'. z~. 0 7 C: C, H H [': F.] T: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown __ Stimulate Plugging Perforate X Pull tubing .__ Alter casing Repair well Other_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development X ARCO Alaska, Inc. Exploratory _ RKB 97 feet 3. Address Stratigraphic _ 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Service _ Kuparuk River Unit 4. Location of well at surface 8. Well number 1298' FSL, 75' FWL, Sec 12, T11N, R9E, UM 2Z-12A At top of productive interval 9. Permit number/approval number 1586' FSL, 1984' FEL, Sec 13, T11N, R9E, UM 95-148 At effective depth 0Rt Gi~ ~i,Plnumber 1139' FSL, 1703' FEL, Sec 13, T11N, R9E, UM -029-21380-01 At total depth /11~. r--~ld/Pool 1026' FSL, 1638' FEL, Sec 13, T11N, R9E, UM Kuparuk River Oil Field/Pool 12. Present well condition summary Total Depth: measured 9480 feet Plugs (measured) None true vertical 6238 feet Effective depth: measured 8 61 7 feet Junk (measured) None true vertical 5757 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 8 0' 1 6" 255 SX PFC 118' 1 1 8' Surface 4393' 9.625" 1300 Sx CS III & 4428' 3360' Intermediate 500 Sx CS II Production 7909' 7" 375 Sx CL G/250 Sx PFC 7942' 5402' Liner 1 71 0' 3 1/2" 330 Sx Class G 9480' 6238' Perforation depth: measured 8814'-8842',8849'-8964',8976'-8980',8996'-9001 ',9220'-9250' true vertical 5870'-5885',5889'-5953',5959'-5961 ',5970'-5973',6094'-6111' Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 @ 7775' Packers and SSSV (type and measured depth) PKR: Baker 'H' @ 7777'; SSSV: None, landing nipple @ 520' R E C E IV E D 13. Stimulation or cement squeeze summary Perforated 'B' & 'C' sands on 4/7/96. MAY 0 7 1995 Intervals treated (measured) 8849'-8929' Treatment description including volumes used and final pressure ~ta. ka (ltl & (~ai Cong. COlllmit Shot using 2 1/8" HC charges @ 4 spf, 0© phasing, Iow side of hole. Ar orage 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 475 2 5 3 36 839 193 Subsequent to operation 5 7 1 457 37 843 214 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ ., Daily Report of Well Operations X Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~ned'~~~..~~ ~~'~~¢' Title Wells Superintendent Date Form 10-404 Rev 06/15/88 SUBMIT~'r LICATE Alaska, inc. KUPARUK RIVER UNIT WELL SERVICE REPORT '~ K1 (Z'l 2A(W4-6)) WELL JOB SCOPE JOB NUMBER 2Z-12A PERFORATE, PERF SUPPORT 0305961333.2 DATE DAILY WORK UNIT NUMBER 04/07/96 PERFORATE C & B SANDS DAY !OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 2 (~) Yes O NoI (~) Yes O No SWS-WARNER GOLDEN FIELD AFC# ~ DAILY COST AC CUM COST t~ 1~,~ ESTIMATE 998375 230DS28ZL $19,562 $42,871 · Initial Tb.a Press Final Tba Press Initial Inner Ann Final Inner Ann I Initial Ou I 500 PSI 1 900 PSI 850 PSI 1400 PSI! 500 PSI! 500 PSI DAILY SUMMARY · PERFORATED C & B SANDS FROM 8849'-8929' RKB. TAGGED FILL @ 9147' RKB. LEFT FISH IN HOLE - 16" (2.0" OD, 1.70" ID) I I BO~'OM NOSE CAP PROTECTOR FOR PERF GUN. TIME LOG ENTRY 08:30 MIRU SWS. TGSM: SLIPPERY CONDITIONS DUE TO SPRING THAW. 09:30 11:30 13:15 14:30 16:00 PT LUBRICATOR TO 3000 PSI - GOOD. RIH W/CCI_, MPD, 20' 2-1/8" HOLLOW CARRIER (4 SPF, 0 DEGREE PHASING, LOW SIDE OF HOLE). TIED INTO SLTJ LOG DATED 12/12/95. WHP (BEFORE)= 1430 PSI. PERFORATED F/8909'-8929' RKB, WHP (AFTER) = 1440 PSI. POOH. ASF. PT LUBRICATOR TO 3000 PSI - GOOD. RIH W/CCL, MPD, 20' 2-1/8" HOLLOW CARRIER (4 SPF, O DEGREE PHASING, LOW SIDE OF HOLE). TIED INTO SLTJ LOG DATED 12/12/95. WHP (BEFORE) = 1580 PSi, PERFORATED F/8889'-8909' RKB, WHP (AFTER) = 1580 PSI. POOH. ASF. PT LUBRICATOR TO 3000 PSI - GOOD. RIH W/CCL, MPD, 20' 2-1/8' HOLLOW CARRIER (4 SPF, 0 DEGREE PHASING, LOW SIDE OF HOLE). TIED INTO SLT LOG DATED 12/12/95. WHP (BEFORE) = 1650 PSI, PERFORATED 8869'-8889 RKB', WHP (AFTER) = 1650 PSI. POOH. ASF. PT LUBRICATOR TO 3000 PSI - GOOD. RIH W/CCL MPD, 20' 2-1/8" HOLLOW CARRIER (4 SPF, O DEGREE PHASING, LOW SIDE OF HOLE). TIED INTO SLTJ LOG DATE 12/12/95. WHP (BEFORE) = 1710 PSI, PERFORATED F/8849'-8869' RKB, WHP (AFTER) = 1710 PSI. TAGGED FILL @ 9147' RKB. POOH. ASF. NOTE - BO'FrOM NOSE CAP PROTECTOR FROM GUN # 4 WAS LOST IN HOLE. FISH IS 16" LONG. 2.0" OD, 1.70' ID. (DETAILED DRAWING IN WELLFILE). RDMO SWS. RECFiVED A;~¢¢ 0!! ~- ~-~ Cons. SERVICE COMPANY - SERVICE APC HALLIBURTON SCHLUMBERGER TOTAL FIELD ESTIMATE D~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate Pull tubing Alter casing Repair well 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 14. Location of well at surface 1298' FSL, 75' FWL, Sec 12, T11N, R9E, UM At top of productive interval 1586' FSL, 1984' FEL, Sec 13, T11N, R9E, UM At effective depth 1139' FSL, 1703' FEL, Sec 13, T11N, R9E, UM At total depth 1026' FSL, 1638' FEL, Sec 13, T11N, R9E, UM 12. Present well condition summary Total Depth: Plugging Perforate X Other 6. Datum elevation (DF or KB) RKB 97 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2Z- 12A 9. Permit number/approval number 95-148 10. APl number 50-029-21380-01 measured 9 4 8 0 true vertical 6238 ORIGINA 11. Field/Pool --Kuparuk River Oil Field/Pool feet feet Plugs (measured) None Effective depth' measured 8 61 7 true vertical 5 75 7 feet feet Junk (measured) None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 80' 16" 4393' 9.625" 79O9' 7" 1710' 3 1/2" measured 8814'-8842',8929'-8 true vertical 5870'-5885' ,5933'-5 13. 14. Cemented Measured depth True vertical depth 255 Sx P F C 118' 1300 Sx CS III & 4428' 500 Sx CS II 375 Sx CL G/250 Sx PFC 7942' 330 Sx Class G 9480' 118' 3360' 5402' 6238' 964',8976'-8980',8996'-9001',9220'-9250' 953',5959'-5961',5970'-5973',6094'-6111' Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 @ 7775' Packers and SSSV (type and measured depth) PKR: Baker 'H' @ 7777'; SSSV: None, landing nipple @ 520' Stimulation or cement squeeze summary Perforated 'B'& 'C' sands on 3/18/96. Intervals treated (measured) 8814'-8842',8929'-8964',8976'-8980',8996'-9001' Treatment description including volumes used and final pressure Shot using 2 1/8" HC w/DP charges @ 4 spf, 0© phasing. RECEIVED MAY 07 t996 Alaska Oil & Gas Cons. c~mmission Anchorage Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 416 2 7 6 26 823 223 5 0 9 317 27 836 226 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev' 06/15/88 Title Wells Superintendant Date J ~,,/~-/' SUBMIT IN DUPLICATE .CO Alaska, Inc. '-' ,,4UPARUK RIVER UNIT WELL SERVICE REPORT K1 (Z-12A(W4-6)) WELL JOB SCOPE JOB NUMBER 2Z-12A PERFORATE, PERF SUPPORT 0305961333.2 DATE DALLY WORK UNIT NUMBER 03/1 8/96 PERF 'B' & 'C' SAND DAY OPERATION COMPLETE ~ SUCCESSFUL KEY PERSON SUPERVISOR 1 O Yes (~ No! (~) Yes O No SWS-BAILEY PAIGE cc, OA, YCOS ACC MCOS ESTIMATE 998375 230DS28ZL $22,230 $22,230 Initial Tb.cl Press Final Tbcl Press Initial Inner Ann Final Inner Ann I Initial Outer Ann J Final'Outer Anh 800 PSI 1 750 PSI 1000 PSI 1000 PSII 500 PSII 500 PSI DAILY SUMMARY COMPLETED 4 Of 8 PERF RUNS; INTERVALS SHOT WERE 8996'-9001', 8976'-8980', 8929'-8964', & 8814'-8842' USING 2-1/8" HOLLOW CASE CARRIER W/DP CHARGES. 4 SPF, 0 DEG PH. WHP INCR FROM 800# TO 1750#. LEFT TO SHOOT IS INTERVAL 8849'-8929'. TIME 08:30 10:00 11:00 11:20 11:30 12:30 13:15 13:30 13:45 14:15 14:45 15:30 15:45 16:00 16:50 17:30 17:40 18:15 19:30 LOG ENTRY MIRU SWS. HELD SAFE-i'Y MTG- CELLULAR PHONES / EXPLOSIVE DETONATION PT LUB TO 2500#; TEST OK. RIH W/GUN#1 - 6' WGT BAR, CCL, MPD, 5' / 8' SWITCHED 2-1/8" HOLLOW CASE CARRIER W/DP CHARGES, 4 SPF. 0 DEG PH TO SHOOT INTERVAL 8996'-9001' & 8834'-8842' ON BO'FrOM TO TIE-IN USING GR/CCL/SLTJ DATED 12/12/95 WHP-800~. FIRED GUN#lA TO SHOOT 8834'-8842'; NO CHANGE IN WHP. RIH TO SHOOT LOWER INTERVAL (8996'-9001 ') W/SWITCH WHP-800#. FiRED GUN#lB TO SHOOT 8996'-9001'; NO CHANGE IN WHP. POH. PT LUB TO 2500~; TEST OK. RIH W/GUN~2 - 6' WGT BAR, CCL, MPD, 4'/15' SWITCHED 2-1/8" HOLLOW CASE CARRIER W/DP CHARGES. 4 SPF. 0 DEG PH TO SHOOT INTERVAL 8976'-8980' & 8949'-8964' ON BOTTOM TO TIE-IN USING GR/CCL/SLTJ DATED 12/12/95. WHP-1300#. FIRED GUNC2A TO SHOOT 8949'-8964'; NO CHANGE IN WHP. RIH TO SHOOT LOWER INTERVAL (8976L8980') W/SWITCH WHP-1300~. FIRED GUNCf2B TO SHOOT 8976'-8980'; NO CHANGE IN WHP. POH. AT SURF W/GUN#2; ALL SHOTS FIRED. PT LUB TO 2500~; TEST OK. RIH W/GUN,F3 - 6' WGT BAR, CCL, MPD, 20' 2-1/8" HOLLOW CASE CARRIER W/DP CHARGES, 4 SPF, 0 DEG PH TO SHOOT INTERVAL 8814'-8834'; WHP INCR TO 1500# ON BOTTOM TO TIE-IN USING G~'CCL/SLTJ DATED 12/12/95. WHP-1500#. FIRED GUN#3 TO SHOOT 8814'-8834'; POH. AT SURF W/GUN#3; ALL SHOTS FIRED. PT LUB TO 2500¢f; TEST OK. RIH W/GUN#4 - 6' WGT BAR, CCL MPD, 20' 2-1/8" HOLLOW CASE CARRIER W/DP CHARGES, 4 SPF, 0 DEG PH TO SHOOT INTERVAL 8929'-8949'; WHP INCR TO 1750# ON BOTTOM TO TIE-IN USING GR/CCL/SLTJ DATED 12/12/95. WHP-1750#. FIRED GUN#4 TO SHOOT 8929'-8949'; POH. AT SURF W/GUNCf4; ALL SHOTS FIRED. RDMO. Mt~Y 0 ~' lOC~q I S ERVICE COMPANY- SERVICE SCHLUMBERGER TOTAL FIELD ESTIMATE Alaska 011 & (:~Rs r;~)ns Ut~mmsSlOr, ,-~RCO Alaska, Inc. Post Office Box 1003bO Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 13, 1996 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2Z-12A(Permit No. 95-148) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report 2Z-12A. If there are any questions, please call 263-4622. for the recent Sincerely, operations on KRU W. S. Isaacson Drilling Engineer Kuparuk Drill Site Development WSI/skad STATE OF ALASKA A~_ASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL ~] GAS E~ SUSPENDED ~ ABANDONED [] SERVICE [] 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 95-148 3 Address 8 APl Number P.O. Box 100360, Anchora~te, AK 99510-0360 50-029-21380-01 4 Location of well at surface 9 Unit or Lease Name , ' ', ..... ~ KUPARUK RIVER UNIT 1298' FSL, 75' FWL, Sec. 12, T11N, R9E, UM i ........ ' :':";.;;'! I~'.~ AtAt Top Producing IntervalTotal Depth ;i~/~' ,. _ -_~ :l"~":~""' '¢"~ I11,~, ,~. ~ 10 Well Number2z_l 2A ~r,.._'4C~'~J---"'' ! .~!; ~-,~ 11 Field and Pool 850'FSL, 2107'FEL, Sec. 13, T11N, R9E, UM ~ - ';; J.: ~,"~i' ~~ KUPARUKRIVER 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. KUPARUK RIVER OIL POOL RKB 97', Pad 72'I ADL 25653 ALK 2579 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 115 Water Depth, if offshore 16 No. of Completions 20-Oct-95 sidetrack 03-Nov-95 01-Jan-96 Peri'edI NA feet MSL 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set I 21 Thickness of permafrost I 9480' MD & 6238'TVD 8617' MD & 5757'TVD YES X~ NO LJ NA feet MD 1500' APPROX 22 Type Electric or Other Logs Run CBL 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENTRECORD 16" 62.5# H-40 Surf 118' 24" 255 sx PFC 9-5/8" 36.0# J-55 Surf 4428' 12-1/4" 1300 sx CS III & 500 sx CS II 7" 26.0# K-55 Surf 7942' 8-1/2" 375 sx Class G & 250 sx PFC 3.5" 9.3# L-80 7770' 9480' 6-1/8" 330 sx Class G 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 7775' 7777' (liner top packer) 9220'-925o' MD 2 spf 6094-6111' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9220'-9250' 162,000# behind pipe, 4711 # left in tubing, 10 ppa of 12/18 proppant at perfs 27 PRODUCTION TEST Date FirStjan_96Production Method of OperationFiowing(FIowing, gas lifl, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 1/22/96 12 TEST PERIOD Ct 6 31 937 88 176 1485 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press 229 763 24-HOUR RATE ct 1 262 1874 176 =24° 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. r q..,: :.ri Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top C Interval 8811' 5868' Top A Interval 9163' 6063' ORIGINAL ,., .,, -'- 13,') .,,, ....... ' ..,.;.~. 31. LIST OF Al-rACHMENTS Directional Survey, Daily Well Operations 32. I hereby certify that the foregoing is true and correct to the best of my knowlege. INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ate: 1/2t/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 1 WELL:2Z-12A RIG:NO RIG WELL ID: 998375 AFC: 998375 TYPE: STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD: START COMP: BLOCK' FINAL: WI- 0% SECURITY:0 AFC EST/UL:$ OM/ API NUMBER: 50-029-21380-00 OM 10/20/95 (13) TD' 8617' ( 0) SUPV' DCL DAILY' 10/21/95 (14) TD' 8140' ( 0) SUPV'DCL DAILY' 10/22/95 (15) TD: 8140' ( 0) SUPV'DCL DAILY' 10/23/95 ( 16) TD: 8140' ( 0) SUPV:DCL DAILY' 10/24/95 (17) TD: 8140' ( 0) SUPV'DCL DAILY' 10/25/95 (18) TD: 8140' ( 0) SUPV-DCL DAILY: MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 RACK AND TALLY DP RIH with 3-1/2" DP. Tag bridge plug at 8143' (Nordic RKB) . Displace well with mud. Circulate and condition mud. Mix and spot 10 bbl - 18 ppb pill. POH with 10 stds. Pump dry job. $41,789 CUM: $41,789 ETD: $0 EFC: $41,789 MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 CIRC AND INCREASE MUD WEIGHT Run in hole with section milling BHA on 3-1/2" DP. Fill DP every 2000'. Position mill at 7944' md-Nordic RKB. Mill casing from 7944' - 7945' md. Had gas to surface while milling at 7945' Shut in well. $37,473 CUM' ~79,262 ETD: $0 EFC' $79,262 MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 MILL SECTION Circ and increase mud wt to 10.8 ppg. Monitor well. OK. Attempt to mill section. Mill does not appear to be fully open. Circ and increase mud wt to 11.0 ppg for trip. Pump dry job. Mill dragging through casing cplgs. LD mill. Mill appears to be jammed with metal. RIH with new section mill, BHA and 3-1/2" DP. Gas cut mud at surface. CBU through open choke. Monitor well.OK. $42,935 CUM: $122,197 ETD: $0 EFC: $122,197 MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 CIRC AND COND MUD AT 3000' Cut section from 7942' to 7964' Circ and condition mud. Pump hi vis sweeps. Hole pkg off. Reciprocate and rotate pipe. Pump hi vis sweeps. Hole not cleaning. $37,512 CUM: $159,709 ETD: $0 EFC: $159,709 MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 PREP TO CUT SECTION RIH with 3-1/2" DP to 6000' Circ and condition mud. Gas cut mud to surface. Circ through open choke to clear gas. Rotate and reciprocate pipe. No metal recovery. RIH w/3-1/2" DP to 7936'. No metal recovery. POH w/bit. Small amount of metal in boot baskets. RIH with milling assembly to 7946'. Work through junk at 7940'. $41,590 CUM: $201,299 ETD: $0 EFC: $201,299 MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 PREP TO CUT SECTION Circ and work section mill to bottom @ 7964' packing off. Continue cutting 7" section from 7964' to 7973'. Was unable to open knives after connection. Remove knives and $49,920 CUM: $251,219 ETD: $0 EFC: $251,219 ate: 1/23/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 2 10/26/95 (19) TD: 8140' ( 0) SUPV:DCL DAILY: 10/27/95 (20) TD: 7700' ( 0) SUPV:DCL DAILY: 10/28/95 (21) TD: 8136' (436) SUPV:DCL DAILY: 10/29/95 ( 22) TD: 8161' ( 25 SUPV:D1W DAILY: 10/30/95 ( 23) TD: 8665' ( 504 SUPV:D1W DAILY: 10/31/95 (24) TD: 8760' ( 95 SUPV:D1W DAILY: 1t/01/95 (25) TD: 8837' ( 77) SUPV:DEB DAILY: 11/02/95 (26) TD: 9034' (197) SUPV:DEB DAILY: 11/03/95 (27) TD: 9480' (446) SUPV:DEB DAILY: MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 RIH TO 8090' FOR KICK OFF PLUG Continue milling 7" section from 7973' to 7992'. POOH with section mill. Knives show about 20% wear. RIH with open ended 3-1/2" DP to lay kick off plug. $41,823 CUM' $293,042 ETD' $0 EFC: $293,042 MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 RIH W/ BIT %1 RIH with 3-1/2" O/E DP form 7987' to 8090' Cement. CIP @ 0740 hrs. 10/26/95. Hesitation down squeeze up to 2000 psi. Test BOPE 250-3000 psi. $69,082 CUM' $362,124 ETD' $0 EFC' $362,124 MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 DIRECT. DRILL 6-1/8" HOLE Wash and clean out cement to 7945' Sidetrack section by sliding from 7945' to 7992'. Drill 14' new hole 8006' Circulate and condition mud to do a formation leak off test. Perform formation leak off. Continue directional drilling 6-1/8" hole from 8006' to 8136'. $~4,253 CUM: $406,377 ETD: $0 EEC: $406,377 MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 CIRC GAS CUT MUD @ 8068' Continue directional drilling 6-1/8" hole from 8136' to 8161'. $47,969 CUM' $454,346 ETD: $0 EFC' $454,346 MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 DRILLING Continue circulating out gas cut mud from 8086' holding 250 psi on casing with 55 spm and 1450 psi on DP. With bottoms up well dead. Directional drill 6-1/8" hole from 8216' to 8665' $46,358 CUM: $500,704 ETD: $0 EFC: $500,704 MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 RIH WITH BIT #RR3 @ 8760' Continue directional drilling 6-1/8" hole with BHA #2 from 8665'-8760' $44,789 CUM: $545,493 ETD: $0 EFC: $545,493 MW: 0.0 PV/YP: 0/ 0 POH WITH BHA #3 Drill 8760' to 8837' Lost returns. $44,026 CUM: $589,519 ETD: $0 EFC: AP IWL: 0.0 $589,519 MW: 11.3 DRILLING @ 9034' Drilling from 8837' to 9034' $51,328 CUM: $640,847 ETD: PV/YP: 0/35 $0 EFC: APIWL: 4.8 $640,847 MW: 11.3 POH, SHORT TRIP TO 7" CSG Drill 9034' to 9480' $51,168 CUM: $692,015 ETD: PV/YP: 0/28 $0 EFC: APIWL: 3.4 $692,015 ate' 1/23/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 3 11/04/95 (28) TD' 9480' ( 0) SUPV'DEB DAILY' 11/05/95 (29) TD' 9480' ( 0) SUPV'DEB DAILY' 11/06/95 (30) TD: 9480' ( 0) SUPV'DEB DAILY: 11/07/95 (31) TD: 9480' ( 0) SUPV:DEB DAILY: 11/08/95 (32) TD' 9480' ( 0) SUPV: DEB DAILY' MW: 11.3 RUNNING 3-1/2" LINER ON DP Run 3-1/2" liner. $36,162 CUM' $728,177 ETD' PV/YP: 0/28 AP IWL · 3.2 $0 EFC: $728,177 MW' 11.3 PV/YP' 0/24 APIWL' 3.4 TESTING LOWER PIPE RAMS Run 3-1/2" liner. Pump cement. CIP @ 1900 hrs. 11/4/95. $79,969 CUM' $808,146 ETD: $0 EFC' $808,146 MW: 11.3 PV/YP: 0/22 APIWL: 3.8 RACK & TALLY 3-1/2" TUBING Test LOPE. Load 3-1/2" tubing & jewelry into pipe shed. $32,200 CUM: $840,346 ETD: $0 EFC: $840,346 MW: 6.8 PV/YP: 0/ 0 APIWL: 0.0 ND LOPE Run 3-1/2" single completion assembly. Test tubing to 2500 psi for 15 minutes, OK. Test annulus to 2500 psi for 15 min., OK. $87,877 CUM: $928,223 ETD: $0 EFC: $928,223 MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED N/D BOP's. Test packoff 250-5000 psi. N/U tree and test to 250-5000 psi. OK. R/D and move rig off hole. Release rig @ 1300 hrs. 11/7/95. $14,764 CUM: $942,987 ETD: $0 EFC: $942,987 ,RCO Alaska, inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(2Z-12A(W4-6)) WELL JOB SCOPE JOB NUMBER 2Z-12A CAPITAL FRAC, FRAC SUPPORT 1 1 28951814.1 UNIT NUMBER DATE 01/01/96 DAY 8 DAILY WORK PERFORATE 'A' SAND OPERATION COMPLETE I SUCCESSFUL YES ! YES IKEY PERSON BAILEY SUPERVISOR PAIGE Initial TDg Press 200 PSI DAILY SUMMARY 200 PSI 0 PSI 0 PSII 600 PSI 600 PSI IPERFORATED 'A' SAND INTERVAL 9220'-9250' (PER CBL DATED 12/12/95) USING 2-1/2" TITAN W/BH CHARGES, 2 JSPF, 0 DEG PH, I ORIENTED 90 DEG CCW F/LOWSIDE I TIME 10:45 12:30 13:30 14:15 14:45 15:15 16:00 16:45 17:15 17:50 LOG ENTRY MIRU SWS. HELD SAFETY MTG. PT LUB TO 3000#; TEST OK. RIH WI GUN#1 - WGT BARS, CCL, 10' 2-172" TITAN WI BIG HOLE CHARGES, 2 JSPF, 0 DEG PH, ORIENTED 90 DEG CCW F/LOWSlDE TO SHOOT 9240'-9250' PER CBL DATED 12/12/95 TAGGED BO'R-OM @ 9251'; UABLE TO SHOOT BO'FI-OM FOOT OF DESIRED INTERVAL. FIRED GUN' INTERVAL SHOT WAS 9239'-9249'. POH W/GUN#1. AT SURF W/GUN#1' ALL SHOTS FIRED. PT LUB TO 3000#; TEST OK. RIH W/GUN#2 - WGT BARS, CCL, 10' 2-1/2" TITAN WI BIG HOLE CHARGES, 2 JSPF, 0 DEG PH, ORIENTED 90 DEG CCW F/LOWSIDE TO SHOOT 9230'-9240' PER CBL DATED 12/12/95 FIRED GUN#2; POH. AT SURF W/GUN#2; MISFIRED. PT LUB TO 3000#; TEST OK. RIH WI GUN#3 - WGT BARS, CCL, 10' 2-1/2" TITAN WI BIG HOLE CHARGES, 2 JSPF, 0 DEG PH, ORIENTED 90 DEG CCW F/LOWSIDE TO SHOOT 9230'-9240' PER CBL DATED 12/12/95 FIRED GUN#3; POH. AT SURF W/GUN#3; ALL SHOTS FIRED. 18:15 PT LU B TO 3000#; TEST OK. RIH W/GUN#4 - WGT BARS, CCL, 10' 2-1/2" TITAN WI BIG HOLE CHARGES, 2 JSPF, 0 DEG PH, ORIENTED 90 DEG CCW F/LOWSIDE TO SHOOT 9220'-923O' PER CBL DATED 12/12/95 18:45 A'I-I-EMPT TO FIRE GUN#4 APPEAR TO BE UNSUCCESSFUL: TROUBLESHOOT THE HARDWARE. 20:45 APPEAR TO BE A DOWNHOLE PROBLEM; POH W/GUN#4. 21:15 AT SURF W/GUN#4 21:30 PROBLEM APPEARS TO BE LOOSE WIRING / BAD CONNECTION IN CIRCUITRY. RIH W/GUN#4 22:15 FIRED GUN#4: POH. 22:45 AT SURF W/GUN#4: ALL SHOTS FIRED. 23:30 RDFN. ~?-n~'~RY-S~ DRILLING SERVICES' ANCHORAGE ALASKA PAGE ARCO ALASKA INC. KUPARUK/2 Z- 12A 500292138001 NORTH SLOPE BOROUGH COMPUTATION DATE: 11/ 7/95 TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN 7900 5377.43 5280.43 54 7 7947 5404.01 5307.01 57 0 8068 5463.33 5366.33 64 28 8097 5475.78 5378.78 65 7 8185 5514.63 5417.63 62 18 8282 5563.79 5466.79 57 2 8376 5616.68 5519.68 54 31 8469 5670.35 5573.35 54 17 8564 5726.06 5629.06 54 29 8655 5778.61 5681.61 54 47 8758 5837.95 5740.95 54 50 8837 5883.19 5786.19 54 50 DATE OF SURVEY: 110195 MWD SURVEY JOB NUMBER: AK-MW-50104 KELLY BUSHING ELEV. = 97.00 FT. OPERATOR: ARCO ALASKA INC COURSE DLS DIRECTION DEGREES DG/10 S 31.40 E .00 S 30.26 E 6.43 S 27.60 E 6.45 S 26.40 E 4.32 S 21.90 E 5.61 S 19.40 E 5.85 S 18.30 E 2.85 S 16.30 E 1.78 S 10.40 E 5.02 S 8.30 E 1.91 S 2.60 E 4.53 S 2.60 E .00 TOTAL RECTANGULAR COORDINATES 0 NORTH/SOUTH EAST/WEST 4446.83S 2871.30E 4480.12S 2891.16E 4572.81S 2942.29E 4596.40S 2954.30E 4668.12S 2986.50E 4746.72S 3016.18E 4820.30S 3041.31E 4891.90S 3063.61E 4967.49S 3081.55E 5040.56S 3093.58E (~5124.24S ~_~3101.56E 5188 40S 3104 47E THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 6046.26 FEET ~O~ AT SOUTH 30 DEG. 53 MIN. EAST AT MD = 8837 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 148.65 DEG. TIE IN POINT 7900' WINDOW POINT 7947' INTERPOLATED DEPTH 8837' NO SURVEY STATIONS TAKEN FROM 8837' TO TD AT 9480' VERT. SECT. 5291.45 5330.21 5435.97 5462 . 36 5540.37 5622.93 5698.85 5771.60 5845.48 5914.14 5989.76 6046.06 ARCO Alaska, Inc. Date: January. 15, 1996 Transmittal #: 9318 RETURN TO: ARCO Alaska, Inc. Attn.: Julie Nash Kuparuk Operations File Clerk ATO-1119B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following Cased Hole items. Please acknowledge receipt and return one signed copy of this transmittal. 2x-18 CBL ,2X-12A CBL ~../2X-19 CBL lq~ 2Z-12A CBL Receipt ~ ._/~J~y~- Acknowledge://', ~'~ DISTRIBUTION: 12/05/95 12/16/95 12/04/95 1 2/12/95 Date' - Sharon AIIsup-Drake DS Devek)pment ATO-1205 .~ '..t:arry- Grant (+sepia) 'AOGCC 3001 Porcupine Drive Anchorage, AK 99501 8500-9809 6500-j~545 8210~.,,.. 7594-936~(,. ... Erickson/Zuspan NSK Central Files NSK-box 69 , iEMORANDL'" .... tate of Alaska Alaska Oil and Gas Conservation Commission TO: David John~ DATE: Chairman~--~'~ November 5, 1995 THRU: Blair Wondzeil, .~~ FILE NO: P. I. Supervisor df~)~ FROM: Jerry Herring,~~ SUBJECT: Petroleum Ins~ectoj abukkecd.doc BOPE Test, Nordic 1 KRU, 2Z-12A PTD 95-148 Sunday, November 5, '!995: I traveled to ARCO's 2Z pad and witnessed a BOPE test on Nordic 1. The BOPE test report is attached for reference. I arrived on the pad as requested at 6:00 AM. A walk-through of the rig was completed and i found the rig and crew to be in somewhat of a disarray and pipe was still being pulled out of the hole. The BOPE test began at 11:00 AM and lasted for 5 hours. The test went slowly due to problems with the test equipment. A good pressure test was finally obtained on all of the BOP equipment. One H2S gas detection head in the cellar malfunctioned and was replaced. Summary: I witnessed a BOPE test on Nordic 1. The test lasted 5 hours and there were no failures. Attachment: abukkecd.xls STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: Test: Initial X Workover: NORDIC Rig No. I PTD # 95-148 ARCO Rep.: KRU 2Z-12A Rig Rep.: 7" Set @ 7942' Location: Sec, Weekly X Other DATE: 11/5/95 Rig Ph.# 659-7115 Don Breeden Shane McGeehan 12 T. 11N R. 9E Meridian Umiat TEST DATA MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) PTD On Location OK Standing Order Posted OK BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Well Sign OK Drl. Rig OK Hazard Sec. OK Quan. Test Press. P/F 300 / 3, 000 P ~ 300/3,500 P 1 300/3,500 P '1 300 / 3, 500 P ~ 300 / 3, 5O0 P ~ 30O/3,5O0 P 2 300/3,5O0 P N/A N/A N/A MUD SYSTEM: Visual Alarm Trip Tank OK OK Pit Level Indicators OK OK Flow Indicator OK OK Meth Gas Detector OK OK H2S Gas Detector OK OK FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F '1 300/3.500 P 300/3.500 P 3OO/3.5O0 P 300 / 3.500 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes 12 Test Pressure P/F 300 / 3, 500 P 26 300 / 3, 5OO P 1 P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 3 Bottles 2,400 (Ave.) 3,000 P '1,650 P 0 minutes 45 sec. 3 minutes 53 sec. OK Remote: OK Psig. /--~ TEST RESULTS Number of Failures: 0 ,Test Time://4._~ Hours. Number of valves tested 20 Repair or Replacement of Failed Equipment will be made within n/a ~Jay's. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: H2S head in cellar changed out. Distribution: orig-Well File c- Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Jerry Herring FI-021L (Rev. 12/94) ABU KKECD.XLS TONY KNOWLES, GOVERNOR ALASKA OILAND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 September 26, 1995 Mike Zanghi, Drig Engr Supv ARCO Alaska Inc P O Box 100360 Anchorage, AK 99510-0360 .... Re: Well Cf - Company Permit Cf Surf Loc Btmhole Loc Kuparuk River Unit 2Z-12A ARCO Alaska inc 9,~148 1298'FSL,. 75'FWL, Sec 12, T11N, R09E, UM 904'FSL, 1912'FEL, Sec 13, T11N, R09E, UM Dear Mr Zanghi: Enclosed is the approved appliCation for permit to re-drill the above referenced well. The permit to re-drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting re-drilling operations until all other required permitting determinations are made. Chairman ~ BY ORDER OF THE COMMISSION Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed pdor to drilling a new hole. Notice may be given by contacting the Commission's petroleum field inspector on the North Slope pager at 659-3607. jo/encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAO 25.005 la. Type of Work Drill Redrlll X 1 b Type o! Well Exploratory [--~ Stratigraphic Test [] Developmen~ Oil X Re-Entry [~] Deepen [~] Service r"J Development Gas r~ Single Zone X Multiple Zone r~ 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 97', Pad 72' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchoracje, AK 99510-0360 ADL 25653, ALK 2579 4. Location of well at sudace 7. Unit or property Name 11. Type Bond (see 20 AAC 25.O2,5) 1298' FSL, 75' FWL, Sec. 12, T11N, R9E, UM _Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8,~.. Well number Number '~. 1442' FSL, 2076' FEL, Sec. 13, T11N, R9E, UM 2Z-12A #U-630610 At total depth 9. Approximate spud date Amount 904' FSL, 1912' FEL, Sec. 13, T11N, R9E, UM 10/2/95 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Numbez-of acres in property 15. Proposed depth (MD and TVD) property line 2Z-13 9438' MD 1912' @ TD feet 360' @ surface feet 2560 6208' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 7948' feet Maximum hole angle 57.7° Max~nurnsu~ace 2930 psig At total depth (TVD) 3590 18. Casing program Seltinc, I Depth size Specifications Top Bottom Quantity/of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage dala~ 6-1/8' 3-1/2' 9.3# L-80 BTC-Moc 1658' 7780' 5313' 9438' 6208' 302 sxs Class G SFP 1 4 !99,5 19. To be completed for Reddll, Re-entry, and Deepen Operations. Alaska ~JJt & Gas Cons, Commission Present well condition summary Total depth: measured 9 5 0 0 feet Plugs (measured) ~mcii0ra§e true vertical 6299 feet Cement retainer set @ 8630' & perfs squeezed Effective depth: measured 8 6 3 0 feet Junk (measured) true vertica 5816 feet Carbide blast rings left @ 8753' MD Casing Length Size Cemented Measured deplh True Vertical depth Structural Conduclor I 18' 1 6 ' 255 Sx PFC I 18' 1 18' Surface 4393' 9-5/8' 1300 sx CSIII, 500 sx CSII 4428' 3360' Intermediate Production 9 4 0 2' 7 ' 375 sx Class G, 250 sx PFC 9 4 3 7' 6 2 6 6' Liner Per~orationdepth: measured 8712-8792', 8944-8958', 8978-9025', 9106-9116' MD true vertical 5865-5915', 6005-6013', 6024-6050', 6094-6099' TVD 20. Attachments Filing fee X Property plat [-] BOP Sketch X Diverter Sketch [~] Drilling program X Drilling fluid program X Time vs depth plot [] Refraction analysis [] Seabed report ~]~.?',20 AAC 25.050 requirements X 21. I hereby certifylhat,~the foj'egoiag is true~~ and correct to the best of my knowledge ~,,,ft ~/~, _,,F~_,~,~ Signed. Title Drill Site Develop. Supv. Date \ [_ _, .~ Commission Use Only .) Permit Number'"q lJA"P~number [ Appr~.val date [ See cover letter for ~:~--/~4'~ ~'~ 50-O~-- ~ "' ,2,.] ~ ~O -O /I ~)' ~'~' '7~"--I other requirements Conditions of approvaJ Samples required [] Yes ,,~ No Mud log required r-] Yes ,~ No Hydrogen sulfide measures [] Yes r'~ No Directional survey required [] Yes [~] No Requimd working pressure for BOPE [-~ 2M [~] 3M ~. 5M [-~ 10M ~] 15M Other:Jnginal Signed By W. Johnston / / / by order of /, Approved ........ by Commissioner the commission Date '- / / ~ (. ?/ Fnrm 1N-4NI Rnv 7-24-R.cl trinli~'.ntn REDRILL PLAN SUMMARY Well 2Z-12A Type of well (producer/injector): Surface Location: Target Location: Bottom Hole Location: MD: TVD: Rig- Estimated Start Date: Operation Days to Complete: Producer 1298' FSL, 75' FWL, SEC 12, T11N, R9E, UM 1442' FSL, 2076' FEL, SEC 13, T11 N, R9E, UM 904' FSL, 1912' FEL, SEC 13, T11N, R9E, UM 9438' 6208' Nordic Rig 1 10-2-95 11 Drill Fluids Program: Milling Section in 7" casing Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids 9.6-9.8 >25 15-35 85-95 20-30 30-40 .. 8.5-9.5 Kick off to weight up 9.4-9.8 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Weight up to TD 11.9 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drilling Fluid System: Bariod Model 2 Tandem Shale Shaker Swaco 6 cone desilter Triflow vacuum Degasser, Poor Boy Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators SEP 'l 4- ~995 Gas Cons. Commission Anchorage Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Page 1 Casing/Tubing Hole size 6-1/8" Program: Csg/Tbg 3-1/2", 9.3#, L-80, BTC Tubing 3-1/2", 9.3#, J-55, EUE Length Top (MD/TVD) Btm (MD/TVD 1658' 7780'/5313' 9438'/6208' 7760' 22'/22' 7780'/5313' Cement Calculations: Casing to be cemented: 3-1/2" in 6-1/8" open hole Volume = 302 sxs of class G Blend @ 1.19 cu ft/sx Based on: Shoe volume, open hole volume + 50%, & 150' liner lap. Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams, blind rams, and annular preventer will be installed. Maximum anticipated surface pressure is estimated at 2,930 psi and is calculated using a gas column to surface. The expected leak-off at the section cut in the 7" casing is estimated at 14.5 ppg EMW. With an expected formation pressure in the Kuparuk of 3590 psi and a gas gradient of 0.11 psi/ft, this shows that formation breakdown would not occur before a surface pressure of 2,930 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3500 psi. See attached BOPE schematic. Drilling Hazards: Lost Circulation: OverDressured Intervals: Other Hazards: No lost circulation hazards are expected to be encountered in 2Z-12A. The well will kick off out of the 7" casing +/-300' TVD below any suspected lost circulation intervals. The kick-off point in 2Z-12 is below any zones which would be of pressure concern prior to weighting up for the Kuparuk interval. The bottom hole location in 2Z-12A is immediately adjacent to a fault, however pressures on both side of the fault are expected to be controlled by the mud weight mentioned in the 'Drilling Fluids Program' section. None Directional: KOP: Max hole angle: Close approach: 7948' MD / 5402' TVD 57.7° (in sidetrack portion) No Hazards SEP ?_Z 199,5 Gas Cons. C0mrnissiort Page 2 Logging Program- Open Hole Logs: None Cased Hole Logs: GR/CCL Notes- Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of an existing, well. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. Page 3 KRU 2Z-12A GENERAL SIDETRACK PROCEDURE NOTE - CURRENT WELL STATUS: The well was previously plugged back and the perforations abandoned during a workover where junk was left across the perforated interval. The perforations were plugged by the down squeeze method through a cement retainer set +/-85' above the top perforated interval. PRE-RIG WORK: 1. Prepare location for MIRU of Nordic Rig. WO 10. RKOVER RIG WORK: 1. MIRU Nordic Rig. Lay hard-line to tree. Load pits with section milling fluid. 2. Check well for pressure. ND tree. NU and test BOPE. 3. RU E-line unit. RIH with bridge plug and set at 8140' MD. 4. PU DP and RIH with section mill to top of bridge plug. Circulate well to milling fluid and spot an 18 ppg balanced mud pill from PBTD to the base of proposed section. Cut a 50' section in the 7" casing from 7940'- 7990'. POOH w/mill. 5. RIH w/open ended DP. Wash down through section and circulate any metal shavings from well. Mix and pump balanced cement kick-off plug f/100' below base of section to 200' above top of section. 6. RIH w/6-1/8" bit, mud motor, MWD, and steerable drilling assembly. Dress off cement to top of section. Kick-off well and directionally drill to total depth as per directional plan. Short trip to window in casing. POOH w/DP. 7. Run 3-1/2" liner to TD w/150' of overlap to top of milled section. 8. Cement liner. Set liner hanger and liner top packer. POOH w/DP. 9. Pressure test casing and liner lap to 3500 psi for state test. RIH w/completion assembly and sting into polished bore receptacle at top of liner. Space out. Displace well to sea water at max rate. Test tubing and annulus. Page 4 11. ND BOPE. NU and test tree. Freeze protect well with diesel. RDMO Nordic. 12. Clean out well to PBTD w/coiled tubing. Perforate through tubing. Lower Limit: 9 days Expected Case: 11 days Upper Limit: 16 days No problems milling section, drilling new hole, or running completion. Difficulties encountered milling section, or drilling new hole. WSI 9/12/95 SEP 2 2 1995 Alaska 0il & Gas Cons. Commission Anchorage Page 5 5200 _ 54oo_ 5500_ 5600_ -- 5700_ - ,5800_ - 5000_ - -- ARCO ALASKA, Inc. Strucfure: Pad 2Z Well : 12A Field : Kuparuk River Unit Location : North Slope, Alaska 6200 _ 6500_ 6400. Created by : jones For: B ISAACSON Date plotted : 12-Sep-95 Plot Reference is 12A Ver~ ~6. Coordinates ore in fee{ reference slot j~I?.A. True Vedicol Oepths ere reference RKB (Nordic ~1). Scale 1 : 50.00 2800 2900 KOP - Sidetrock Point 3000 EOC East 3100 3200 3300 SURFACE LOCAl.ION: 1298' FSL, 75' FWL SEC. 12, T11N, R9E S 31.35 DEG E 6014' (TO TARGET) ***PLANE OF PROPOSAL*** HRZ Midpoin TARGET - Top Kup Sands TOp Zone C Top Zone B Top Zone A KOP TVD=5402 TMD=7948 DEP=5340 55.78 57.04 Bose Kup Sands EOC TVD=5582 TMD=8266 DEP=5600 HRZ Midpoint 'Fy'D=5647 TM0=8589 DEP=5700 5500 5600 I I TARGET - T/ KUP SNDS TVD=5852 TMD=8772 DEP=6014 K-1 TARGET ANGLE 57.68 DEG B/ KUP SNDS %/0=6101 TMD=9258 DEP=6395 TARGET LOCATION: 1442' FSL, 2076' FEL SEC. 13, ]'11N, R9E 5700 I 4500 -- _4400 _ _4500 -- _4600 -- _4700 -- 4800 _4900 - _5000 - _5100 _ _5200 5300 5400 5500 _5600 'rD TD LOCATION: - _5700 90¢' FSL, 1912' FEL SEC. 13. T11N, R9E L _5800 TVD=5785 TMD=8643 DEP=S908 ZONE C %/D=5864 TMD=8794 DEP=6032 T/ ZONE B TVD=5900 TMD=8862 OEP=6088 T/ ZONE A TVD=5992 TMD=90$4 S.£P=5228 TD TI/D=6808 134D=9438 DEP=6559 I I I I I I I I I I I I I I I I I I I I I I I I I I 5100 5200 5300 5400 5500 5600 5700 5800 5900 6000 6100 6200 6300 Scole 1 · 50.00 Verticol Section on 148.65 ozimufh with reference 0.00 N, 0.00 E from slot #12A i 64O0 6500 6600 6700 O c- I I V 7-1/16" 5000 PSI BOP STACK 6 PIPE RAM ~= I 5 BLINDRAM~ CROSS 4 I · ACCUMULATOR CAPACITY TEST 1. CHECKAND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 5 MINUTES. INCREASE PRESSURE TO 3500 PSI AND HOLD FOR 5 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND INSIDE MANUAL KILL AND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS, HCR VALVE ON CHOKE LINE, AND OUTSIDE MANUAL VALVE ON KILL LINE. 6. TEST TO 250 PSI AND 3500 PSI AS IN STEP 4. 7. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3500 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BOq-TOM PIPE RAMS. TEST BOq-rOM RAMS TO 250 PSI AND 3500 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. 10. CLOSE BLIND RAMS AND TEST TO 3500 PSI FOR 5 MINUTES. BLEED TO ZERO PSI. 11. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 12. TEST STANDPIPE VALVES TO 3500 PSI. 13. TEST KELLY COCKS AND INSIDE BOP TO 3500 PSI WITH KOOMEY PUMP. 14. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 15. PERFORM COMPLETE DOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1.11"- 3000 PSI CASING HEAD 2.11" - 3000 PSI x 7-1/16" 5000 PSI TUBING HEAD 3.7-1/16" - 5000PSI SINGLE GATE W/PIPE RAMS 4.7-1/16"- 5000 PSI DRLG SPOOL W/CHOKE & KILL LINES 5.7-1/16"- 5000 PSI SINGLE GATE W/ BLIND RAMS 6.7-1/16" - 5000 PSI SINGLE GATE W/PIPE RAMS 7.7-1/16"- 5000 PSI ANNULAR PREVENTER sEP 1 4 1995 Gas Cons. Commission Anchorage LLPI::T S NORDIC RIG # 1 LEVEL 2 ." ~UJO'IqT' · · · II II I TiilP I~IK '" '-- R.ICK uOOULE UCC PANEL TR£P. NORDIC RIG # ! LEVEL 3 ~:t~ 150 BBI- ~, ({t~l : '. 0 I - , 40' PIPE DOOR " / ., ELL PERMIT CHECKLIST ADMINISTRATION 1. Permit fee attached .................. 2. Lease number appropriate ............... 3. Unique well name and number .............. 4. Well located in a defined pool ............. 5. Well located proper distance from drlg unit boundary.. 6. Well located proper distance from other wells ..... 7. Sufficient acreage available in drilling unit ..... 8. If deviated, is wellbore plat included ........ 9. Operator only affected party .............. 10. Operator has appropriate bond in force ......... j 11. Permit can be issued without conservation order .... 12. Permit can be issued without administrative approval.. 13. Can permit be approved before 15-day wait ....... ENGINEERING WELL NAME GEOL AREA UNIT# ON/OFF SHORE ~'~ Conductor string provided ............... ~) Surface casing protects all known USDWs ......... Y CMT vol adequate to circulate on conductor & surf csg.. Y CMT vol adequate to tie-in long string to surf csg . . . Y 15. 16. 17. 18. CMT will cover all known productive horizons ...... 19. Casing designs adequate for C, T, B & permafrost .... 20. Adequate tankage or reserve pit ............. 21. If a re-drill, has a 10-403 for abndnmnt been approved. ~ 22. Adequate wellbore separation proposed .......... 23. If diverter required, is it adequate .......... 24. Drilling fluid program schematic & equip list adequate 25. BOPEs adequate ............ m ........ 26. BOPE press rating adequate; test to ~~ psig.~ 27. Choke manifold complies w/API RP-53 (May 84) ...... 28. Work will occur without operation shutdown ....... 29. Is presence of H2S gas probable ............ GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Seismic analysis 9f shallow gas zones .......... ~/ N /~/,~' Data presented on potential overpressure zones ..... Y 32. 33. Seabed condition survey (if off-shore) ........ /Y N /~ ' ' 34. Contact name/phone for weekly progress reports . . . ~. Y N [exploratory only] GEOLOG,Y~ ENGINEERING: CO~: Comments/Instructions: TAB O HOW/jo - A:tFORMS~cheklist rev 03/94