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Home My WebLink About185-272MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 24, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3F-11 KUPARUK RIV UNIT 3F-11 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/24/2025 3F-11 50-029-21482-00-00 185-272-0 W SPT 5672 1852720 1800 1560 1560 1560 1560 240 2000 1900 1885 REQVAR P Bob Noble 6/7/2025 MIT-OA to 1800 psi as per AIO 2B.089. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3F-11 Inspection Date: Tubing OA Packer Depth 800 900 900 900IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN250616214946 BBL Pumped:1 BBL Returned:0.7 Thursday, July 24, 2025 Page 1 of 1             MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 24, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3F-11 KUPARUK RIV UNIT 3F-11 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/24/2025 3F-11 50-029-21482-00-00 185-272-0 W SPT 5672 1852720 3000 1560 1565 1565 1565 300 550 560 560 REQVAR P Bob Noble 6/7/2025 MIT-IA to max injection psi as per AIO 2B.089. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3F-11 Inspection Date: Tubing OA Packer Depth 760 3290 3200 3190IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN250616214458 BBL Pumped:2.4 BBL Returned:2 Thursday, July 24, 2025 Page 1 of 1            C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\R97USUAM\2024-09-05_22613_KRU_3F-11_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22613 KRU 3F-11 50-029-21482-00 Caliper Survey w/ Log Data 05-Sep-24 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 185-272 T39569 9/16/2024 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.09.16 13:47:18 -08'00' Originated: Delivered to:12-Sep-24 Alaska Oil & Gas Conservation Commiss 12Sep24-NR ATTN: MeredithGuhl 333 W. 7th Ave., Suite 100 600 E 57th Place Anchorage, Alaska 99501-3539 Anchorage, AK 99518 (907) 273-1700 main (907)273-4760 fax WELL NAME API # SERVICE ORDER # FIELD NAME SERVICE DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED CD2-58 50-103-20457-00-00 203-085 Colville River WL SBHPS-RBP FINAL FIELD 16-Aug-24 CD2-21 50-103-20504-00-00 204-245 Colville River WL Patch FINAL FIELD 18-Aug-24 CD2-467 50-103-20579-00-00 208-114 Colville River WL Patch FINAL FIELD 20-Aug-24 1B-07 50-029-20616-00-00 181-089 Kuparuk River WL MechCutter FINAL FIELD 24-Aug-24 2A-11 50-103-20057-00-00 186-003 Kuparuk River WL Isealate Patch FINAL FIELD 27-Aug-24 3F-11 50-029-21482-00-00 185-272 Kuparuk River WL IPROF FINAL FIELD 29-Aug-24 2A-20 50-103-20196-00-00 193-151 Kuparuk River WL IPROF FINAL FIELD 30-Aug-24 3F-20 50-029-22947-00-00 199-079 Kuparuk River WL IPROF FINAL FIELD 2-Sep-24 3J-18 50-029-22701-00-00 196-147 Kuparuk River WL Lee-PPROF FINAL FIELD 3-Sep-24 2U-12 50-029-21304-00-00 185-041 Kuparuk River WL PPROF FINAL FIELD 4-Sep-24 1D-39 50-029-22997-00-00 200-216 Kuparuk River WL Punch-Cut FINAL FIELD 9-Sep-24 2P-448A 50-103-20396-01-00 202-005 Kuparuk River WL Punch FINAL FIELD 10-Sep-24 2P-432 50-103-20420-00-00 202-091 Kuparuk River WL Punch FINAL FIELD 11-Sep-24 2P-434 50-103-20467-00-00 203-153 Kuparuk River WL Punch FINAL FIELD 11-Sep-24 Transmittal Receipt ________________________________ X_________________________________ Print Name Signature Date Please return via courier or sign/scan and email a copy to Schlumberger. Nraasch@slb.com SLB Auditor - TRANSMITTAL DATE TRANSMITTAL # A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted media. # Schlumberger-Private T39555 T39556 T39557 T39558 T39559 T39560 T39561 T39562 T39564 T39565 T39566 T39567 T39668 T39563 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.09.13 08:31:59 -08'00' 3F-11 50-029-21482-00-00 185-272 Kuparuk River WL IPROF FINAL FIELD 29-Aug-24 T39560 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 3F-11 (PTD 185-272) Update and plan forward Date:Monday, April 1, 2024 9:32:02 AM Attachments:AnnComm Surveillance TIO for 3F-11.pdf MIT KRU 3F-11 diagnostic MIT 03-01-24.xlsx From: Byrne, Jan <Jan.Byrne@conocophillips.com> Sent: Monday, April 1, 2024 9:05 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU 3F-11 (PTD 185-272) Update and plan forward Chris, KRU 3F-11 (PTD 185-272) (AIO 2B.09) was reported 2/27/24 for suspect IA pressure fall off. A passing diagnostic MITIA and MITOA were performed. The IA pressure was left elevated, and no IA pressure fall off was observed during the monitor period. The well is being returned to ‘normal’ status at this time. Please let me know if you disagree or have any questions with this plan. Regards, Jan Byrne Well Integrity Specialist | ConocoPhillips Alaska O: (907) 265-6471 | M: (808) 345-6886 Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 1852720 Type Inj W Tubing 1940 1940 1940 1940 Type Test P Packer TVD 5672 BBL Pump 5.5 IA 900 2900 2860 2850 Interval O Test psi 1500 BBL Return OA 320 400 400 400 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 1852720 Type Inj W Tubing 1940 1940 1940 1940 Type Test P Packer TVD 5672 BBL Pump 0.8 IA 15 900 900 900 Interval O Test psi 1500 BBL Return OA 320 1800 1790 1790 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting ConocoPhillips Alaska Inc, Kuparuk / KRU / 3F Pad Weimer 03/01/24 Notes:Diagnostic MITIA Notes: 3F-11 3F-11 Notes:Diagnostic MITOA Notes: Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Form 10-426 (Revised 01/2017)MIT KRU 3F-11 diagnostic MIT 03-01-24 (002) 3F-11 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 3F-11 2024-03-01 15.0 800 785.0 IA 3F-11 2024-03-14 83.0 0 -83.0 IA Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: 8,029.0 3/27/2000 3F-11 WV5.3 Conversion Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Pull plug 7/6/2021 3F-11 spilch Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 38.0 Set Depth (ftKB) 115.0 Set Depth (TVD) … 115.0 Wt/Len (l… 62.58 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 37.0 Set Depth (ftKB) 3,843.3 Set Depth (TVD) … 3,023.9 Wt/Len (l… 36.00 Grade J-55 Top Thread BUTT Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 35.0 Set Depth (ftKB) 8,454.1 Set Depth (TVD) … 6,048.5 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description TUBING WO String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 33.2 Set Depth (ft… 7,877.7 Set Depth (TVD) (… 5,649.1 Wt (lb/ft) 9.30 Grade L-80 Top Connection ABM-EUE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 33.2 33.2 0.05 HANGER FMC GEN III TUBING HANGER 3.500 468.0 468.0 0.45 NIPPLE CAMCO DS NIPPLE 2.812 7,790.6 5,589.6 47.16 PBR BAKER PBR w/ 10' STROKE 3.000 7,804.3 5,598.9 47.11 PACKER BAKER FHL RETRIEVABLE PACKER 3.000 7,843.1 5,625.4 46.88 NIPPLE CAMCO W-1 SELECTIVE NIPPLE 2.812 7,876.8 5,648.4 46.69 OVERSHOT UNIQUE MACHINE OVERSHOT TUBING GUIDE 2.930 7,877.2 5,648.8 46.69 OVERSHOT EXTENSION OVERSHOT BODY EXTENSION; O/S GUIDE 7.30' OAL, SWALLOWS 6.84' OF 3.5" TUBING 3.654 Tubing Description TUBING 3.5"x2.875" Original String Ma… 4 1/2 ID (in) 2.87 Top (ftKB) 7,877.7 Set Depth (ft… 8,077.2 Set Depth (TVD) (… 5,787.0 Wt (lb/ft) 9.30 Grade J-55 Top Connection BTC Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,898.3 5,663.2 46.57 SBR OTIS SBR 3.000 7,911.3 5,672.2 46.51 PACKER OTIS RRH RETRIEVABLE PACKER 2.970 7,985.6 5,723.4 46.16 BLAST RING CARBIDE BLAST RING (1) 2.867 8,039.6 5,761.0 46.06 NIPPLE AVA BPL SLEEVE 2.750 8,042.5 5,763.0 46.06 XO Reducing CROSSOVER 3.5 x 2.875, ID 2.441, #6.5, J-55, EUE 2.875 8,052.7 5,770.1 46.05 LOCATOR OTIS LOCATOR SEAL ASSEMBLY 2.437 8,053.7 5,770.7 46.05 PACKER OTIS WD PERMANENT PACKER 3.000 8,057.1 5,773.1 46.04 SBE SEAL BORE EXTENSION 3.000 8,069.0 5,781.3 46.03 NIPPLE CAMCO D NIPPLE NO GO 2.250 8,076.5 5,786.6 46.03 SOS CAMCO SHEAR OUT SUB 2.500 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 8,039.6 5,760.9 46.06 SLEEVE-O 2.75" AVA BPI SET IN NIPPLE 4/14/2011 2.300 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,989.0 8,013.0 5,725.8 5,742.5 C-4, C-1, 3F-11 1/20/1986 12.0 IPERF 5" HJ II Csg Gun; 120 deg. phasing 8,121.0 8,142.0 5,817.4 5,832.0 A-3, 3F-11 5/14/1988 4.0 APERF '2 1/8" Tornado Jet' 90 deg. phasing 8,167.0 8,225.0 5,849.4 5,889.7 A-2, 3F-11 1/20/1986 4.0 IPERF 4" Carrier HJ II Gun' 90 deg. phasing Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 7,738.4 5,554.2 47.34 CAMCO MMM 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/17/1996 7:30 2 7,948.4 5,697.8 46.33 CAMCO KBUG 0.0 INJ DMY BK 0.000 0.0 1/21/1986 8:30 Close d Notes: General & Safety End Date Annotation 5/2/2014 NOTE: IA x OA COMM. WATER INJECTION ONLY. 11/12/2010 NOTE: View Schematic w/ Alaska Schematic9.0 3/27/2000 NOTE: Unable to pass 8070' RKB 10/24/1996 NOTE: CORKSCREWED/COLLAPSED TBG below AVA (See WSR 6/24/90) 10/24/1996 NOTE: W/O LEFT PORTION OF ORIGINAL TBG STRING 7878'-8077' 3F-11, 7/7/2021 5:58:09 AM Vertical schematic (actual) PRODUCTION; 35.0-8,454.1 IPERF; 8,167.0-8,225.0 APERF; 8,121.0-8,142.0 SOS; 8,076.5 NIPPLE; 8,069.0 SBE; 8,057.1 PACKER; 8,053.7 LOCATOR; 8,052.8 NIPPLE; 8,039.6 SLEEVE-O; 8,039.6 IPERF; 7,989.0-8,013.0 INJECTION; 7,948.4 PACKER; 7,911.3 SBR; 7,898.3 OVERSHOT; 7,876.8 NIPPLE; 7,843.1 PACKER; 7,804.3 PBR; 7,790.6 GAS LIFT; 7,738.4 SURFACE; 37.0-3,843.3 NIPPLE; 468.0 CONDUCTOR; 38.0-115.0 HANGER; 33.2 KUP INJ KB-Grd (ft) 41.79 Rig Release Date 12/6/1985 3F-11 ... TD Act Btm (ftKB) 8,654.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292148200 Wellbore Status INJ Max Angle & MD Incl (°) 51.62 MD (ftKB) 5,400.00 WELLNAME WELLBORE3F-11 Annotation Last WO: End Date 10/24/1996 H2S (ppm) DateComment SSSV: NIPPLE CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 3F-11 (PTD 185-272) Report of suspect IA pressure fall off Date:Tuesday, February 27, 2024 12:53:18 PM Attachments:AnnComm Surveillance TIO for 3F-11.pdf From: Byrne, Jan <Jan.Byrne@conocophillips.com> Sent: Tuesday, February 27, 2024 12:31 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU 3F-11 (PTD 185-272) Report of suspect IA pressure fall off Chris, KRU 3F-11 (PTD 185-272) (AIO 2B.09) was noted to be exhibiting an unexplained slow IA pressure fall off. The plan is for DHD to perform initial diagnostics including an MITIA, MITOA, pack off tests, and set the well up for a 30-day monitor. Any required paperwork for corrective action or continued injection will be submitted upon completion of the diagnostics and monitor period. A 90-day TIO trend is attached. Please let me know if you disagree or have any questions with this plan. Regards, Jan Byrne Well Integrity Specialist | ConocoPhillips Alaska O: (907) 265-6471 | M: (808) 345-6886 3F-11 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 3F-11 2023-12-10 300 500 200 IA Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: 8,029.0 3/27/2000 3F-11 WV5.3 Conversion Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Pull plug 7/6/2021 3F-11 spilch Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 38.0 Set Depth (ftKB) 115.0 Set Depth (TVD) … 115.0 Wt/Len (l… 62.58 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 37.0 Set Depth (ftKB) 3,843.3 Set Depth (TVD) … 3,023.9 Wt/Len (l… 36.00 Grade J-55 Top Thread BUTT Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 35.0 Set Depth (ftKB) 8,454.1 Set Depth (TVD) … 6,048.5 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description TUBING WO String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 33.2 Set Depth (ft… 7,877.7 Set Depth (TVD) (… 5,649.1 Wt (lb/ft) 9.30 Grade L-80 Top Connection ABM-EUE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 33.2 33.2 0.05 HANGER FMC GEN III TUBING HANGER 3.500 468.0 468.0 0.45 NIPPLE CAMCO DS NIPPLE 2.812 7,790.6 5,589.6 47.16 PBR BAKER PBR w/ 10' STROKE 3.000 7,804.3 5,598.9 47.11 PACKER BAKER FHL RETRIEVABLE PACKER 3.000 7,843.1 5,625.4 46.88 NIPPLE CAMCO W-1 SELECTIVE NIPPLE 2.812 7,876.8 5,648.4 46.69 OVERSHOT UNIQUE MACHINE OVERSHOT TUBING GUIDE 2.930 7,877.2 5,648.8 46.69 OVERSHOT EXTENSION OVERSHOT BODY EXTENSION; O/S GUIDE 7.30' OAL, SWALLOWS 6.84' OF 3.5" TUBING 3.654 Tubing Description TUBING 3.5"x2.875" Original String Ma… 4 1/2 ID (in) 2.87 Top (ftKB) 7,877.7 Set Depth (ft… 8,077.2 Set Depth (TVD) (… 5,787.0 Wt (lb/ft) 9.30 Grade J-55 Top Connection BTC Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,898.3 5,663.2 46.57 SBR OTIS SBR 3.000 7,911.3 5,672.2 46.51 PACKER OTIS RRH RETRIEVABLE PACKER 2.970 7,985.6 5,723.4 46.16 BLAST RING CARBIDE BLAST RING (1) 2.867 8,039.6 5,761.0 46.06 NIPPLE AVA BPL SLEEVE 2.750 8,042.5 5,763.0 46.06 XO Reducing CROSSOVER 3.5 x 2.875, ID 2.441, #6.5, J-55, EUE 2.875 8,052.7 5,770.1 46.05 LOCATOR OTIS LOCATOR SEAL ASSEMBLY 2.437 8,053.7 5,770.7 46.05 PACKER OTIS WD PERMANENT PACKER 3.000 8,057.1 5,773.1 46.04 SBE SEAL BORE EXTENSION 3.000 8,069.0 5,781.3 46.03 NIPPLE CAMCO D NIPPLE NO GO 2.250 8,076.5 5,786.6 46.03 SOS CAMCO SHEAR OUT SUB 2.500 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 8,039.6 5,760.9 46.06 SLEEVE-O 2.75" AVA BPI SET IN NIPPLE 4/14/2011 2.300 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,989.0 8,013.0 5,725.8 5,742.5 C-4, C-1, 3F-11 1/20/1986 12.0 IPERF 5" HJ II Csg Gun; 120 deg. phasing 8,121.0 8,142.0 5,817.4 5,832.0 A-3, 3F-11 5/14/1988 4.0 APERF '2 1/8" Tornado Jet' 90 deg. phasing 8,167.0 8,225.0 5,849.4 5,889.7 A-2, 3F-11 1/20/1986 4.0 IPERF 4" Carrier HJ II Gun' 90 deg. phasing Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 7,738.4 5,554.2 47.34 CAMCO MMM 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/17/1996 7:30 2 7,948.4 5,697.8 46.33 CAMCO KBUG 0.0 INJ DMY BK 0.000 0.0 1/21/1986 8:30 Close d Notes: General & Safety End Date Annotation 5/2/2014 NOTE: IA x OA COMM. WATER INJECTION ONLY. 11/12/2010 NOTE: View Schematic w/ Alaska Schematic9.0 3/27/2000 NOTE: Unable to pass 8070' RKB 10/24/1996 NOTE: CORKSCREWED/COLLAPSED TBG below AVA (See WSR 6/24/90) 10/24/1996 NOTE: W/O LEFT PORTION OF ORIGINAL TBG STRING 7878'-8077' 3F-11, 7/7/2021 5:58:09 AM Vertical schematic (actual) PRODUCTION; 35.0-8,454.1 IPERF; 8,167.0-8,225.0 APERF; 8,121.0-8,142.0 SOS; 8,076.5 NIPPLE; 8,069.0 SBE; 8,057.1 PACKER; 8,053.7 LOCATOR; 8,052.8 NIPPLE; 8,039.6 SLEEVE-O; 8,039.6 IPERF; 7,989.0-8,013.0 INJECTION; 7,948.4 PACKER; 7,911.3 SBR; 7,898.3 OVERSHOT; 7,876.8 NIPPLE; 7,843.1 PACKER; 7,804.3 PBR; 7,790.6 GAS LIFT; 7,738.4 SURFACE; 37.0-3,843.3 NIPPLE; 468.0 CONDUCTOR; 38.0-115.0 HANGER; 33.2 KUP INJ KB-Grd (ft) 41.79 Rig Release Date 12/6/1985 3F-11 ... TD Act Btm (ftKB) 8,654.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292148200 Wellbore Status INJ Max Angle & MD Incl (°) 51.62 MD (ftKB) 5,400.00 WELLNAME WELLBORE3F-11 Annotation Last WO: End Date 10/24/1996 H2S (ppm) DateComment SSSV: NIPPLE MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, July 26, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3F-11 KUPARUK RIV UNIT 3F-11 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/26/2023 3F-11 50-029-21482-00-00 185-272-0 W SPT 5672 1852720 3000 2341 2345 2243 2374 720 950 950 950 REQVAR P Brian Bixby 6/4/2023 MIT-IA as per AIO 2B.089 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3F-11 Inspection Date: Tubing OA Packer Depth 950 3290 3220 3200IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB230607082326 BBL Pumped:2 BBL Returned:2 Wednesday, July 26, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 9 MIT-IA James B. Regg Digitally signed by James B. Regg Date: 2023.07.26 15:05:25 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, July 26, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3F-11 KUPARUK RIV UNIT 3F-11 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/26/2023 3F-11 50-029-21482-00-00 185-272-0 W SPT 5672 1852720 1800 2340 2340 2344 2341 665 2000 1920 1900 REQVAR P Brian Bixby 6/4/2023 MIT-OA as per AIO 2B.089 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3F-11 Inspection Date: Tubing OA Packer Depth 980 1040 1040 1040IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB230607082546 BBL Pumped:0.6 BBL Returned:0.6 Wednesday, July 26, 2023 Page 1 of 1 9 9 9 9 9 9 99 9 9 9 9 9 9 9 9 9 MIT-OA James B. Regg Digitally signed by James B. Regg Date: 2023.07.26 15:08:34 -08'00' MEMORANDUM TO: Jim Regg P.I. Supervisor % FROM: Lou Laubenstein Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 28, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 3F-11 KUPARUK RIV UNIT 3F-1 I Src: Inspector Reviewed By: P.I. Supry j --ex—, Comm Well Name KUPARUK RIV UNIT 3F -I I API Well Number 50-029-21482-00-00 Inspector Name: Lou Laubenstein Permit Number: 185-272-0 Inspection Date: 7/24/2021 , Insp Num: mitLOL210724133218 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3F-11 Type Inj W - TVD 5672 Tubing 2408 2410. 2410 2410- PTD852720 Type Test' SPT Test psi 1800 IA -220 - 270 - 270 - 270 - p Pum ed: 0.8 - ;BBL Returned: 0.8 OA 730 2010 - Intervals REQVAR P/F P 1940 1930 - J Notes: MPII - A to 1800 psi per AIO 213.089 ✓ II— 'r1 — (�,✓ C('x(7t'ZI z Wednesday, July 28, 2021 Page I of I MEMORANDUM TO: Jim Regg f ,/ P.I. Supervisor (( � FROM: Lou Laubenstein Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 28, 2021 SUBJECT: Mechanical Integrity Tests ConoccPhillips Alaska, Inc. 3F -ll KUPARUK RIV UNIT 3F-11 Src: Inspector Reviewed By: P.I. Suprv Comm Well Name KUPARUK RIV UNIT 3F-11 API Well Number 50-029-21482-00-00 Inspector Name: Lou Laubenstein Permit Number: 185-272-0 Inspection Date: 7/24/2021 Insp Num: mi[LOL210724132941 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3F-11 Type Inj w -TVD F 5672 Tubing 2410 2410. 2410 - 2410 - PTD 1852720 - -- -- --. — Type Test SPT Test psi 3000IA 160 3290 3210 - 3200 - BBL Pumped: 1 3 BBL Returned: 3 OA 1 770 - 1075 - 1075 - 1075 - Interval REQVAR P/F P Notes: MIT -IA to Maximum Anticipated Injection pressure per AIO 213.089 ✓ CtPP JJ`*:L + cll;- d L - — CJL(..t e-. (30 -713�f zez 1 Wednesday, July 28, 2021 Page 1 of l MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim ReggP�� c�' �% ZvZ� DATE: June 23, 2021 P. I. Supervisor ( I FROM: Brian Bixby SUBJECT: Surface Casing Repair Petroleum Inspector KRU 3F-11 Conoco Phillips Alaska , PTD 1852720; Sundry 320-364 6/20/21: 1 arrived location and met with Roger Mouser (CPAI) and looked at the repair work on the surface casing of KRU 3F-11. The well had already been tested to 1800psi. v I took 3 photos. I looked to be good and I told them they could proceed on with wrapping the repaired section of the casing. Attachments: Photos (3) 2021-0620_Surface_Casing_Repair KRU_3F-11_bb.docx Pagel of 3 0 N ti N LO co r IL LL x M m /yam m A/ L Y o I v L_ Q �m C/) Q c �U U c C7 O y � N V cn O lC O N O U) 0- O .40 M -3F- I i Regg, James B (CED) From: Regg, James B (CED) Sent: Tuesday, June 22, 2021 10:54 AM S. �'7 z I ze� To: Well Integrity Specialist CPF1 & CPF3 Cc: Wallace, Chris D (CED) Subject: RE: KRU 3F-11 (PTD 185-272) Request for SW MIT grace period Extension to complete the MIT is approved as requested (test not later than 7/31/2021). Jim Regg Supervisor, Inspections AOGCC 333 W. 7`1 Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Tuesday, June 22, 202110:31 AM To: Regg, James B (CED) <jim.regg@alaska.gov> Subject: RE: KRU 3F-11 (PTD 185-272) Request for SW MIT grace period Jim, I've attached a 10-426 for the MITOA and a copy of the 10-404 packet that was submitted yesterday. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 From: Well Integrity Specialist CPF1 & CPF3 Sent: Tuesday, June 22, 202110:12 AM To: Regg, James B (CED) <jim.regf @alaska,ov> Subject: KRU 3F-11 (PTD 185-272) Request for SW MIT grace period Jim, KRU 3F-11 (PTD 185-272) (AIO 213.089) has been shut in and secured since July 2020 due to a surface casing leak which recently had a witnessed repair completed 6/20/21 (sundry 320-364). The well is due for it's 2 -year SW MITIA & SW MITOA 06/30/2021. The well is planned to be de -secured and put back on injection in the coming weeks and a SW MITIA & SW MITOA will be scheduled, but due to the timing of the well work and allowing the well to stabilize after being 1301 the well will pass the required test date for the MITs. CPAI would like to request that 3F-11 be given a month grace period to allow for completion of de -securing the well, bringing online and stabilizing the well, and scheduling the testing. The testing would be completed no later than 7/31/21. i/ Please let me know if that plan is acceptable for you. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 P,, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: iim.regg a,alaska.goy: AOGCC.Inspectors@alaska.gov; phoebe.brooksa_alaska.gov OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk / KRU / CPF-3 06/20/21 Green ch ris.wallace(d)alaska.gov Well 3F-11 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. P = Pressure Test PTD 1852720 , Type Inj N - Tubing 0 0 0 0 V = Required by Variance Type Test P Packer TVD 5672 BBL Pump 0.7 IA 0 0 0 0 Interval O Test psi 1500 BBL Return OA 0 2000 - 1970 1965 " Result P Notes: Diagnostic MITOA post surface casing repair Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBI -Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBI -Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBI -Pump IA Interval Test psi BBL Return OA Result Notes: Form 10-426 (Revised 01/2017) MIT KRU 3F-11 diagnostic MITOA 6.20.21 i INTERVAL Codes Result Codes TYPE INJ Codes TYPE TEST Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Form 10-426 (Revised 01/2017) MIT KRU 3F-11 diagnostic MITOA 6.20.21 i ! 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G /' # ! # ! !# .*6%/*:. @>C8 #> "+$'8& /0:)?;+F**66?<+ ).0?;+F).0?<+ " G 202(:(: -* + ;+7 9 8%0: :%):- # -2(:(: # $ %#$&'() &) $ & #* By Samantha Carlisle at 7:53 am, Sep 01, 2020 320-364 Digitally signed by Roger Mouser DN: O=Conocophillips, CN=Roger Mouser, E=N1927@conocophilllips.com Reason: I am the author of this document Location: your signing location here Date: 2020-08-31 16:31:48 Foxit PhantomPDF Version: 10.0.0 Roger Mouser SFD 9/1/2020 6149 SFD 9/1/2020 DSR-9/1/2020 10-404X Photo document all steps including cutting windows and SC before and after patch VTL 9/2/20 " 9/2/2020 dts 9/2/2020 JLC 9/2/2020 RBDMS HEW 9/3/2020 ! " #$$% & '! ()(*+! ) ( , ) ! - .!/#012*3-4&5%*6 )!!"/ -! !0 " ,)7%$*%7), ,8 / ! , 0 " 9 ." ,2( ! - .!/ Digitally signed by Roger Mouser DN: O=Conocophillips, CN=Roger Mouser, E=N1927@conocophilllips.com Reason: I am the author of this document Location: your signing location here Date: 2020-08-31 16:30:39 Foxit PhantomPDF Version: 10.0.0 Roger Mouser ! 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allace, Chris D (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Thursday, July 9, 2020 6:53 PM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: KRU 3F-11 (PTD 185-272, AIO 26.089) Report of Outer Annuls to Atmosphere Communication Attachments: 3F-11 90 -Day TIO 7.9.20.pdf, 3F-11.pdf Good Evening Chris, KRU seawater injector 317-11 (PTD 185-272, NO 213.089) exhibited evidence of a surface casing leak to atmosphere today through slight bubbling at the conductor top and presence of diesel in the well cellar. The well is waivered for water only injection due to slow inner by outer annulus communication and is required to be shut in and secured if the mechanical condition changes. As a result, the well has been shut in and slickline is being mobilized to secure the well as early as tomorrow. The inner and outer annuli were bled as low as possible and no liquid actively leaked to surface. The well most recently passed an AOGCC witnessed MIT -IA to 3300 psi and an MIT -OA to 1800 psi in June of 2019. After securing the well, the plan forward is to pull the floor kit, remove gravel to clean up any contamination, and perform diagnostics to determine the leak source and develop a repair plan. The well will remain SI and proper paperwork will be submitted for any repairs. Please let me know if you disagree with this plan or if you have any questions. Attached is a schematic and 90 -day TIO plot. Sincerely, sa,ra.CcwU&1&(He iu:v) /stephanu&pacIv Well Integrity & Compliance Specialist, WNS & CPF3 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 1 n25490cop com Cell: 907-331-7514 1 sara.e.carlisle(@cop.com MEMORANDUM State of Alaska Initial 15 Min 30 Min 45 Min 60 Min Alaska Oil and Gas Conservation Commission TO: Jim Regg I y/ �6 1 DATE: Wednesday, June 12, 2019 Mechanical Integrity Tests P.I. Supervisory ` i SUBJECT: 3300 . 3230 - 3220 CONOCOPMLLIPS ALASKA, INC. 2.1 BBL Ret: 2.1 OA 600 Returned: 3F -1I FROM: Guy Cook KUPARUK RIV UNIT 3F -I1 Petroleum Inspector ✓ Ste: Inspector Notes: MIT -IA to maximum anticipated injection pressure per AIO 2B.089. Job was completed with a Little Red Services pump truck and calibrated Reviewed By: P.I. Suprv-J3 NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3F-11 Insp Num: mitGDC190607181141 Rel Insp Num: API Well Number 50-029-21482-00-00 Inspector Name: Guy Cook Permit Number: 185-272-0 Inspection Date: 6/6/2019 ' Wednesday, June 12, 2019 Page I of 1 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3F-1 I Type lnj 'I W TVD 1611 Tubing ]651 2681 2682 '-Gso - PTD 1852720 iType Test. SPT I�Test psi 3000 IA 1120 3300 . 3230 - 3220 BBL Pumped: 2.1 BBL Ret: 2.1 OA 600 Returned: soon soo soo -- Interval REQVARJ IP/F P ✓ ✓ Notes: MIT -IA to maximum anticipated injection pressure per AIO 2B.089. Job was completed with a Little Red Services pump truck and calibrated gat Wednesday, June 12, 2019 Page I of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 12, 2019 TO: Jim Regg n P.I. Supervisor 1 %(13f Cj SUBJECT: Mechanical Integrity Tests l CONOCOPHILLIPS ALASKA, INC. 3F-11 FROM: Guy Cook KUPARUK RIV UNIT 3F-11 Petroleum Inspector Src: Inspector Reviewed By:p �� P.I. SuprvllF— NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3F -II Insp Num: mitGDC190607181536 Rel Insp Num: API Well Number 50-029-21482-00-00 Inspector Name: Guy cook Permit Number: 185-272-0 Inspection Date: 6/6/2019 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3F -I I - Type Inj W TVD 1672 Tubing 21680 2639 ]680 arao PTD 1852720 Type Testi sPT Test psi � 1800 IA 870 Oso 900 961 BBL Pumped: 0.8 - BBL Returned: o.a pA s6o 2000 9�n ,ao Interval REQVAR P/F P Notes: MIT -10 to 1800 psi per AIO 2B.089. Job was completed with a Little Red Services pump truck and calibrated gauges. Wednesday, June 12, 2019 Page I of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg '� DATE: Thursday,June 15,2017 P.I.Supervisor (I s(Zo ,7 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3F-11 FROM: Lou Laubenstein KUPARUK RIV UNIT 3F-11 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry ja/ NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3F-11 API Well Number 50-029-21482-00-00 Inspector Name: Lou Laubenstein Permit Number: 185-272-0 Inspection Date: 6/6/2017 Insp Num: mitLOL170607163410 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3F-11 Type Inj W TVD 5672 Tubing 2725 - 2725 2725 ' 2725 " PTD 1852720 " Type Test SPT Test psi 3000 IA 820 3500 3440 - 3420 BBL Pumped: 2.5 ' BBL Returned: 2.5 • OA 400 650 ' 650 650 Interval REQVAR P/F P ✓ Notes: MITIA per AIO 2B.089 to MAIP i SCIWAS SE) 052.0.: • Thursday,June 15,2017 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,June 15,2017 TO: Jim q276 /t 7 SUBJECT: Mechanical Integrity Tests P.I.Supervisor 1 CONOCOPHILLIPS ALASKA INC 3F-11 FROM: Lou Laubenstein KUPARUK RIV UNIT 3F-11 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3F-11 API Well Number 50-029-21482-00-00 Inspector Name: Lou Laubenstein Permit Number: 185-272-0 Inspection Date: 6/6/2017 Insp Num: mitLOLl70607163828 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3F-I I Type Inj W'TVD 5672 - Tubing 2725 2725 2725 - 2725 PTD 1852720 - Type Test SPT Test psi 1800 IA 820 960 975 • 975 ' BBL Pumped: 0.9 BBL Returned: 0.9 ' OA 400 2000 • 1920 ' 1900 Interval REQVAR P/F P '� Notes: MITOA to 1800 psi re AIO 2B.089 SCANNED :SEP 0 5 20r/ Thursday,June 15,2017 Page 1 of I ' S-2.-72 S '22-1 k,2 SAY 17 AN WELL LOG TRANSMITTAL#903268718 To: Alaska Oil and Gas Conservation Comm. May 13, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, Alaska 99501 M 5 nBENDER RE: Multi Finger Caliper&Bottom Hole Pressure Survey: 3F-11 Run Date: 4/25/2016 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 3F-11 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-21482-00 Static Bottom Hole Pressure Survey 1 Color Log 50-029-21482-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518SCON Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: / /_ ,/, • 111 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To Jim Regg ) / �ll DATE: Monday,January 25,2016 P.I.Supervisor ( I SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3F-11 FROM: Johnnie Hill KUPARUK RIV UNIT 3F-11 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry - NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3F-11 API Well Number 50-029-21482-00-00 Inspector Name: Johnnie Hill Permit Number: 185-272-0 Inspection Date: 1/17/2016 Insp Num: mitJWH160121130813 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min -------- --- T Well 3F-11 - Type Inj W 'TVD 5598 . Tubing 2890 2890- 2890 - 2890 PTD 1852720 Type Test SPT Test psi 3000 IA 770 3455 3410 ' 3400 Interval REQvAR P/F P ✓ OA 260 260 260 _ 260 Notes: MITIA per AIO 2B.089 to max anticpated psi 3.4 bbls diesel used - scoNED Monday,January 25,2016 Page 1 of 1 • S MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,January 25,2016 TO: Jim Regg Supervisor Ig k 7 l i SUBJECT: Mechanical Integrity Tests P.I.Pb CONOCOPHILLIPS ALASKA INC 3F-11 FROM: Johnnie Hill KUPARUK RIV UNIT 3F-11 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3F-11 API Well Number 50-029-21482-00-00 Inspector Name: Johnnie Hill Permit Number: 185-272-0 Inspection Date: 1/17/2016 Insp Num: mitJWHl60121131348 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min ----- -- --- -- -- —_ ---- - ----- Well! 3F-11 • I.Type Ind W'ITVD 5598 I Tubing 2890 2890 2890 - 2890 - PTD 1852720 - Type Test SPT Test psi, 1800 . IA 600 675 - 675 - 700 .Interval - Q' P/F P OA 260 2000 . 1930 - 1920 - Notes: MITOA per AIO 2B.089 to 1800 psi 2.1 bbls diesel used , sukNWn Monday,January 25,2016 Page 1 of 1 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. J_ ~ ~- ~.-'~ _'7.-- Well History File Identifier Organization (done) ~Two-Sided RESCAN DIGITAL DATA OVERSIZED (Scannable) 13 Color items: 13 Diskettes, No. 13 Maps: O Grayscale items: n Other, No/Type o Other items scannable by large scanner 13 Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: 13 Logs of various kinds 13 Other TOTALPAGES: ~r~ NOTES: ORGANIZED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: IS/ Project Proofing [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Isl PAGES: qC;~ (at the time of scanning) SCANNED BY~ J~BEVERL~ BREN VINCENT SHERYL MARIA LOWELL ReScanned (done) RESCANNEDBY~ BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: IS/ General Notes or Comments about this file: PAGES: ~ Quality Checked (done) RevlNOTScanned.wpd MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, June 07, 2011 TO: Jim Regg V / P.I. Supervisor ("t ( /( SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3F-11 FROM: John Crisp KUPARUK RIV UNIT 3F-11 Petroleum Inspector Src: Inspector Reviewed P.I. Supry -.ACP- NON-CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 3F-11 API Well Number: 50-029-21482-00-00 Inspector Name: John Crisp Insp Num: mitJCrl 10605214452 Permit Number: 185-272-0 Inspection Date: 6/5/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well -r 3F-11 - 1Type Inj. w TVD 5598 ' IA 720 2100 2060 2060 P.T.D 1852720 ' TypeTest SPT Test psi 1500 OA 400 500 500 500 Interval 4YRTST P/F P Tubing 2800 2800 2800 2820 Notes: 1 bbl pumped for test. No problems witnessed. JUN ?k, 01) Tuesday, June 07, 2011 Page 1 of 1 lVIEìVIORANDUM . State of Alaska . \Iaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supen isor r1 /i i<1'1 t'!1 l n\Tf: Tuesdav IlIne l~ ~OrF -, ( Sl BJECT: \!echanrcaIIIHCé:rrt\ TeSIS (-O:\OCOPH;LI~]:)S ,\L";'SK.\ ¡I \ ~6~'J-1'd- FROM: John Crisp Petroleum Inspector KI;PARUK RIV UNIT 3f-11 Src: Inspector Reviewed By: P.I. Suprv Sq,~ Comm NON-CONFIDENTIAL Permit Number: l85-272-0 Inspector Name: John Crisp Inspection Date: 6í8í2007 Well Name: KUPARUK R[V UNIT 3F-11 Insp Num: mitJCr070612[ [1804 ReI Insp N urn: API Well Number: 50-029-2[482-00-00 Initial 2980 15 Min. 30 Min. 45 Min. 60 Min. Packer Depth Pretest ; --~~--I-'----- -----,-- ------- -- Well i 3F-Il ìType Inj. , W ; TVD . 5672 : IA I 725 ------~---------¡-------T-¡--- ~--~-- ~-- P.T.D' 1852720~Typ~!e~SPT I Testpsi.-.l 1500 OA Interval 4YRTST P¡F P Tubing 2540 --------¡-..----...---- 2980 2980 700 700 700 -_.._-.---_.._~ ~_._._---- 2540 2539 2538 ----_._--------_.__.~_._.__.- ---~_.__.._---~_._- -~-- ----- ------ , --------- Notes: 2 bbl's pumped for test sCANNED JUN· 2 1 2G07 Tuesday. June [2. 2007 Page [ of 1 . '~ ConocoPhillips Alaska . P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 2, 2006 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, SuitesØANNED SEP 0 8200B Anchorage, AK 99501 \ I6G"d-Î ~ Dear Mr. Maunder: ? Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU) 3F Pad. Each of these wells was found to have a void in the conductor by surface casing annulus. The voids that were greater than 6 feet were first filled with cement to a level of 2.5 feet. The remaining volume, 2.5 to 6 feet of annular void respectively was coated with a corrosion inhibiter, RG2401, then filled with a viscous hydrocarbon based sealant, RG casing filler, 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 top-fill operation was completed on August 14,2006 and is reported as follows. Schlumberger Well Services mixed 15.7 ppg Arctic set I in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The corrosion inhibitor and sealant were pumped in a similar manner August 21-29, 2006. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Jerry Dethlefs or myself at 907-659-704~,1{You have any questions. // Sincerely, ß ii' .///' 7/ /Þ ð Æ,df/y;I/ /l / //1'~7 ItJz~/~~ /,' l- / :1 M.J.loveland ConocoPhillips Well Integrity Supervisor Attachment . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement and Sealant Top-off Kuparuk Field 8/31/2006 Initial Top Cement Final Top Sealant Well Name PTD # of Cement Volume of Cement Cement Volume Sealant Feet Barrels Feet Date Gallons Date 3F;P1 .' 18~~:~5/' .' . ',.')1''' . NA. . '. :,' '. '" I,' '. " " 8¡2·ifltg:o.~. . " " , 3F-02 1 85-226 24' 7.0 8/1 4/2006 7.5 8/21/2006 . " ~F;~3 :: 1;a~~~1;, . {c " J~'~" '. '2.3 . ',.:.> 81t41¿QP~ " I ' ··l;t~:· c·.'â/2!f/2,pn~:, . 3F-04 1 85-228 80' 22.7 1 0' 8" 8/14/2006 38.2 8/21/2006 .~ " . 5:1 c' ., . '. ...... :. . ..' ·8/1:412006 1.5" . ." ·gfg1~2Ø,«6'; . , 1 85-244 Did not modify 3F;!c),7; ....' " >¡:1ß;&f2:45·;i :'1", . '·c·. .'. , 6;6 . . I 8Jt4/ZQOô. . .; 7.5 .. .8/21:/2(100, . 3F-08 1 85-246 1 1 '4" 2.6 8/14/2006 6.6 8/21/2006 3R~()'9: ;" .. . :tß:5i-t.10 .'. Did not modify 3F-1 0 1 85-271 SF NA NA 6.6 8/21/2006 "~"" ''r . '1~~~}~"t I·..··. ·:,e.c· ';'.' ·,:',.NA.. .. '. I . '''",/''. . . 8~$fÂ.t1.UQ¡' 3F-12 1 85-273 7'4" 1 .8 ~2006 6.2 8/23/2006 ~ ' . NAc·... . .'. . :¿1:"" '7>"C.;c. ...... ) ·}.&¡¡t9f2'f)q~. . 1 85-292 Did not ~ 1.0 . "',, 2.4~ , . :.' . .' '. 811¿f/~ØØ62. ," "'Q:7 ". o.: ~S'2:$'lZØÐ() , f ,'" '--, ~ 3F-1 6 196-151 6" NA NA 2.7 8/23/2006 :3j7;..;11. ~ '.11" :. "3.1 .... . . . '. :8If4/~Ø~16:· c' a. '. ·81~1~j1~6. . 3F-1 8 196-112 4' NA NA 28 8/23/2006 :3F:;t9> c " c' 'zØîf[df[ß';: . ,.,-, ···.··.··WA·. . .- '8" . NÅ. . .'. ..... 2 . .. ". ·81~~/2Ø:Ø'6;, . 3F-20 199-079 36" NA NA 1 7.7 8/23/2006 3F-21. . ....:.. 2p{)i203 . .. . 45" NA NA . 31 ..8/2:i/2ÖÖ6 · STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Tom_Maunder@admin.state.ak.us and Bob_Fleckenstein@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk/KRU/3F 06/05/03 Arend/Brake - APC Chuck Scheve Packer Depth Pretest Initial 15 Min. 30 Min. We'll3F'07 ITypelnj I Gp I T.V.D. 15850 I Tubing I 25001 25001 ~001 ~S001 Interval P.T.D. 1185245o Type Test Test psi I 1500 I Casing I 11001 23001 22751 22751 P/F Notes: P.T,D. I1852460 Type Test Test psiI 1500 I Casing I 8001 22751 22501 22501 P/F Notes: P.T,D~..I1852720 Type Test Test psiI 1500 I Casingl 11001 23001 22751 22751 P/F Notes: Well 13F-12 P.T.D. IlS52730 Notes: Type Test Test psiI 15oo I Casing I 11501 22751 22501 22501 P/F P.T.D. I1852930 TypeTest Test psiI 1500 I Casing I 14001 23001 22801 22801 P/F Notes: P.T.D. I1961510 Type Test Test psiI 1500 I Casingl 01 23001 23001 23001 P/F Notes: Test Details: TYPE INJ codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover O = Other (describe in notes) MIT Report Form Revised: 05/19/02 2003-0605_MIT_K RU_3 F-07_-08_-11_-12_-15_-16A.xls 6/25/2003 ,CANNED ¢~UG O & ?__0'03 '~R.U MIT's Subject: KRU MIT's Date: Fri, 6 Jun 2003 15:28:32 -0800 From: "NSK Problem Well Supv" <n1617~conocophillips.com> To: bob_fleckenstein@admin.state.ak.us, tom_maunder@admin.state.ak.us, jim_regg@admin.state.ak.us CC: "nl 617" <nl 617~conocophillips.com> Attached are the 4 year cycle MIT Results for 3B and 3F. Please call with any questions. MJ Loveland Problem Well Supervisor ConocoPhillips Alaska Inc. (907) 659-7224, 659-7043 (See attached file: MIT KRU 3F 06-05-03.xls) (See attached file: MIT KRU 3B 06-05-03.xls) [~MIT KRU 3F 06-05-03.xls MIT KRU 3F 06-05-03.xls ~] Name: EXCEL File (applieation/msexeel)il Type: Encoding: base64 [~,MIT KRU 3B 06-05-03.xls Name: MIT KRU 3B 06-05-03.xls Type: EXCEL File (application/msexcel) ] Encoding: base64 I of 1 6/25/2003 4:37 PN STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Tom_Maunder@admin.state.ak.us and Bob_Fleckenstein@admin.state.ak.us OPERATOR: FIELD I UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk/KRU/3F 06/05/03 Arend/Brake - APC Chuck Scheve Packer Depth Pretest Initial 15 Min. 30 Min. welll3F'07 ' I Type lnj I Gp I T.V.D.-I 5850 I Tubingl 25001 25001 25001 25°°lInterval P.T,D. I1852450 Type Test Test psi I 1500 I Casing I 11001 23001 22751 22751 P/F Notes: We, 13F-08 I Typelnj T.V.D. 15726 I Tubingl 36501 36501 36501 36501Interval P-T-D-II852460I Type Test Test psiI 1500 I Casing I 8001 22751 22501 22501 P/F Notes: P.T.D. I1852720 Type Test Test psi I 1500 I Casing I 11001 23001 22751 2275I Notes: Well 13F-12 P.T.D. 11852730 Notes: IWelII3F-15 P.T.D. 11852930 INotes: IWe, 13F-~6A P.T.D. 11961510 Notes: Intervall ;P/F Type Test Test psiI 15oo I Casing I 11501 22751 22501 22501 P/F Type Test Test psiI' 1500 I Casing I 14oo1 23°°1 22801 228oI P/F Type Test Test psiI 1500 I Casing I 01 23001 23001 230OI P/F Test Details: TYPE INJ codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey. D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover O = Other (describe in notes) MIT Report Form Revised: 05/19/02 MIT KRU 3F 06-05-031 .xls 7/10/2003 MEMORANDUM ,. State of Alaska Alaska Oil and Gas Conservation Commission TO: Randy Ruedrich Commissioner THRU: Jim ~Regg . (~L?~I~ P.I. bupervlsor I FROM' Chuck Scheve Petroleum Inspector DATE: June 5, 2003 SUBJECT: Mechanical Integrity Test Conoco Phillips 3F Pad KRU NON- CONFIDENTIAL Well J 3F-07 P.T.D. J 185-245 Notes: VVellI 3F-08 P.T.D. J 185-246 Notes: Packer Depth Pretest Initial 15 Min. 30 Min. Type Inj. J G J T.V.D. J5850 J Tubing J2500 J2500 J2500 J2500 J lntervalJ 4 Type testJ P J TestpsiJ 1463 JCasingJ 1100 J 2300 J 2275 J 2275 J P/F J _.P jTypetestJType P JTestpsiJ 1432 J CasingJ 800 J 2275 J 2250 J 2250 J P/F J -PI I Well J 3F-11 P.T.D. J 185-272 Notes: WellI 3F-12 P.T.D. J 185-273 Notes: WellI 3F-15 P.T.D. I 185-293 Notes: WellI 3F-16A P.T.D.I 196-151 Notes: I Typelnj.I S I T.V.D. I ~ ITM I~'~° I~'~° I~'~° I185° I'nte~va'l 4I I TypetestI P ITestpsil 1400 I Casingl 1100I 2300I 2275I 2275I P/F I P I IT,,e'ni.I s I T.V.~,. I ~' ITubing I13°° I13°° I13°° I13°° I'nterva'l 4 Type testI P I Testpsil 1407 I CasingI 1150I 2275I 2250I 2250I P/F I P I T ,e,ni.I~ I T.V.~. I~ I Tu~n~13500 13500 1350O 13500 I'nterw'l 4 TypetestIP ITestpsil 1418 I Casingl 1400I 2300I 2280I 2280I P/FI --P JTypelnj. J S J T.V.D. 14988 J Tubing'J 2550 12550 12550 12550 J,nterva, J 4 TypetestJ P JTestpsiJ 1247 J CasingJ 0 J 2300 I 2300 I 2300 I P/F J _P ,/ Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to Conoco Phillips 3F Pad in the Kuparuk field and witnessed the rout/ne 4 year MIT's on the above listed 6 wells. The pretest pressures were observed and found to be stable. The standard annulus pressure tests were then performed with all wells demonstrating good mechanical integrity. M.I.T.'s performed: _6 Number of Failures: 0 Attachments: Total Time during tests: 4 hours cc: MIT report form 5/12/00 L.G. 200'3-0605_M IT_KRU_3F- 16A_cs.xls 6/24/2003 SCANNED JUL 0 ? 200:3 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELl. OPERATIONS 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510~0360 4. Localion of well at surface 5244' FNL, 114' FEL, Sec. 19, T12N, R9E, UM At top of productive intewal 1419' FSL, 1335' FWL, Sec. 30, T12N, R9E, UM At effective depth 5. Type of Well: Development_ Sen4ce~X (asp's 508384, 5985858) ,At total depth 4230' FNL, 3827' FEL, Sec. 30, T12N, R9E, UM (asp's 504691, 5981588) 12_ Present well condition summary 'l'otal depth: measured ~ ver'dcal 8654 feet Plugs (measured) 6187 feet 6. Datum elevation (DF or KB feet) RKB 93 feet 7. Unit or Property name Kuparuk Unit 8. Well number 3F-11 9. Permit number / approval numbe~ 185-272 / 10. APl number 50-029-21482 11. Field / Pool Kuparuk Oil Pool EffeclNe depth: measured feet Junk (measured) true vertical feet Casing Leagth Size Cemented Measured Depth CONDUCTOR 115' 16' 268 sx AS n 115' SUR. CASING 3750' 9-5/8' lO2O sx PF E & 445 sx PFC Perle 3843' PROD. CASING 8361' 7' 250 sx Class G & 175 sx PFC 8454' True veftic~De~th 115' 3024' 6048' 13. Stimulation or cement squeeze summary .- :....:.:::.:.:.:.: : .: : : - : . :.:.:.:.:.:...:..- :........:..: :.:.:...-.- : ..... :...: :...: - ........... :... Intervals ~eated (measured) Treatment description including volumes used and final pressure '<:::.iiiii:::!ii!:i:;:;.i.::i:i '"';:i: ii: i'i!.:ii;i'i;i i:i ;'; ;: i;?:;.:.; ..' ;-iii':';-.':::'i:.i'} ' 14. Prior to well operalJon Subsequent to operalJon Representative Daily Average Production or Injection Data .... Oil~Bbt . . C~3s_ ~MCf . Waler:Bbl. C..a.~.'ng Pressure T ..u~_ .g pm~ ::::-.;-:;.:-: : :::: --: . ..... :-:-:::::-: : :-:::-:-: ::-:-::;:::-;:.:-:-: :.; : :::-;::- . .:.: . .......... ........ ... 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X 17. I hereby ceCdfy that the foregoing is true and correct to the best of my knowledge. Signed ~1~" ~ ~ Titie Production Engineedng Supervisor Jeff A. Spencer Questers? Call Jeff Sp~/~er 659-7226 3F-11 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 1(:t/28/2001[~~ WAG EOR InjeCtion ] -- STATE OF ALASKA ALASK~ OIL AND GAS CONSERVATION C~,,VlMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well [] Oil [] Gas .~ Suspended [] Abandoned ~ Service Classification of Service Well Water & Gas Injector 2. Name of Operator 17. Permit Number ARCO Alaska Inc. 85-272 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50-029-21482 9. Unit or Lease Name Kuparuk River Unit 4. LocaMo~ of well at surface 32' FSL, 112' FEL, Sec. 19, T12N, RDE, UM At top of producMve interval 1419' FSL, 1335' FWL, Sec. 30, T12N, RDE, UM At total dep~ 1077' FSL, 3786' FEL, Sec. 30, T12N, R9E, UM 10. Well Number 3F-11 11. Field and Pool Kuparuk River 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. RKB 93' I ADL 25643, ALK 2574 8600 6149 FT~ 8365 5986 FT~ [] Yes [] No ~ N/A MD! 1465' (Approx.) 22. Type Electric or Other Logs Run 23. CASING SIZE Wt. PER FT. GRAD6 CASING, LINER AND CEMENTING RECORD SE'I-rING DEPTH I HOLE I TOP Bo'FrOM ] ..S..!ZE I CEMENTING RECORD Surf. 115' ] 24" ]268sxASII Surf. 3843' ] 12.25" 11020 sx PF 'E'& 445 sx PF 'C' I IPerfo~med tbp job wi60 sx PF 'C' 8454' sx Class G & 175 sx PF 'C' 16" 62.5# H-40 ~ 9-5/8" 36.0# J-55 7" 26.0# J-55 Surf. 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) MD 'FVD MD TVD 7989'-8013' 5725'-5742' i815~ i250 AMOUNT PULLED 8121 '-8142' 5817'-5831 ' 8167'-8225' 5849'-5889' 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" X 2-7/8" 8043' & 8077' 7804' & 7911' & 8054' 26. AC~D FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production iMethod of Operation (Flowing, gas lift, etc.) i Water Injection Date of TestiHours Tested IPR~ucT,~ FORIO,L-BBL IGAs'MCF I ITEST PERK:X)' I Fi0w TubingiCasing pressure~ALCULATED . IOiL:BBL GAS-MCF Press. ! I24-HouR RATE j 28. CORE DATA WATER-BBL WATER-BBL iCHOKE SIZE i GAs-OIL RATIO OiL GRAviTY-APi (CoRR) Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED · , , i\ t ~,_:' =?~ , ' i'~ i i"d~., FEB 5 1997 Alaska Oil & Gas Cona. Cornrnis~ion Anchorage Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Marl, ~ 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Total Volume Pumped to Date = 3708 bbls Top Kuparuk C 7985' 5723' Bottom Kuparuk C 8013' 5742' Top Kuparuk A 8080' 5789' Bottom Kuparuk A 8276' 5925' Freeze protected annulus with diesel. 131. List of Attachments Summary of Daily Drilling Reports 32. I hereby certify that the foregoing is true and correc{ to the best of my knowledge Signed ~J'L ~. ~ ^,,,.,....--..._ Title ~tr-~T.,L- ~r.~l~li, Date "L - ~-cl 3r Prepared By Name/Number: 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 cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ., Date: '11/19/96 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 REMEDIAL AND COMPLETION OPERATIONS WELL:3F-11 RIG:NORDIC WELL ID: 998412A TYPE: AFC:--998412 AFC EST/UL:$ 295M/ 345M STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD:10/21/96 START COMP:10/22/96 FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-21482-00 10/22/96 (C 1) TD: 8600' PB: 8365' SUPV:DEB DAILY:$ WEIGHT UP BRINE TO 12.3 P MW:12.3 BRINE Accept rig @ 1630 hrs. 10/21/96. pump sea water down tubing to kill well. 87, 691 CUM:$ 175,382 ETD:$ 0 EFC:$ 470,382 10/23/96 (C 2) TD: 8600' PB: 8365' SUPV:DEB DAILY:$ POH LD 3.5" TUBING MW:12.3 BRINE Kill well by injecting brine to flush out tail & 'A' sand perfs. Well dead. Test all BOPE equipment. POH - LD 3.5" tubing & jewelry. 31,970 CUM:$ 239,322 ETD:$ 0 EFC:$ 534,322 10/24/96 (C 3) TD: 8600' PB: 8365' SUPV:DEB DAILY:$ RUNNING 3.5" TUBING MW:12.3 BRINE POH - LD 3.5" tubing and jewelry. MU overshot guide on first joint & run 3.5" completion assembly 69,359 CUM:$ 378,040 ETD:$ 0 EFC:$ 673,040 10/25/96 (C 4) TD: 8600' PB: 8365' SUPV: DEB DAILY: $ SET MA2 PLUG IN Wi NIPPLE MW:12.3 BRINE Run 3.5" tubing and jewelry. Land tubing hanger. RIH & set MA2 plug in W-1 nipple. 116,683 CUM:$ 611,406 ETD:$ 0 EFC-$ 906,406 10/26/96 (C 5) TD: 8600' PB: 8365' SUPV:DEB DAILY:$ RIG RELEASED MW: 0.0 Set MA2 plug in W-1 nipple @ 7850' SLM. ND BOPE. NU tree. Test packoff to 5000 psi. Test tree to 250/5000 psi. Freeze protect well. Secure well. Release rig @ 2400 hrs. 10/25/96. 34,231 CUM:$ 679,868 ETD:$ 0 EFC:$ 974,868 End of WellSummary for Well:998412A RECEIVED FEB 5 1997 Alaska 0il & Gas Cons. Commissio. Anchorage ARCO hlaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 4, 1997 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 3F-11 (Permit No. 85-272) Well Completion Report ORIGINAL Dear Mr. Commissioner: Enclosed is the well completion report to cover any changes made to the completion during the recent workover operations on KRU 3F-11. During the workover operations, the 3.5" tubing was cut and pulled above the top packer. The well was recompleted using an overshot to tie-back into the original completion and a retrievable packer was set above the overshot to provide isolation between the 3.5" tubing and the 7" annulus. If there are any questions, please call 263-4622. Sincerely, W. S. Isaacson Drilling Engineer Kuparuk Drill Site Development RECEIVED FEB 5 19 7 Alaska Oil & Gas Cons. Commislion Anchorage WSI/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION U REPORT OF SUNDRY WELL OPERATIONS RIGINAL 1. Operations Performed: Operation Shutdown__ Pull tubing Alter casing 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 9951O Stimulate __ Plugging Perforate _ Repair well Other X 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 32' FSL, 112' FEL, Sec. 19, T12N, R9E, UM At top of productive interval 1422' FSL, 3506' FEL, Sec. 30, T12N, R9E, UM At effective depth 1210' FSL, 3680' FEL, Sec.30, T12N, R9E, UM At total depth 1077' FSL, 3786' FEL, Sec. 30, T12N, R9E, UM 6. Datum elevation (DF or KB) 93' RKI~ 7. Unit or Property name Kuparuk River Unit 8. Well number ;~F-11 9. Permit number/approval number 85-272 10. APl number 50-029-21482 11. Field/Pool Kul3aruk River Oil Pool feet 12. Present well condition summary Total Depth: measured Effective depth: Casing Structural Conductor Sudace Intermediate Production Liner Perforation depth: 8600' true vertical 61 4 9' measured 83 6 5' true vertical 5 9 8 6' Leng1~ Size 80' 16" 3808' 9 5/8" 8419' 7" measured feet Plugs (measured) feet None feet Junk (measured) feet None Cemented Measured depth True vertical depth 260SxAS II 115' 115' 1020 Sx PF E & 3843' 3024' 445 Sx PFC 250 Sx Class G & 8454' 6048' 175Sx PFC 8167'-8225', 7989'-8083', 81 21'-8142' true vertical 5849'-5890', 5725'-5791', 5816'-5831' RECEIVED 13. Tubing (size, grade, and measured depth) 3 1/2" J-55 w/ tbg tail at 8088' Packers and SSSV (type and measured depth) Otis RRM @ 7922', Otis WD ~ 8065', Camco SSSV @ 1820' Stimulation or cement squeeze summary SE P 2 ? 199t Alaska Oil & G~s Con~. ~mmi~i~n Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation -600- -480- 0 1200 120 Subsequent to operation - 0- -0- 5000 350 1600 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Water Injector x Oil _ Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si, ned '~i~'~'' ~ Title ~~'~¢¢[ ¢~ Form 10-404 Rev 09/12/90 SUBMIT IN DUPLICATE ARCO Alaska, Inc. Sul~'(:liary of Atlantic Ricl~fielcl Company WELL 3F-Il ,ITRACTOR REMARKS FIELD- DISTRICT- STATE OPERATION AT REPORT TIME WELL SERVICE REPORT 1140 J ~20 SEP 2 7 t991 u,, ~= C,c=~ C~.".~. ~em- miS$ier~ N~chorage CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ARCO Alaska, Inc, SuDsidia~y of Atlantic Richfield Company WELL PBDT REMARKS WELL SERVICE REPORT I OPEi~A~E PORT TIME FIELD - DISTRICT- STATE iDAYS : DATE 1130 SEP 2 7 Alaska Oil & Gas Cons. Anchorage [-'] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather Chill Report ITemp' Flctor I Visibility Vel. ARCO Alaska, Inc. August 24, 1990 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached in duplicate are multiple Reports of Sundry Well Operations notices in the Kuparuk field. The wells are listed below. WELL ACTION 3C-03 Stimulate 3F-1 1 Stimulate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Operations Engineer cc: J. R. Brandstetter L. L. Perini KOE1.4-9 ATO 1120 ATO 1130 E6EIVED AUG 2 9 1990 Alaska 0ii & Gas Cons. Comn~issi_Q[t ~Ulchorag. w/o attachments STATE OF ALASKA A~ OIL AND GAS CONSERVATION COMMIS,'SION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown Pull tubing Alter casing Stimulate X Plugging Perforate Repair well Pull tubing Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service Location of well at surface 32' FSL, 112' FEL, Sec. 19, T12N, R9E, UM At top of productive interval 1422' FSL, 3506' FEL, Sec. 30, T12N, At effective depth 1210' FSL, 3680' FEL, Sec. 30, T12N, At total depth 1077' FSL, 3786' FEL, Sec. 30, T12N, R9E, UM R9E, UM R9E, UM 12. Present well condition summary Total Depth: measured 8 6 0 0' true vertical 61 4 9' 6. Datum elevation (DF or KB) 93' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number ;~F-11 9. Permit number/approval number 85-272 10. APl number 50-029-21482 11. Field/Pool Kuparuk River Oil Pool feet Plugs (measured) feet None Effective depth' measured 8 365' true vertical 5 98 6' feet Junk (measured) feet None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 80' 16" 3808' 9 5/8" 8419' 7" measured 8167'-8225', true ve~ical 5849'-5890', Tubing (size, grade, and measured depth) 3 1/2", 9.3#, 8088' Cemented 260 Sx AS II 1020Sx PF E& 445 Sx PF-C Measured depth 115' 3843' True vertical depth 115' 3024' 250 Sx Class G & 175 SX PF-C 7989'-8083', 8121'-8142' 8454' 6048' REEEIVED 5725'-5791' 5816'-5831' AUG 2 9 1990 Alaska 0il & Gas Cons. 6ommiSsio[~ Packers and SSSV (type and measured depth) .~0Mra~~ PKRs @ 7922', 8065', (Otis RRM & Otis WD), SSSV @ 1820' (Camco TRDP-, ,.,,,,.,/ge 13. Stimulation or cement squeeze summary A Sand Refracture treatment. Intervals treated (measured) 8121'-8142', 8167'-8225' Treatment description including volumes used and final pressure See attached report 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 610 503 - 0- 1140 110 Subsequent to operation 630 535 - 0 - 1 140 1 1 0 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. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~Ined ~~x~)' ~/t~ Title Senior Operations Engineer Fnrm 1 f3-4134 Rp.v f').~/1 7/R.q Date RI IRMIT IN 1311Pl IC, ATF ARCO Alaska, Inc. Sublidi~r/of Atlm~tic Rtcttfletd Company WELL 4TRACTOR REMARKS IPBDT WELL SERVICE REPORT FIELD- DISTRICT- STATE OPERATION AT REPORT TIME '1~3110° V© c... 1.5o 4. oo 43,0 'TOT ~-.(_. A U G ~: 9 i990 Alaska 0il & Gas Cons. C0mmtsston r'-] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK W#ther 1 TemP'Report 'F I Chill Fact°r I VisIbIIItY'F miles Iwi''" v'~' knots Sr^ EO 0 ~ OIL AND GAS CONSERVATION COMMIS,'~,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 _ 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 32' FSL, 112' FEL, Sec. 19, T12N, R9E, UM At top of productive interval 1422' FSL, 3506' FEL, Sec. 30, T12N, R9E, UM At effective depth 1210' FSL, 3680' FEL, Sec.30, T12N, R9E, UM At total depth 1077' FSL, 3786' FEL, Sec. 30, T12N, R9E, UM 6. Datum elevation (DF or KB) RKB 93 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 3F-11 Producer 9. Permit number 85-272 10. APl number 5o-029-21 482 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool 12. Present well condition summary Total Depth' measured true vertical Effective depth' measured true vertical Casing Length Structural Conductor 8 0' Surface 3 8 0 8' Intermediate Production 8 41 9' Liner Perforation depth: measured 8167'-8225', true vertical 5849'-5890', Tubing (size, grade, and measured depth 3 1/2", 9.3#, @ 8088' Packers and SSSV (type and measured depth) 86 0 O' feet 61 4 9' feet 8365' feet 5 9 8 6 feet Size 16" 9 5/8" ,, Plugs (measured) Junk (measured) Cemented Measured depth True vertical depth 260SxAS II 115' 115' 1020 SX PF E & 3843' 3024' 445 SX PFC 250 Sx Class G & 8454' 6048' RECEIVED 7989'-8083', 8121'-8142' 5725'-5791', 5816'-5831' AU G 2 9 1990 Alaska 0il & Gas Cons. C0mmiSs[on Anchorage PKRs @ 7922' & 8065' (Otis "RRM" & Otis "WD"), SSSV @ 1820' (Camco TRDP-1-SAM) 13. Attachments Description summary of proposal ~ Detailed operation program _ BOP sketch Waterflood Conversion. 14. Estimated date for commencing operation 11/1/90 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil m Gas m Suspended Service Water In!ection 17. I hereb~c~th~ the foregoing is true and correct to the best of my knowledge. Si~ned . ~ Title Senior Operations Engineer FOR CC~MI~N USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test Location clearance Mechanical Integrity Test ,~' Subsequent form require / Approved by the order of the Commission Form 10-403 Rev 5/03/89 ORIGINAL SIGNED BY LONNIF, G, SMITH Approved Copy ~.,~..Retl, i r n ed Commissioner IApproval No. / SUBMIT IN TRIPLICATE Kuparuk Well 3F-11 Permission is requested to convert Kuparuk Well 3F-11 from an oil producer to a water injector. This will help complete the development of the 160 acre line drive waterflood patterns on drill site 3F and provide needed reservoir pressure support for offset drill site 3G. Drill site 3G is currently being developed and is scheduled for production start up in late September. REEEIVED AUG 2 9 1990 Alaska Oil & Gas Cons. (;ommiss[o~ Anchorage ARCO Alaska, Inc. -- Post Office . _ ~360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 9, 1990 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Attached in triplicate are multiple Applications for Sundry Approvals on the following Kuparuk wells. Well Action Anticipated Start Date 2U-15 Stimulate April, 1990 3F-11 Stimulate April, 1990 3Q-11 Stimulate April, 1990 If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Operations Engineer cc: J. Gruber ATO 1478 J. R. Brandstetter ATO 1120 L. Perini ATO 1130 KOE1.4-9 w/o attachments APR 12 Oil & Gas Cons. chorag ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany AIq3B 6002 C - STATE OF ALASKA . ~ OIL AND GAS CONSERVATION COMMIS,'~ION 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 X 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 X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 32' FSL, 112' FEL, Sec. 19, T12N, R9E, UM At top of productive interval 1422' FSL, 3506' FEL, Sec. 30, T12N, R9E, UM At effective depth 1210' FSL, 3680' FEL, Sec.30, T12N, R9E, UM At total depth 1077' FSL, 3786' FEL, Sec. 30, T12N, R9E, UM 6. Datum elevation (DF or KB) RKB 93 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3F-11 Producer 9. Permit number 85-272 10. APl number 5o-029-21 482 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 8 0' Surface 3 8 0 8' Intermediate Production 8 41 9' Liner Perforation depth: measured 8167'-8225', true vertical 5849'-5890', Tubing (size, grade, and measured depth 3 1/2", 9.3#, @ 8088' Packers and SSSV (type and measured depth) 8600' feet 61 4 9' feet 8 3 6 5' feet 5 9 8 6 feet Size 16" 9 5/8" ,, Plugs (measured) Junk (measured) Cemented 260 Sx AS II 1020SXPFE& 445 SX P F C 250 Sx Class G & 175 Sx PFC 7989'-8083' MD 5725'-5791' TVD Measured depth True vertical depth 115' 115' 3843' 3O24' 8454' 6048' PKRs @ 7922' & 8065' (Otis "RRM" & Otis "WD"), SSSV @ 1820' (Camco TRDP-1-SAM) 13. Attachments Description summary of proposal X Detailed operation program _ BOP sketch A Sand refracture treatment. 14. Estimated date for commencing operation May 15. 1990 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil z.~ Gas __ Suspended Service 17. I hereby/,~_,ertify that .the fo~ue and correct to the best of my knowledge. Si~ned - Title Senior Operations Engineer FOR COMMISSION USE ONLY Date q'"-? '" ?~ Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test _ Location clearance m Mechanical Integrity Test_ Subsequent form require Approved by the order of the Commission nR'~'_ ,o!NAL SIGNED BY LONNIE C. SMITH IApproval No. 10- ~ .z~ . ~d · Commissioner Date '~ /& - //? Form 10-403 Rev 5/03/89 SUBMIT IN TRIPLICATE Well 3F-11 A Sand Refracture Treatment ARCO requests permission to refracture the A Sand in Well 3F-11. This sand was originally refractured on 2/11/86 with 7800 pounds of 20/40 mesh sand and used 100 mesh sand for leakoff control. The new fracture treatment will use 34,000 pounds of 16/20 mesh Carbolite and will not use 100 mesh sand for leakoff control. ARCO Alaska, Inc. Date: February 23, 1989 Transmittal #: 7432 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk 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. 3F-15 3N-18 3F-01 3F-02 3F-09 3F-06 3F-10 3F-11 3F-15 3F-14 3N-10 3N-06 3N-09 31-01 3N-11 3N-14 3F-08 3N-01 3N-14 3F-15 3F-15 3F-13 3F-15 1B-05 1E-25 3B-11 3A-03 3H-01 2Z-19 31-12 1E-08 3M-18 Ku 3aurk Ku 3aurk Ku 3aurk Ku 3aurk Ku3aurk Ku 3aurk Ku3aurk Ku 3aurk Ku ~aurk Ku )aurk Ku )aurk Ku )aurk Kupaurk Kupaurk Kupaurk Kupaurk Kupaurk Kupaurk Kupaurk Kupaurk Kuparuk Fluid Level Report I 2 Fluid Level Report I 2 Fluid Level Report Fluid Level Re~ Fluid Level Re Fluid Level Re Fluid Level Re Fluid Level Re Fluid Level Re Fluid Level Re Fluid Level Re Fluid Level Re Fluid Level Re Fluid Level Re Fluid Level Re Fluid Level Re Fluid Level Re Fluid Level Re Fluid Level Re Fluid Level Re Well 3ort 3ort 3ort 3ort 3ort 3ort 3ort 3ort 3ort 3ort 3ort 3ort 3ort ~ort ~ort ~ort 3ort Pressure Report Kuparuk Well Pressure Report Bottom-Hole Pressure Survey Kuapruk Well Pressure Report Kuparuk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report Kupaurk Fluid Level Report 12 -03-87 -18-87 8-29-87 8-29-87 8-29-87 8-29-87 8-29-87 8-29-87 8-29-87 8-29-87 5-18-87 5-22-87 5-21-87 4-24-87 4-15-87 4-13-87 4-14-87 4-20-87 -O4-87 2-02-89 8-27-87 8-27-87 8-25-87 2-2O-89 2-19-89 2-20-89 2-21-89 2-21-89 2-2O-89 2-20-89 2-19-89 2-15-89 Casing Casing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Casing Casing Casing Casing Casing Casing Casing Casing Casing Tubing Sand 'C' Sand 'C' BHP Amerada Casing Casing casi.g casing Tubi.g mubin~ casi.l Casin~ 3 H-01 Kupaurk Fluid Level Report 2-15-89 Casing 3 B- 1 3 Kupaurk Fluid Level Report 2-17-89 Casing I E-29 Kupaurk Fluid Level Report 2-15-89 Casing 1 C-05 Kupaurk Fluid Level Report 2-18-89 Casing/Tubing 3M- 1 7 Kupaurk Fluid Level Report 2-16-89 Casing 2Z-20 Kupaurk Fluid Level Report 2-18-89 Tubing 30-1 0 Kupaurk Fluid Level Report 2-16-89 Casing 31-1 2 Kupaurk Fluid Level Report 2-20-89 Tubing 3 H - 1 0 BHP Report 2-13-89 BHP Receipt Acknowledged: ........................... Date: ............ DISTRIBUTION: D&M State of Alaska SAPC Unocal Mobil Chevron Ar;chorage ~'u'~,~,$S,.of~ ARCO Alaska, Inc. Date: February 17, 1989 Transmittal #: 7429 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk 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. 3F- 11 Sub-Surface Pressure Survey I 0-06-88 3 H-12 Kuparuk Well Pressure Report 8-29- 88 30-07 Kuparuk Well Pressure Report I 2-20-88 3F- 10 Kuparuk Well Pressure Report 8-29- 87 3 F o 06 Kuparuk Well Pressure Report 8 - 29 - 87 3F-02 Kuparuk Well Pressure Report 8-29- 89 3F-16 Kuparuk Well Pressure Report 8- 17- 87 3F-16 Kuparuk Well Pressure Report 8- 17- 87 3F- 11 Kuparuk Well Pressure Report 8-29- 87 3 Fo04 Kuparuk Well Pressure Report 6-26- 87 3 F-05 Kuparuk Well Pressure Report 12- 12-88 3F- 13 Kuparuk Well Pressure Report 12-31 -88 3N-10 Kuparuk Well Pressure Report 6- 11 - 87 3N-10 Kuparuk Well Pressure Report 6 o 11 - 87 3N-04 Kuparuk Well Pressure Report 9- 01 - 87 3 N - 09 Kuapruk Fluid Level Report 5 - 04 o 87 3 O- 14 Kuparuk Fluid Level Report 2- 13 - 89 3 O- 14 Kuparuk Fluid Level Report 2 - 10 - 89 3Mo 18 Kuparuk Fluid Level Report 2- 10- 89 3 F- 16 Kuparuk Fluid Level Report 6 o 05 - 87 3F- 13 Kuparuk Fluid Level Report 6- 09- 87 3 F- 13 Kuparuk Fluid Level Report 6 - 18 - 87 3 F- 13 Kuparuk Fluid Level Report 6 - 16 - 87 3 F o 13 Kuparuk Fluid Level Report 6 - 21 o 87 3 F- 08 Kuparuk Fluid Level Report 5 - 08 - 87 3 F- 16 Kuparuk Fluid Level Report 8 - 18 - 87 3 F- 16 Kuparuk Fluid Level Report 8 - 24 - 87 3 F- 13 Kuparuk Fluid Level Report 6 - 05 o 87 3Fo 16 Kuparuk Fluid Level Report 6- 2/3- 8 7 3 F- 16 Kuparuk Fluid Level Report 8 - 5 - 87 3 F- 16 Kuparuk Fluid Level Report 6 - 5 - 8 7 3F- 14 Kuparuk Fluid Level Report 9-8- 87 #7-889 Amerada Sand 'A' Amerada Amerada Amerada Sand 'A' Sand 'A' Amerada Sand 'A' Both Sands Both Sands Sand 'A' Casing Casing Casing Casing Tubing Casing Casing Casing Anct~orage Tubing Casing Casing 3F-14 3F-06 3F-14 3F-08 3F-14 3F-09 3F-05 3F-09 3F-06 3F-05 3N-10 3N-10 3N-11 3N-10 3N-05 3N-04 3N-13 3N-11 3N-18 3N-17 3N-07 3N-15 3N-05 3N-09 3N-04 3N-14 3N-08 3N-06 3N -02 3N-10 3N-10 3N-10 3N-10 3N-10 3N-10 3N-10 3N-07 3N-01 3N-04 3N-04 3N-09 3N-10 Receipt Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Ku ~aruk Fluid Ku ~aruk Fluid Ku ~aruk Fluid Ku :)aruk Fluid Ku ~aruk Fluid Ku ~aruk Fluid Ku :)aruk Fluid Ku :)aruk Fluid Ku aaruk Fluid Acknowledged: Level Level Level Level Level Level Level Leyel Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Level Report Report Report Report Report Report Report Report Report Report Report Report Report Report Report Report Report Report Report Report Report Report Report Report Report Re ~ort Re ~ort Re ~ort Re :)orr Re :)orr Re :)orr Re aort Re ~ort Reaort Re aort Re aort Report Report Report Report Report Report 9-1 I-87 12-06-86 9-11-87 10- 11 -87 9-16-87 4-11-88 4-08-88 4-01 -88 3-26-88 1 -30-88 10-12-87 10-15-87 10-28-87 10-28-87 10-28-87 10-28-87 3-19-87 9-12-87 9-10-98 9-10-87 9-10-87 9-12-87 9-08-87 9-01 -87 9-01 -87 9-06-87 9-06-87 9-06-87 9-06-87 6-01 -87 5-31 -87 6-03-87 6-06-87 6-08-87 6-09-87 6-25-87 4-17-87 4-18-87 6-17-87 6-20-87 5-07-87 8-24-87 ........................... Date: Casing Tubing Casing Tubing Casing Casing Casing Casing Casing Casing Casing Casing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Casing Casing Casing Casing Casing Casing Casing Casing Casing Casing/'~ ,~7 f- r" ~ ! ,, ,.. Alaska Oil & Gas Ccn;. ....... ~orage ,,~c,-, DISTRIBUTION: D&M State of Alaska Mobil Chevron Unocal SAPC ARCO Alaska. Inc. ~os! Cffic~ B~ ,360 .anchorage. AlasKa 99510-0360 TeieDnone 907 276 12!5 November 9, 1988 Mr. C. V, Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached in duplicate are multiple Reports of Sundry Well Operations on the following Kuparuk wells. Conyersions 3N-11, 3N-10, 3No05, 3N-04, 3F-12, 3F-03, 3F-08, 3N-03, 13, 1E-21, 1E-19, 1E-23, 1E-lA, 1E-04, 1E-16 and1E-27 .Fractures and Stimulations '3K-14, 3C-16, 3K-17, 1E-14, 3N-17, 3F-16 and 2V-12 Perforations 3N-11, 3F-11 and 3N-SA 1E-30 Failed MIT, 3N-12, 3N- If you have any questions, please call me at 265-6840. Sincerely, G. B. Sn'~llwood Senior Operations Engineer Attachments cc: J. Gruber M. L. Hagood S. P. Twiggs KOE1.4-9 AT© 1478 ATO 11 20 ATO 113O RECEIVED Nov 1 6, 1988 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown m Stimulate __ Plugging Perforate X Pull tubing Alter casing Repair well Pull tubing Other 2. Name of Operator ARCO Al¢¢ka. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 32' FSL, 112' FEL, Sec. 19, T12N, R9E, UM At top of productive interval 1422' FSL, 3506' FEL, Sec. 30, T12N, R9E, UM At effective depth 1210' FSL, 3680' FEL, Sec. 30, T12N, R9E, UM At total depth 1077' FSL, 3786' FEL, Sec. 30, T12N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 6. Datum elevation (DF or KB) RKB 93 7. Unit or Property name Kuparuk River Unit 8. Well number ~F-11 Producer 9. Permit number/approval number 8-325 10. APl number 50-029-21482 11. Field/Pool Kuparuk River Oil Pool 8600' MD feet Plugs (measured) NONE 6149' TVD feet feet Effective depth: measured 8365' MD feet true vertical 5986' TVD feet Junk (measured) NONE Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 80' 1 6" 260 SX AS II 115' MD 115' TVD Surface 3808' 9 5/8" 1020 SX PF E 3843' MD 3024' TVD Intermediate & 445 SX Class G Production 841 9' 7" 250 Sx Class G 8454' MD 6048' TVD Liner & 175 PFC Perforation depth: measured 8167'-8225' MD, 7989'-8083' MD true vertical 5849'-5890' TVD, 5725'-5791 TVD Tubing (size, grade, and measured depth) 3-1/2", 9.3#, @ 8088' MD Packers and SSSV (type and measured depth) Pkrs @ 7922' & 8065' (Otis "RRM" & Otis "WD"), SSSV @ 1820' (Camco TRDP -1A-SAM) 13. Stimulation or cement squeeze summary L JV Intervals treated (measured) 14. Treatment description including volumes used and final pressure Representative Daily Average Production or Injection D~"aw ~" & CF; ,.,,, .... OiI-Bbl Gas-Mcf Water-Bbl Casing pressu ~'' 9r~oing Pressure Prior to well operation 106 90 0 1 1 00 152 Subsequent to operation 664 914 0 1 225 188 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. Signed / '~'~ Form 10-404 ~ 06/15/8~ Date ?///~/~ f~ SUBMIT IN DUPLICATE ARCO Alaska, Inc.~¢~ Subs,diary of Atlantic Richfield Compan' WELL SERVICE REPORT WELL jr dDT ~7-.- // ' ~' ~z..~' ~ONTRACTOR HEMARKS tFIELD - DISTRICT- STATE OPERATION AT REPORT TIME DATE 0700 i~ I ~ U ~4,~H~,~ T d/z-/Nd '::1 z/ ~- ~ I P I,,1 VE'~ O t:?, T, U~ / 7F )0/~' · .;/_, r_,;! & G:' -; (;n-:~ £:'mr,fis~:~. [] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather tTemp' I Chill Fact°r 1 Visibility IWind vel'Report OF OF miles knots STATE OF ALASKA ALASK,-, ,glL AND GAS CONSERVATION COMN. 4,51ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon - Suspend - Operation Shutdown - Re-enter suspended well Alter casing Time extension - Change approved program _~ Plugging -- Stimulate . Pull tubing -- Amend order - Perforate ~ Other 5. Datum elevation (DF or KB) 2. Name of Operator ARCO Alaska, Inc 3. Address PO Box 100360, Anchorage: AK 99510 4. Location of well at surface 32' FSL. 112' FEL. Sec. 19 T12N R9E UM At top of productive interval ' ' ' la22' FSL, 3506' FEL, Sec.30, T12N, R9E, UN RKB 93 6. Unit or Property name KuDaruk River Unit 7. Well number 3F-11 ]"r;'. 4~, 0_,-,, 8. Permit number Permit ¢~85-272 feet At effective depth 1210' FSL, 3680' At total depth 1077' FSL: 3786' 11. Present well condition summary Total depth: measured 8600' ND true vertical 61~-9' TVD FEL, Sec.30, T12N, R9E, UH FEL, Sec.30. T12N, R9E; UP feet feet 9. APl number 5O-- 029-21482 10. Pool Kuparuk River Oil Pnnl Plugs (measured)None Effective depth: measured 8365' ND feet true vertical feet 5986' TVD Casing Structural Conductor Surface XXXJ4)4ff~te Production xxx~kr~xxxx Perforation depth: Junk (measured) None Length Size Cemented Measured depth 115' MD & 3843' MD 80' 3808' 16" 260 SX ASII 9-5/8" t020 SX PF E 445 SX PFC 8419' 7" 250 SX Class G 8454' MD 6048' TVD & 175 SX PFC 8167'-8225' MD, 7989'-8082' MD measured ~ue Vertical depth 115' TVD 3024' TVD true vertical 5849'-5890' TVD, 5725'-5791' TVD Tubing (size. grade and measured depth) '" 9 3# fa 8088' MD ' Packers and SSSV (type and measured depth) Pkrs fa 7922' ~; 80~.~' (ntis "RPM" _~ Otis "WD") SS~V @ !820' (Camco TDrlD_I/~_q/1M)~_ 12.Attachments Description summary of proposal Z, [~etail~(~ operations program __' "~OP"~k~'t'~'h' Adding perforations te¢ new interval _ 13. Estimated date for commencing operation April 20, 1988 14. If proposal was verbally approved /¢' ~/Oz/ ~ ?~'//Date approved Name of approver 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~/ ~. , ~'-" ' '~.4,~ C: Title Sr. Operations Engineer Commission Use Only ,'/ 7; -? Date 4 / 14 / 88 Conditions of approval Notify commission so representative may witness _- Plug integrity - BOP Test -- Location clearance Approved Copy Returned Commissioner Approved by ORIGINAL SIGNED BY LONNIE C. SMITH Form 10-403 Rev 12-1-85 IAppr°va'N°' ~_ ~<~~- by order of the commission Date ~ - ~:~ ~ /-~. . Submit in triplicate Kuparuk Well 3F-11 Application for Sundry Approval April 18, 1988 . The estimated BHP is 2591 psig @ -6200'SS based on data taken 10/87. 2. No workover fluids will be required for perforating. . There will be a lubricator with a 5000 psig rate BOP used during the perforating work (see the attached diagram). 3 1. ,5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. ,5000 PSi WlRELINE RAMS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4. 1/6" FLOW TUBE PACK-OFF W I REL I NE BOP EQU I PM£NT Kuparuk Well 3F-Il Through Tubing Perforating Procedure 1. MIRU slickline unit and cleanup tanks. Pressure test equipment. 2. RIH and pull AVA commingling sleeve and set AVA isolation sleeve to isolate C Sands. 3. RDMO slickline unit. 4. Flow well for 48 hours and obtain an A Sand only well test. 5. MIRU E-line unit and pressure test equipment. 6. RIH with gun assembly and tie in depths (with the well shut in) using the following Schlumberger logs: DIL/SFL dated 12/5/85 CET dated 12/19/85 7. Drop back down to retie in and perforate the following interval at 4 SPF with the well shut in. 8121'MD - 8142'MD (RKB) 8. Leave well shut in following perforating to insure that the perforation debris falls into the rathole and does not flow up hole. After a few minutes have passed, make a collar log pass across the perforated interval to verify the presence of the perforations. 9. POOH/RDMO E-line unit. ARCO Alaska, Inc. Post Office Bc ~360 Anchorage. Ala~,-,a 99510-0360 Telephone 907 276 1215 October 31, 1986 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk AT0-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal 45806 Transmitted herewith are the folloWing items. Please acknowledge receipt and return one signed copy of this transmittal. Final Prints: CET/CEL 10-12-85 Run ~2 8600 CET/CEL 10-13-85 Run ~3 8550 CET/CEL 10-02-85 Run ~1 6795 CET/CEL 10-01-85 Run ~1 7550 CET/CEL 10-01-85 Run #1 6680 CET/CEL 10-01-85 Run ~1 6080 CET/CEL 12-30-85 Run ~2 6400 CET/CEL 12-30-85 Run ~2 7300 CET/CEL 10-!5-85 Run ~1 5887 CET/CEL 10-15-85 Run ~1 3995 CET/CEL 10-!7-85 Run #1 7000 . 51 5166 CET/CEL 12-19-85 Run = CET/CEL 12-19-85 Run #1 6950 CET/CEL 10-05-85 Run ~1 6860 CET/CEL 10-19-85 Run 51 7000 CET/CEL 12-18-85 Receipt Acknowledged: - 9120 - 8894 - 7763 - 9467 - 8570 - 8256 - 8038 - 9030 - 7730 - 6753 - 8488 - 6483 - 8322 - 8410 - 8487 Run ~1 36 - 6678 ,/"x~ ~A!aska Oil & Gas Co:re. Oommi,s,sion. , K Drillino Vault(1 film) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO,,,MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL~ GAS [] SUSPENDED ~ ABANDONED ~ SERVICE ~ 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-272 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21482 9. Unitor Lease Name Kuparuk River Unit 4. Location of well at surface 32' FSL, 112' FEL, Sec.19, T12N, PgE, UN At Top Producing Interval 1422' FSL, 3506' FEL, Sec.30, T12N, R9E, UM At Total Depth 1077' FSL, 3786' FEL, Sec.30, T12N, R9E, UN 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 93' RKB ADL 25643 ALK 2574 12. Date Spudded 113. Date T.D. Reached 14. Date Comp., Susp. or Aband. 11/29/85 I 12/04/85 12/06/85' 17. Total Depth (MD+TVD) 18.PlugBackDepth(MD+TVD) 19. Directional Survey 8600 'MD,6149 'TVD 8365 'HD,5986 'TVD YE~ NO ~ 10. Well Number 3F-11 11. Field and Pool Kuparuk River Fi eld Kuparuk River 0i1 Pool 15. Water Depth, if offshore 116. No. of Completions N/A feet MSL I 1 20. Depth where SSSV set I 21. Thickness of Permafrost 1820 feet MD I 1500' (Approx) 22. Type Electric or Other Logs Run DIL/SFL/SP/GR, FDC, CNL, Cal, GR/CCL/CET, GCT 23. CASING SIZE 9-5/8" WT. PER FT. b2.b~ 36.0# GRADE H-~O J-55 TOP ' Surf Surf 7" 26.0# J-55 Surf 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) 8167' - 8225' w/4 spf, 90° phasing CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD AMOUNT BOTTOM HOLE SIZE CEMENTING RECORD PULLED 115' 24" 268 sx AS II 3843' 12-1/4" 1020 sx PF "E" & 445 sx PF "C" Performed top job w/60 ~x PF "C" ! 8454' 8-1/2" 250 sx Class G & 175 sx/PF "C" / 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 8088' 7922' & 8065' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD)/AMOUNT& KIND OF MATERIAL USED See addendum attacl~ed to Well Completion Report, dated 3/7/86. / 7989' - 8083' w/12 spf, 120° phasing 27N/A PRODUCTION TEST Date First Production Date of Test Hours Tested Casing Pressure Flow Tubing Press. 28. I Method of Operation (Flowing, gas lift, etc.) PRODUCTION FOR IOIL-BBL GAS-MCF TEST PERIOD I~ CALCULATED I~ OIL-BBL GAS-MCF 24-HOUR RATE -'~ COP E DATA WATER-BBL WATER-BBL CHOKE SIZE ] GAS-OIL RATIO OIL GRAVITY-AP (corr) Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None Form 10~07 * NOTE: Tubing was run & the well perforated 1/21/86. WC1/053 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. GEOLOGIC MARKERS NAME Top Kuparuk C Base Kuparuk C Top Kuparuk A Base Kuparuk A MEAS. DEPTH 7982' 8064' 8087' 8276' TRUE VERT. DEPTH 5720' 5777' 5793' 5924' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS None 32 1 hereby certify that the foregoing is true and correct to the best of my knowledge ~/~ ~_~L~ Associate Engineer S~gneo Title INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on alt 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 10407 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well REV I SED __ -- GAS __ SUSPENDED __ O L__ --XX ABANDONED Z SERVICE Z 2 Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-272 3. Address 8 APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21482 4. Location of well at surface : 32' FSL, 112' FEL, Sec.19, T12N, R9E, UN At Top Producing Interval 1422' FSL, 3506' FEL, Sec.30, T12N, R9E, UM At Total Depth 1077' FSL, 3786' FEL, Sec.30, T12N, RgE, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 93' RKB ADL 25643 ALK 2574 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 11/29/85 1 2/04/85 1 2/06/85? 17. Total Depth (MD-TVD) 18. Plug Back Depth (MD--FVD)I 19. Directional Survey 8600 'HD ,6149 'TVD 8365'HD,5986'TVD i YES EX NO---- [ 22. Tvpe Electric or Other Logs Run DIL/SFL/SP/GR, FDC, CNL, Cal, GR/CCL/CET, OCT 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 3F-11 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool 15. Water Depth, if offshore ! 16. No. of Compietions N/A feet MSL 1 20. Depth ~,hereSSSV set 21 Thickness o¢ Permaf-ost 1820 feet MD I 1500' (Approx) 23. CASING 16" SIZE 9-5/8" WT. PER FT. GRADE 62.5# H-40 36.0# J-55 SETTING DEPTH MD TOP BOTTOM Surf Surf 7" 26.0# J-55 ! Surf CASING, LINER AND CEMENTING RECORD HOLE SIZE I CEMENTING RECORD AMOUNT PULLED 115' 24" ] Conductor report not yet received. 3843' 12-1/4'! 1020 sx PF "E" & 445 ~x PF "C" Performed top job w/60 sx PF "C" 8454' 8-1/2" i 250 sx Class G & 175 sx PF "C" i 24. Perforations open to Production (MD-TVD of Top and Bottom and interval, size and number) 8167' - 8225' w/4 spf, 90° phasing 7989' - 8083' w/12 spf, 120° phasing 25. TUBING RECORD SIZE DEPTH SET ~MD) PACKER SET ~.ID~ 3-1/2" ' 8088' 7922' & 8065' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. See addendum 3/7/86. ched to Well Completion Report dated 27. N/A PRODUCTION TEST Date Fi-st Production Date of Test Hours Tested Flow, Tubing Casing Pressure Press. 28. I Method of (Flowing, lift, etc.) Operation gas I PRODUCTION FOR OIL-BBL GAS-MCF TEST PERIOD I~ 'CALCULATED OIL-BBL GAS-MCF 24-HOUR RATE CORE DATA WATER-BBL CHOKE SIZE GAS-OIL I WATER-BBL iOIL GRAVITY-APl (corr) RATIO Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED APRO 1986 Oil & Gas C~ns. Oon~a~mn Form 10407 * NOTE: Tubing was run & the well perforated 1/21/86. DAM/WC94 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate~, 29. 30. NAME Top Kuparuk ¢ Base Kuparuk ¢ Top Kuparuk A Base Kuparuk A GEOLOGIC MARKERS MEAS. DEPTH 7982 ' 8064 ' 8087' 8276' TRUE VERT. DEPTH .. 5720' ~1 5777' 5793' 5924 ' FORMATION TESTS Include interval tested, pressure data, all fluids recove,ed an(] Gravity, GOR, and time of each phase N/A 31. LIST OF ATTACHMENTS None 32. I hereby certify that the foregoing ~s true and correct to the best of my know, ledge Associate Engineer S~gned ..... Tit~e iNSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and :og on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam ~njection, 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 19407 STATE OF ALASKA ALASKA u,- AND GAS CONSERVATION CO~,MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service OIL ..... --)(X GAS -- SUSPENDED -- ABANDONED -- SERVICE -- 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-272 3. Address 8. APl Number P. 0. BOX 100360, Anchorage, AK 99510 5O- 029-21482 ~ 4. Location of well at surface 32' FSL, 112' FEL, Sec.19, T12N, R9E, UPI At Top Producing Interval 1422' FSL, 1774' FWL, Sec.30, T12N, R9E, UN At Total Depth : 1077' FSL, 1494' FWL, Sec.30, T12N, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) 93 ' RKB I 6. Lease Designation and Serial No. ADL 25643 ALK 2574 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 3F~11 !1 Field and Pool Kuparuk River Fie~d Kuparuk River 0il Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore ! !6. N3. of Completions 11/29/85 1 2/04/85 . 1 2/06/85* I N/A feet MSL 1 17. Total Depth (MD~-TVD) 18. Plug Back Depth (ME)--FVD)'i 19. Directional Survey I 20. Depth where SSSV set 21 Thickness of Permafrost 8600 'MD ,6149 'TVD 8365 'MD ,5986 'TVD i YES X3( NO -- I 1820 feet MD 1500' (Approx) I -- -- 22. Type Electric or Other Logs Run DIL/SFL/SP/CR, FDC, CNL, Cal, GR/CCL/CET, GCT 23. CASING, LINER AND CEMENTING RECORD [ CASING SIZEfWT. PER FT. 16" 62.5// 9-5/8" 36.0# GRADE H-40 SETTING DEPTH MD TOP BOTTOM Surf J-55 i Surf HOLE SIZE CEMENTING RECORD AMOUNT PULLED 115' Conductor report not y~et received. 3843 ' 24" 1 2-1/4"! 24. Perforations open to Production (MD-TVD of Top and Bottom and interval, size and number) 1020 sx PF "E" & 445 s~X PF "C" Performed top job w/6~ sx PF "C" 7" 26.0# J-55,I Surf 8454' 8-1/2" ~, 250 sx Class G & 175 s~ PF "C" 25. TUBING RECORD w/4 spf, 90° phasing w/12 spf, 120° phasing 8167' - 8225' 7989' - 8083' SIZE PACKER SET I~.,1D~ 3-1/2" ! 8088' 7922' & 8065' DEPTH SET MD~ 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL I,MD)/ NT & KI AMOU ND OF MATERIAL USED ! See attached addlndum. 27. N/A PRODUCTION TEST Date First Production Date of Test Hours Tested Flow' Tubing Casing Pressure Press. 28. I Method of Operation (Flowing, gas lift, etc.) 1 PRODUCTION FOR OIL-BBL 1 GAS-MCF [ 24-HOUR RATE CORE DATA I WATER-BBL CHOKE SIZE I GAS-OIL RATIO WATER-BBL IL GRAVITY-APl (corr) i Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None Form 10-407 * NOTE: Tubing was run & the well perforated 1/21/86. DAM/WC80 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Sui)mi,'t in dup!i£ate 29. 30. NAME Top Kuparuk C Base Kuparuk ¢ Top Kuparuk A Base Kuparuk A GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH 7982' 8064" 8087' 8276' 5720' 5777' 5793' 5924' FORMATION TESTS Include interval tested, pressure da[a, all fluids recovere(J and gravity, GOR, and time of each phase N/A 31. LIST OF ATTACHMENTS Gyroscopic Survey (2 copies), Addendum (dated 2/27/86) 32. I hereby certify that the foregoing is tr~Je and correct tO the best of my knowledge 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 ~.muitipte completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement lng and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Wate~ In jection, Gas Injection, Shut-in, Other explain. Item 28: If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 12/20/85 3F-11 Rn GR/CCL/CET/gage ring f/8328'-6950'. FRACTURE STIMULATION SUMMARY Begin Frac Work At: 1420 hrs, 2/11/86. AFE: AK0499 Frac Kupurak "A" sand perforations 8167'-8225' in 6 stages per 2/10/86 procedure using gelled diesel Musol, 100 mesh & 20/40 mesh. Press'd ann to 1760 psi w/diesel. Tst lns to 7950 psi; OK. Pmp'd 40 bbls 5% Musol/diesel + 71 bbls diesel 12 hrs prior @ 3/4 BPM, 2500 psi. Stage 1: 20 bbls gelled diesel pad @ 8 BPM w/final press of 3360 psi. Stage 2: 12 bbls gelled diesel w/100 mesh @ 7 BPM w/final press of 3170 psi. Stage 3: 35 bbls gelled diesel @ 6.5 BPM w/final press of 3120 psi. Stage 4: 13 bbls gelled diesel w/20/40 mesh @ 11BPM w/final press of 3070 psi. Stage 5: 27 bbls gelled diesel with 20/40 mesh @ 14.5 BPM w/final press of 3200 psi. Stage 6: 71 bbls gelled diesel flush @ 19-20 BPM w/final pressure of 4210 psi. Pmp'd total of 500#, 100 mesh, 1 ppg + 1403# 20/40 mesh, 3 ppg, + 5988# 20/40, 8 ppg in formation leaving 492# 20/40 mesh sand. Job underflush by 2 bbls in 7" csg. Load to recover 291 bbls of diesel. Job complete @ 1438 hrs, 2/11/86. Drilling Sdperintendent D/ce ARCO Alaska, Inc. Post Office [ .~0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 19, 1986 Mr. C. V. Ch Commissioner State of Ala Alaska Oil & Commi ssion 3001 Porcupi Anchorage, A SUBJECT: We atterton ska Gas Conservation ne Drive K 99501 ll Completion Reports Dear Mr. Chatterton: Enclosed are the Well 2A-14 3F-11 Completion Reports for the following wells: The bottomhole locations, TVDs, and geologic markers will be submitted when the gyroscopic surveys are received. If you have any questions, please call me at 263-4944. Sincerely, ~. Gruber Associate Engineer JG/tw GRU13/L149 Enclosures ARCO Alaska. Inc ~s a Subs~char¥ O! AtlanlicRichfieldCornpany STATE OF ALASKA ALASKA OiL AND GAS CONSERVATION CO~wMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well OIL ~X GAS -- SUSPENDED -- ABANDONED -- SERVICE -- 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-272 3. Address I 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50 029-21482 Classification of Service Well ' 4. Location of well at surface 32' FSL, 112' FEL, Sec,19, T12N, R9E, UN At Top Producing Interval To be submitted when gyro is run. At Total Depth To be submitted when gyro is run. 5. Elevation in feet findicate KB, DF, etc.) 93 ' RKB 12. Date Spudded 11/29/85 17. Total Depth (blD+TVD) 8600 'MD J 6. Lease Designation and Serial No. ADL 25643 ALK 2574 13. Date T.D. Reached 1 2/04/85 18. Plug Back Depth (MD-TVD) 8365 'HD 22. Type Electric or Other Logs Run D IL/SFL/SP/GR, FDC, CNL, Cal, GR/CCL/CET 14. Date Comp., Susp. or Aband. 1 2/06/85* 19. Directional Survey YES ~ NO 9. Unit or Lease .Name Kuparuk River Unit i0. Well Number 3F-11 i11. Field and Pool i Kuparuk River Field i Kuparuk River Oil Pool 15. Water Depth, if offshore 116. No of Comp!et,ohS N/A feet MSL 1 20. Depth where SSSV set 21 Thickness of Permafrost 1820 feet MD 1500' (Approx) 23. CASING SIZE 16" WT. PER FT. 62.5// GRADE H-40 9-5/8" 36.0# J-55 I I I " Performed top job w/60. sx PF "C" 7" 26.0// J-55 Surf I 8454' 8-1/2" i 250 sx Class C & 175 sx PF "C" TUBING RECORD CASING, LINER AND CEMENTING RECORD SETTINGi DEPTH MD I !][ TOP I BOTTOM HOLE SIZE ! CEMENTING RECORD AMOUNT PULLED ~ . Surf 115' 24" Conductor report not yet received. Surf ! 3843' 12-1/4"! 1020 sx PF "E" & 445 s~ PF "C" 24. Perforations open to Production (MD-TVD of Top and Bottom and interval, size and number) 8167' - 8225' w/4 spf, 90° phasing 7989' - 8083' w/12 spf, 120~ phasing 25. SIZE DEPTH SET ~rvlD) PACKER SET {MD) 3-1/2" ., 8088' 7922' & 8065' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL IMD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date F rst Production Date of Test Hours Tested Flow Tubing Casing Pressure Press. 28. I Method of Operation (Flowing, gas lift, etc.) 1 PRODUCT.ON FOR O,L-BB. ~AS-MCF TEST PERIOD I~ CALCULATED OIL-BBL i GAS-MCF 24-HOUR RATE ~' CORE DATA IWATER-BBL CHOKE SIZE IGAS OIL RATIO , ! WATER-BBL !OIL GRAVITY-APl (corr) Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or v~ater. Submit core chips. None Form 10-407 Rev. 7-1-80 * NOTE: Tubing was run & the well perforated 1/21/86. DAM/WC29 CONTINUED ON REVERSE SIDE Suomi' in duollcate 29. N/A NAME GEOLOGIC MARKERS MEAS. DEPTH 3! LIST OF ATTACHMENTS Well History (completion details) TRUE VERT. DEPTH I 30 FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase N/A 32 I hereby certify that the foregoing is true and correct to The Des: .L? ~,-y kno~,iedge '~~ Associate Enoineer Signed ~' 7 - e ~ Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement. lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10407 ARCO Oil and Gas Company Daily Well History-Final Report Instructions: m'eoa,e amc su~mtt :~e "Final Report" on 9'e '.st Wednesday a~:e' a · 'Final Repo~" shou,C De su~m,t~ec also w~en oDe'at~ons a~e susce~ced 'or an racer- :e o' acc,ec~amle ~e~gt~ of ~mme C~ ~or~ove-s .he~ a~ off:c~a[ :est ,s not reoulre~ u~on como etlon 'e39~ comp:et on a~d .eDresen atlve :est ~a a ,n c cc~s z'o.:cec T~e "Final Report" form may De usec 'o' .eco-t ng the entire oce'at'cn ~ scaces IAccountmg cost center coce State Alaska Dist-,c: JCob'-:) or =ar s Alaska F~e~ Lease or Kuparuk River ADL 25643 Auth. or WC no Tit~e ArE AK0499 Completion North Slope Borough Nordic 1 API 50-029-21482 Operator A R Co. W J ARCO Alaska, Inc.56.24% Spudded or W C Degun Date Complete 1/20/86 Date and cemh Complete recora for each day repo~ea as of 8 00 Old TD 1/21/86 1/22/86 me~easeC r.g 1930 hrs. Iotai number of weJls ~act~ve or ,nact,ve) on this! pst center prior to pluggmg and 1 bandonment of this well our Prior status ~f a W.O 1800 hrs. 7" @ 8454' 8365' PBTD, Prep to rn 3½" Accept rig @ 1800 hrs, 1/20/86. ND tree, NU & tst BOPE. RU Schl, perf w/4" guns, 4 SPF, 90° phasing f/8167'-8225' & w/5" guns, 12 SPF, 120° phasing f/7989'-8083'. Make gage ring/JB rn to 8290'. RIH, set WD pkr @ 8049' WLM. Prep to rn 3½" compl. 7" @ 8454' 8365' PBTD, RR 6.8 ppg Diesel Rn 258 jts, 3½", 9.3#, J-55 EUE 8RD tbg w/SSSV @ 1820', RRH pkr @ 7922' WD pkr @ 8065', "D" Nipple @ 8080', TT @ 8088'. Space out & lnd tbg. Set pkr & tst tbg, ann & SSSV. Shear out sub. NU & tst tree to 5000 psi. Displ well to diesel. RR @ 1930 hrs, 1/21/86. New T~ Date 8365 ' PBTD Rotary 1/21/86 CJass~'~cat~ons lo:,. gas etc. Oil ProaL, c:ng method Flowing Ty3e com2~e:,c~ (s ~g,e cua,, etc: Single Officta~ -ese~o,' ~a~e,s~ Kuparuk Sands moten: al test sara We;; no. Date Rese,'voir Procuc ~g !':e'~al Cd or gas ""est t,'"'e°'cC..ct c~ C, on test Gas per cay Pump size. SPM X length Choke s~ze T p C.P Water % GCR Gray,fy A,~o*ae~e Effect,,,.e Cate corrected The aoove ~s correct Signature /~ sF~; fl~rro~ e~ruerCe~ ' a~'~nnu aa .~S ed igt, rc~ ne u.i i0°.n' Drilting. mages 86 and 87. Drilling Superintendent ARCO Alaska, Inc. Post O,:ice BuN ~00360 -"nc:ho~ge ~iaska 99510-0360 Teie~no~e ~07 276 1215 January 17, 1986 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 3F-11 Dear Mr. Chatterton' Enclosed is the Well Completion Report for 3F-11. The bottomhole location, TVDs, and geologic markers will be submitted when the gyroscopic survey is received and the well completed. you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU13/L!O Enclosure STATE OF ALASKA - ALASKA~. AND GAS CONSERVATION CC .~ISSION WELL COMPLETIOIM OR RECOMPLETIOI,,I REPORT Al,ID LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED i-~1X ABANDONED .'.'--1 SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-272 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21482 4. Location of well at surface 32' FSL, 112' FEL, Sec.19, T12N, PgE, UN At Top Producing Interval To be submitted when gyro is run. At Total Depth To be submitted when gyro is run. 5. Elevation in feet (indicate KB, DF, etc.) 93 ' RKB 6. Lease Designation and Serial No. ADL 25643 ALK 2574 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 3F-!1 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool 12. Date Spudded 113. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 11/29/85 I 1 2/04/85 1 2/06/85 N/A feet MSL N/A 17. Total Depth (MD+TVD),18. Plug Back Depth (MD+TVD)19. Directional Survey8600 'HD Ii 8365 'MD YES [] NO [~X I20' Depth where SSSV setN/A feet MD ] 21. Thickness of Permafrost1500, (Approx) 22. Type Electric or Other Logs Run DIL/SFL/SP/CR, FDC, CNL, Ca1, GR/CCL/CET/Cauge ring 23. CASING, LINER AND CEMENTING RECORD CASING SIZE WT. PER FT. GRADE HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 24" Conductor report not y,;t received. 9-5/8" 36.0# Jo55 12-1/4" 1020 sx PF "E" & 445 s: PF "C" Performed top job w/60 sx PF "C" 7" 26.0# J-55 8-1/2" 250 sx Class G & 175 s: PF "C" 25. TUBING RECORD SETTING DEPTH MD TOP BOTTOM Surf 115' Surf 3843 ' Surf 8454 ' 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) None SIZE DEPTH SET (MD) PACKER SET (MD) N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested Casing Pressure Flow Tubing Press. PRODUCTION FOR TEST PERIOD ~ CALCULATED 24-HOUR RATE OI L-BBL OIL-BBL GAS-MCF GAS-MCF WATER-BBL WATER-BBL ICHOKE SIZE GAS-OIL RATIO OIL GRAVITY-APl (corr) 28. COP E DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None Form 10-407 Rev. 7-1-80 TEMP3/WC54 CONTINUED ON REVERSE SIDE Submit in duplicate 29. N/A NAME GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS Well Hi story 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Associate Engineer 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. Itern 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 Well History - Initial Report- Dally 1114 I~lt thl "llitill ~ ~fl the .firl~ ~ Iftol' I well il sl~Jdded or wort<over operltiOnl ~,rl ltlrtld. ~ I~ to N:~ng should bi ~ MI th~ form giving inclusive dlt~l only. [X~rlGt I ~ir'ri,~ O~ ~O,-ough Alaek~ ~' North Slope Borough ~d [~ o~ Un~ Kupa~k ~ve= ~L 25643 ~. or W.O. no. Title ~ ~0499 Drill State Alaska Vell no. 3F-11 Doyon 9 AP1 50-029-21482 Operator [ARCO W.I. ARCO Alaska, Inc. S~.d~ o, W.O. ~g,. ID-,. ]Hou, [P,o, .t.,~., · W.O. Spudded 11/29/85 2300 hrs. Oa~e and deOth as of 8.-00 Lin. 11/3o/85 thru 12/02/85 12/03/85 12/04/85 12/o5/85 Complete record for each day reported 56.24% 9-5/8" @ 3843' 3860' (3745'), Tst BOPE Wt. 9.6+, PV 13, YP 12, PH 9.0, WL 14.8, Sol 9 Accept riS @ 2030 hfs, 11/29/85. 16" @ 115' NU diverter sys. Spud well @ 2300 brs, 11/29/85. Navi-Drl & surv 12¼" hole to 2011', rotary drl to 3860', short trip to 1278', C&C, TOM. RU & rn 97 Jts, 9-5/8", 36#, J-55 BTC csg w/F$ @ 3843', FC @ 3762'. Cmt w/1020 sx PF "E" & 445 sx PF "C". Did not circ, bump plug. ND diverter sys. Perform 60 sx of PF "C" for top job. NU & tst BOPE. 593', 4.7°, S64.25W, 593 TVD, 3.5 VS, 1.78, 3.4W 1040', 21.6', S40.25W, 1025 TVD, 106 VS, 698, 81W 1481', 30.4*, S41.25W, 1418 TVD, 307 VS, 2218, 212W 2127', 50.1e, S36.25W, 1892 TVD, 739 VS, 5518, 491W 3115', 48.8e, S41.25W, 2531TVD, 1491VS, 1135S, 967W 3815', 46.7°, S43.25W, 2999 TVD, 2012 VS, 1521S, 1316W 9-5/8" @ 3843' 6068', (2208'), Drlg Wt. 9.2, PV 9, YP 5, PH 9.0, WL 6.8, Sol 6 Tst BOPE. TIM, tst csg to 2000 psi. DO cmt & flt equip. Conduct formation tst to 12.7 ppg EMW. Navi-Drl & surv 8½" hole to 6068'. 4015', 49.0e, S43.25W, 3133 TVD, 2160 VS, 1629S, 1418W 4330', 49.6°, S43.25W, 3338 TVD, 2399 VS, 1803S, 1581W 4707', 50.2°, S42.25W, 3581TVD, 2687 VS, 2015S, 1777W 5086', 50.7°, S42.25W, 3822 TVD, 2979 VS, 2231S, 1974W 9-5/8" @ 3843' 7939', (1871'), Navi-Drl Wt. 9.4, PV 11, YP 7, PR 9.5, WL 2, Sol 8 Navi-Drl & surv 8½" hole to 7939'. 5524', 51.1°, S42.25W, 4099 TVD, 3319 VS, 24838, 2202W 6376', 49.4°, S41.25W, 4642 TVD, 3875 VS, 28718, 2641W 7094', 47.3°, S42.25W, 5120 TVD, 4511VS, 33698, 2889W 7692', 47.3°, S40.25W, 5522 TVD, 4954 VS, 3699S, 3295W 9-5/8" @ 3843' 8600', (661'), Cut DL Wt. 9.9, PV 14, YP 11, PR 9.5, WL 5.6, Sol 10 Navi-Drl & surv 8½" hole to 8600', short trip to 3843', C&C, POH. RU Schl, rn DIL/SFL/SP/GR f/8588'-3840', cont w/GR to 150'. Log FDC f/8563'-7750', CNL f/8548'-7750' & CAL f/8588'-6650'. RD Schl. RIH. 8097', 46.0°, S39.25W, 5800.5 TVD, 5248.4 VS, 3925.48, 3483.6W 8540', 46.5*, S39.25W, 6106.8 TVD, 5568.1VS, 4173.28, 3686.3W The above is correct For form preparation and dlstributi~, see Procedures Manual, Sectiofl 10, Drilling, Pages 86 and 87. Date I Title Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Rel~ort" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Relm3rt" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test [s not reguired upon completion, rePort completion and representative test data in blocks provided. The "Final RefN3rt" form may be used for reporting the entire operation if space ~s avaHaole, Spudded or W.O. begun 11/29/85 Spudded , t Accounting cost center code District ICounty or Parish State Alaska Alaska North Slope Borough Field [L ...... Unit IWell no. Kuparuk River ADL 25643 3F-11 Auth. or W.O. no. ~Title AFE AK0499 I Drill Doyon 9 API 50-029-21482 Operator I A.R.Co. W.I. ARCO Alaska, Inc. I 56.24% J Date 12/06/85 12/07/85 thru 12/09/85 Date and depth as of 8:00 a.m. 12/tt/85 Complete record for each day reported Iotal number of wells (active or inactwe) on th~s, ost center prior to plugging and / bandonment of this well our I Prior status if a W.O. 2300 hrs. 7" @ 8454' 8454', (0'), Prep to cmt Wt. 9.9+, PV 17, YP 11, PH 9.5, WL 6.0, Sol 11 Fin RIH to 7935', wsh & rm to 8511', CBU, 25 std short trip, C&C, POH, LD DP. Chg rams to 7", tst to 1500 psi. RU & rn 194 its, 7", 26#, J-55 BTC csg to 8454' w/FC @ 8365'. Prep to cmt. 7" @ 8454' 8600', 8365', RR 9.8 ppg Brine in 7" csg Cmt 7" w/250 sx Cl "G" w/.6% FDP-C344 & .25% HR-7. Displ w/brine, bump plug. CIP @ 0805 hrs, 12/6/85. ND BOPE, instl pack-off, NU lower tree & tst to 3000 psi. RR @ 1100 hrs, 12/6/85. Arctic packed well w/175 sx PF "C". Old TD New TD Released r,g Date 1100 hrs. C assifications (oil. gas, etc.) Oil Producing method Flowing Potential test data J PB De~th JKind of rig 12/6/85 I IType coml~letion (single. dual. etd ) Single Official reservoir name(s) Kuparuk Sands Rotary Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke s~ze T P. C.P. Water % GOR Grav,ty Allowable , Effective date corrected The above is correct For form preparation and distribution, see Procedures Manual. Section 10. Drilling. Pages 86 and 87 Drilling Superintendent S~IB.$ URFA CE DIRECTIONAL SURVEY r~UIDANCE [~ONTINUOUS ~OOL Company Well Name Field/Location ARCO ALASKA INCORPORATED WELL 3F-11 ~32' FSLI 112' FELl Si~ ~-~q. R9E~ KUPARUK~ NORTH SLOPEr AI~SKA Job Reference No. 71268 WEST Date 12-FEB-1986 Computed By; OGDEN SCT 2Iq:CTi]N~L SURVEY 'USTg~E2 LiSTIN] SJR¢(Y ]~TE: 25-3E'-~5 METH]]S O: C]qaJT~TI3~ I~TE~D_&TI]N: LINE&R ~RTIC&L ~CTI]'~: H2~iZ. ?ZST. ~ZI~JTM &ZIMJTH S]'JTq 3~ 3:-11 KJO~RJ( CO4PdT~TIO~ DATE: 12-FEB-R5 [NTE~PCL~TE] V~LJES FgR ~VE~ 100 FEET TRUF ~E~SURE] V:RTI'~L 0,03 0,30 -~3,00 100,03 lO0,O0 ?,00 200,33 200,00 137,00 3]0.33 339.33 207.30 ~39.33 COO,DO 301,00 530.00 ~.~9 405.99 500,~3 59~,32 505,82 ~00.33 7~7.25 70~.Z5 ~90.32 8~3.75 ~03.75 1300.J3 9~8,24 11~0,]] 1091,31 9~,01 1Z30,30 1171,25 107~,26 1330,39 1260,~ 1157,53 1~30.30 13~9.~3 1255.93 1530.30 1~37.37 13~,07 1500,09 1521,]2 I~2~,02 1720,03 1601,~3 1509,33 1930,30 1675,30 1583,30 1~]9,30 17~6,%9 155~,~) 2330,3] 1812,~5 171~,~5 2193,90 1877,38 178~,0~ 2200.00 1~1.12 1~4~.12 2333.]] 2005.Z0 1~12.20 2~30,32 ~05~,~9 1975.48 2590,03 2133,22 234].22 2530,32 2197,Z0 210~,20 2730.]] 2251,52 215a,52 2~00,33 2326,71 2233,71 2~00.93 2392,~5 22~.~5 3090.3] 2458.90 2355.00 3110.33 2523.70 3!]0.33 2590.03 2~?,03 3300.03 2657.33 Z55~.03 3~30.00 272~.D2 2531,02 3590.00 2790.B3 25}?.83 3530.33 2857,5) 276~,5~ 3700,00 2925,1~ ~32,1~ 3~00.33 2993.33 2903.32 39]0.00 3052.1) 295~.1~ C]JRSE VERTISaL 035L~$ ]EVI~TI~ AZimUTH SECTION SEVERITY DEG ~IN 9~$ MI~ FEET 953z103 0 0 N 0 3 = 0.00 3.00 0 3 S 75 43 ~ 0.14 ~.33 0 15 N 25 47 = -3 ~4 ~ 12 0 17 ~ 17 3 _- -3,65 3.13 0 1~ N 2~ 53 ~ -1,17 0.05 O 30 N 73 17 ~ -1,5'~ ~,7~ 5 !5 S 52 3~ W 3,12 3,55 ~ 34 S 53 3B ~ 1~.53 ;.0~ 13 10 S ~5 21 d 33.39 3.71 17 3 S ~3 35 ~ 3).35 %.77 20 31 S ~4 23 W 91.84 ~.02 23 34 S 3} 4~ N 12~.1~ 3,5~ 26 ~4 S ~O 2~ W 172,11 2,23 2~ ~ S 39 ~ N 217,08 0,7? 27 ~i S 3~ 3¢ N 251.94 3.01 31 3 5 ~O 4~ W 31~.95 3.6~ 34 ~6 S ~3 25 ~ 355.23 3.72 3~ ~7 S 60 35 ~ ~23.75 3.35 43 37 S ~2 2~ d 4~3.87 ~.53 46 35 S 39 33 d 562,05 ~,21 49 39 S 35 15 W 535.55 2.15 50 ~ S 35 51 ~ 712.31 9.3~ 50 16 S 35 11 W 739.35 69 38 S 35 1~ w ~55.78 3.3~ 50 12 S 35 31 W ')G2.07 3.62 50 23 S 37 9 ',4 1'31~.86 3.55 50 5 S 37 35 d 1395.49 3.32 ~) ~4 S 3~ 15 W 1171,90 0.93 ,8 55 S 3a 5~ d 1257.63 ~,75 ~.5 38 5 ~O la, 1322.92 49 O S ~O 40 ~ 1393.4~ ].17 48 30 S aO 63 d 1473.~1 0.95 4'~ 13 S ~3 5) W 15~.65 ~7 50 5 ~1 ~ ,N 1522.87 ,3.33 48 0 S 41 5 d 1697.12 0.13 4'~ 5 S %1 33 W 1771.52 3.53 47 52 S ~1 5~ .4 1~45.,~9 a7 16 S qZ 1~ ,v 1~1).67 3.55 ~0 ~4 S ~Z 25 w l)~l.~O 0.47 46 ~ S 42 3t A 1055.B5 1.7) 3~TE ]F SJR~EY: 23-OES-83 KELLY ~USHIN5 ELEV~TIJN: ENGINEER: T. WEST 1 ~T RE'T~NOUL~R COOR N]RTq/SO;JTq E&ST 0.30 q O. O.lv S O. 0.13 q O. O. 57 '~ O. 1.D~ N O. 1 · 54 '4 O. 0.50 S ~. 6.~7 S 1~. 19.25 S 28. 37.32 S ~7. 58,97 S 71, 87,17 S 95, 119,~8 S 1IV. 154.31 S 153. 183.~ 5 1~1. 225,~2 S 213, 257.~? S 2¢~, 312.)7 S 2,~7. 362.23 S 331. ~15.55 5 378. ~7~.$3 S 62~. 536.75 5 469. 598.88 S 51~. 550.78 S 55). 722.~3 S 605. 7~4.14 S 651. ~45.15 S 698. 905.5) S 7~5. )54.94 S 7~2, 1322,~7 3 8~0, 1389.21 S 889. 1137.35 S 938. 1193.~7 S 9~7. 1249.,~7 5 1035. 1305.8~ S 1085. 1~61.79 S 11)~. 1~17.2~ S 118~. I~Ti.~T S 12~3. 15Z$.2Z S 1282. 157~.53 S 1331. Olq~T~S H3~IZ, /R:ST 9157, ~ZIqJTH T F::T OEO O0 E O.DO O~ W 3.15 21 E 0.25 35 E 0.57 35 5 1.21 65 6 1.57 1~ W 4.17 33 W 15.~5 50 W 3~.~ 5~ ~ ~0.37 )0 W 92.9~ 31 W 12'9.90 09 W 172.51 15 w 217.41 6~ W 262.1~ 32 w 311.38 33 W 365.33 35 W ~90,~2 31 W 562.10 3~ W 536.55 19 W 712.~3 39 w 78).~7 l~ W 366.05 25 W 40 ~ lg19,~1 11 W 1D96.21 15 W 1172.75 47 ~ 126~.37 53 w 1323.91 6~ w 13'~}.gZ 85 W 107~.79 91 W 156'9.51 53 W 1523.~Z ~2 W 159~.35 ~ W 1772.~3 O~ w 13~6.75 51 W 78 w 19'93.55 79 N 2365,05 S 17 30 ~ q 59 12 ~ 31 52 ~ 25 51 q 23 1e 5 ~3 5 ,5~ ZO d S 55 3 ~ 5 52 11 ~ S 33 38 ~/ S ,~? 51 .4 S 45 57 ,4 .543 52 ,4 5 63 17 ~ 5 42 32 ~ S ~,2 27 d S ~+2 19 ~ ']~PUTfiT[]t DfiFE: 12-F;8-85 ~SE Z 62'"0 ~,La, SKfi, INC. 3=-11 KJ~aRJK N]~TH SLOPE,aL~S{fi INT:RPOL~T:D V4' JES FDR EVEN lOD ~EET 0= TRJE SJB-SEfi MEASURE3 VERTICAL VERTI'fiL ]EPTt DEPTt DEPTH 40D0.23 3129.35 3336.35 4130.~3 319~.~$ 3101.86 ~230.00 3260.31 3167.01 4300.3~ 3324.~7 3231.87 4~00.30 3389.~9 3295.49 4500.00 3~53.~0 3353.~0 ~530.3~ 3518.00 4700.~3 3582.32 348~.0Z 4~30.3~ 3645.~7 3552.87 4300.00 3703.51 3615.5~ 5330.~3 3773.15 5100.03 3836.~7 37~3.47 5200.00 3899.56 3805.56 5330.00 3952.13 386~.13 5~30.00 ~02~.22 3931.22 5500.00 ~0~5.~6 3993.46 5530.00 ~149.16 ~055.15 5700.30 4212.30 ~119.30 5~0,00 4275.~1 ~182.81 5~O0.OO 4339,52 ~Z4S.SZ 5030.93 ~O2.gq ~309.~4 51OO.O0 4456.76 ~373.76 5230.00 ~530.119 ~437.7') 5300.~D ~595.19 ~502.1~ 6¢00.99 ~659.37 ~566.97 6500.~0 4725.~5 4532.45 6SDO.~O ~731.29 ~59~.29 6800.00 ~923.~8 5~30.3~ ~991.10 ~39~.10 7030.00 5058. q. 6 q965.~6 7130.33 5125.33 5032.93 7230.33 5193,37 5133.37 7300.30 5259. :33 5165.93 7~30.00 5326.~0 5233.60 7530.30 5393.}4 5309.0~ 7530.09 5459. ~6 5365.95 7730.33 5527.32 3~3~.32 7~00,3~ 55~3.39 5502.99 7)30.33 5563. ~5 5373.65 C2J~SE V:RTIC&L OOG_EG ]EVi~TI3~ 4ZIMUTH SECTION SEVERITY lEG MIN OE~ M!q FEET OES/IOO 48 ~1 S ~2 33 ~ Z139.43 1.22 49 13 S 42 23 W 221~.97 49 ZT S q2 22 ~ Z290.83 ~.Z~ 49 39 S ~2 Z1 ~ 2355,94 ~9 52 S ~Z 25 ~ 2~43.24 3.33 50 2 S 42 1~ W 2519.81 0.16 50 4 S ~2 1S W Z595.48 3.27 50 16 S ~Z 15 W 2573.30 50 23 S ~Z 13 ~ ~750.25 0.29 50 Z7 S ~2 17 W 2~27,32 ~.21 50 35 S 62 13 ,~ 2904.50 3.15 50 q. 9 S 42 ~ ~ 2981.90 3.15 51 Z S t, 1 ,59 ,4 305::).4'9 0.3.3 51 28 S ~1 50 w 3137.49 3.43 51 37 $ ~.1 5~ ~ 3215.~9 ,').Z$ 51 ZO S e, 1 5~ W 3294.15 O.3Z 51 1 S ~Z S ,4 3372.05 9.2:3 50 ~2 S 62 12 W 34~9.50 3.13 50 2_4 S e, 2 5 ~ 3525,83 3.3~ 50 33 S ~2 Z W 3603.91 3.45 50 ~_~ S ~2 $ -4 3531.23 3.63 50 19 S ~Z 5 W 375~,21 0,41 50 Z S ~Z 1 '4 3335.02 3.25 ~'9 51 S ~1 51 W 3~11.51 3.2) 49 17 S 41 39 ~ 3987.70 3.45 68 53 S ~1 29 W ~053.28 0,29 a8 38 S ~1 27 J ;136,54 3.35 48 29 S ~1 1~ ~ ;213,47 ~3 ~ S ~1 i5 ~ ~ZB~.18 0.35 ~7 ~3 S ~1 ~ w ~352.32 D.25 47 36 S ~3 59 d ~35.21 3.13 ~7 32 S 41 1 W ;513.02 9.21 ~7 53 S ~1 23 ,4 ~333.85 1.7~ 66 Zl S 42 3 ~ ~55g.49 3.33 43 15 S 41 37 ~ ~733.19 D.4Z g3 9 S ~1 ~ ',4 ~$07.'75 3.5~ ~7 ~3 S ~3 33 ,4 ~.3~2.05 3.33 ~7 ZB S ~3 13 ~ ~355.95 3.33 ~7 7 S ~3 1Z w 3323.65 3.53 ~6 33 S 3~ 33 ',4 3102.~2 OaT: DF SJRV:Y: Z3-~:5-85 KELLY aUSqIN3 ELEVfiT[3~: gS.00 FT ENGINEER: T. WEST ME~SURE) D~TH R:'T4N3JLaR C]]R3Iq~TES 4]~IZ. 9E~RTY~E N3~TH/S3UT'~ E a ST/'d:- ST DIST. ~ZI~IUTH F:ET FEET =E~T i]E~ MIN 1534.03 S 1381.97 W 2140.07 S 4'3 13 1539.75 S 1433.03 W 2215,55 S 40 17 1745.71 S 1484.22 W 22':31.3~ S 40 ZZ lB01.gg S 1533.67 W 236~.~5 1353.32 ~ 1536.~5 1)1~.~1 S 1538.5~ W 2520.25 S 1~71.51 S 1692.15 W 2595.89 S 40 3c 2028.~7 S 17~1.~1 W 2573.5~ S 2335.41 S 17'~3.5~ 2199.57 S 1897.33 W 2~0~.32 S 43 46 W 2236.98 S 196~.25 W 2982.20 S 40 48 d Z31~.bO S 2001.21 W 3359,78 S ~3 50 W 2372.57 S 2053.30 W 3137,77 S 43 5Z W 2G31.35 S 2105.62 W 3216.15 S 43 53 ~ 2~$9.28 S 2157.91 W 3294,~0 S 40 55 W 2547.1~ S 2213.07 W 3372.29 S 63 56 ,4 2504.51 S 2262.13 W 3~4~.82 S 43 58 W 2561.83 S Z314.01 W 3527.04 S 41 O ~ 2719.10 S 2365.51 W 3504.11 S 41 1 ,4 2776.~8 S 2417.43 ,4 3581.~2 S 41 Z ~ 2333.51 S 246~.05 W 3758.39 S 41 4 ,4 2390,64 S 2520,50 W 3335,19 $ 41 5 W 2947,52 S 2571,6~ W 3~11,55 S 41 6 4 3304.35 S 2522.31 W 3~7.86 S 41 $ d 3060,~3 S 2672,31 w ~363,46 5 61 7 3117,30 S 2722,35 W 4138,70 S 41 7 I 3173,52 S 2771,90 W ~213,62 S 41 d , 3229.55 S 2821,21 w 62~9.3~ S 41 a ~ 32a5.~3 S 2810,05 W 4352.~8 S 41 ~ g 3341.13 S 291~.55 W ~35.37 S 41 8 ,4 3395.97 S 2967.00 W 4510.1~ 3 41 ~ ~ 3452.54 S 3015.49 d 4584.02 S 41 B ,4 3508.35 S 3065.3~ W 455~.$5 S 61 ~ w 3553.?~ S 3115.1~ ~ ~733.35 S ~1 9 ,4 3519.56 S 316~.5D W 4307. ~1 S 41 9 ,4 3575.90 5 3Z13.05 W 4~SZ.Z1 5 41 9 J 3732.15 5 3261.02 W 4~56.12 5 41 ~ N 379B.28 $ 330~.51 W 5029.64 ~ 41 7 ,4 3~44.07 5 3355.57 ,4 510g,$g ~ 41 7 ~ 3=-11 KJPARJK N];~TH SLgPE,AL&SKA COMPUTATI]N DATE: 12-FEB-B5 INT=~°SL~T53 V&U'JE$ F3R :VE~ lO0 ~EST O: TRUE SJB-SE~ VERTIJ~L VERTIDAL CSJRSE VERTICAL DgS,EG }EVI~TI]N ~ZIMJTi SECTION SEV~IT~ ]~G qlN ~E3 MI~ FEET DES/103 46 5 S 39 34 ~ 5114.65 0.77 ~6 0 S 39 23 W ~245.48 }.31 45 59 S 39 ~ ~ 531g.44 46 9 S 33 5~ N 5390.29 3.03 46 ? $ 3~ 5~ ~ 3462.34 O.O] ~5 9 S 35 5% ~ ~534.38 9.OO 46 9 S 3~ 3& d 3505.43 8000.00 5732.55 5539.55 BtDO.23 5802.98 57J~.08 8200.33 5~?1.~? 577~.47 8330.03 59~O.g2 5847.92 8590.00 5079.45 5985.45 85DO.OD 5148.72 5055.72 3~T~ 3F SJRqEY: 23-D~3-85 qELLY 3JSHIN3 ELEqATISN: ~NSI~EER: f. WFST }3.0~ FT MEASURE FEE 3?55. 4010. ~123. 6179. 6235. ] DEPTH 3Ju~q C SOUTH 5 f 51 S 34 14 S 34 ~3 S 34 88 S 35 O1 S 35 13 S 35 25 S 36 3]RDI~aTES ~ST/WSST FEET 01.8~ 47.W7 93.00 38.21 83.52 c8.32 ?&.13 ~]RIZ. DIST. 5174.58 5245.73 531~.71 33~0.5'~ 462. $7 553~.75 5503.,~3 AZIMUTH 3E3 S 41 5 N S 41 4 d S 41 3 d S 41 1 ~ S 43 59 ~ S 40 5~ '4 S 40 5 : ~R',3 &L~S(~, INC. 3=-11 KJOflRJ'C ',1] RTH CgMPJT&TI]~ D~TE: 12-FE~-.~$ PAgE DATE 3: SURVEY: 23-DE2-55 KELLY ~USqINS ELEVATIDN: ENGIqEED: T. WEST ~3.00 FT INT:qPGLAT:D VALJES FDR :VEN 1ODD FEET DF TRUE ~EASJRE] V:RTI'~L V:RTI'AL O.OO O.DO -93.00 2000.90 1512.85 1719.85 3)30.33 2~5~.00 !355.00 ~000.09 3129.35 3335.35 5~00.90 3773.16 368).16 6OO0.OO ~02.94 ~309.94 7330.39 5058.~6 ~65.~5 8330.03 57~Z.55 553~.55 C3JRS: V:RTI'AL 90S.EG 3EVZ~Tl]q AZIMUTH S~-CTION SEVERITY )ErG ~I~ DES ME~SUR ~3 ]EPT R:'TAN3,JLA~_ CS]R,]I~ATcS_ N3RTH/SOUTH EAST/W:ST 0.30 ~ 3.00 5~.97 S 71.'93 ~7~.53 S ~2~.3~ 1380.21 5 88~.$9 153~.03 S 1381.~7 21~9.57 S 1897.33 2776.~ S 2~17.~3 33~1.18 S 291~.55 3~9.51 S 3C01.'~ DIST. FE:T ]E~ARTURE AZIMUTH ]ES ~I~ 92.)9 S 53 38 N 535.55 S 41 47 ~ 139~.~2 S 39 28 ~ 2140.07 S ~ 13 ~ Z~04.~2 S 43 4~ 4 3S~I,~Z S 41 4~36.37 S 41 ~ ~ ~174.]] ~ 41 5 ~ 3:-11 KJPARJ< NgRTH SLDPE,fiL~SK& CDMPUT~TI]~ D~TE: 12-F:B-35 P & 3E ]~TE ]F SJRVEY: 23-g_=2-83 K:LLY 9JS4ING ELE~fiT[]N: =N,SIX~E:_R: T. WEST 5 93.0'2 FT INT:qmOL~TE] VfiLJES =OR =V:~ 100 FEET 3: TRUE SJE-S:~ ME~SUR~] V:RTI'&L VsRTI-&L ]EPTH ]:PTi DE~TH 0.00 0.00 -93.00 93.0~ ~3.00 3.00 l~3.DO 193.00 103.00 2~3.30 293.00 203.00 393.03 393.90 300.00 ~3.D1 ~93.30 409.00 593.15 5~3.30 503.30 5~3.8~ 593.33 509.00 7~5.$~ 7~3.00 703.00 ~9~.21 ~93.00 903.00 1005.07 993.00 903.90 1113.14 1093.00 1003.03 1224.~ 1193.00 llOO.OO 1336.19 1293.30 1ZO~.O0 1~9.~2 1393.00 1303.00 1555.0M 14~3.00 1~03.00 1589.~5 1593.00 1509.00 1323.Z~ 16~3.00 1603.00 1959.55 1793.30 173].00 2124.7B 1~93.~0 1503.00 2281.00 1993.00 1903.00 2~35.~Z 2093.00 ZOOO.O0 2593.~5 2193.00 2103.00 27~8.55 2293.00 220,].00 2~30.33 2393.00 2303.00 3353.33 2~93.00 2~03.00 3294.~5 2593.00 2503.00 3353.55 2693.00 2503.00 3533.25 2T~3.00 Z73].00 3552.~$ Z~3.00 2803.00 3799.~ 2993.00 2g03.00 3~5.37 3093.00 3000.00 4097.15 3193.D0 31O}.OO 4250.80 3293.00 3203.00 4535.$5 3393.00 330D.00 4551.07 3493.00 ~402.00 4717.19 3593.00 3503.00 4373.~7 3593.30 3503.00 5331.2~ 3793.00 3703.09 51~9.57 3893.00 3~0~.00 CDJRSE V:RTISfiL D33_'EG 3EVI~TI3~ fiZI~JTq 3ECTIDN SEV-RITT )EO ~I'~ 3~3 MI~ FEET 3:3/103 0 0 5 8 13 17 0 0 N O 3 = 0.00 9.03 0 5 S 5~ 31 ~_ 3.14 0.12 0 16 N 27 53 E -3.21 9.12 0 15 N 15 23 E -0.63 3.10 19 N 23 33 c -1.13 3.07 21 ~ 53 S ~ -1.60 Z.7~ 10 S 53 12 ~ 2.5~ 3.37 20 S 5~ 13 ,~ 13.73 ~.3~ 0 S 45 27 ~ 32.42 3.51 1 S ~;3 33 vi 5~.11 ~.Ta 20 39 S ~3 57 d ~3.59 ~.05 24 4 S 39 32 W 13~.51 3.73 26 38 S 63 2~ W 133.29 1.1~ Z5 33 S 39 23 W ~33.15 1.03 29 15 S ~J ~ ~ 2~3.33 3.~3 33 Z9 S ~3 ~3 W 3~5.12 ~.13 38 1~ S ~3 2~ ~ ~13.30 ~.91 4~ 32 S ~2 2~ W 507.03 3.91 ~8 5~ S 37 7 ~ 513.65 3.53 50 7 S 35 57 W 731.31 9.4~ 50 2 S 35 17 W 351.29 ~.37 50 22 S 35 41 W )70.28 ].57 50 6 S 37 35 ~ 1093.49 3.27 49 19 S 33 37 d 1208.81 1.13 49 39 S ~3 13 W 1323.55 0.83 48 55 S ~0 43 W 1439.66 2.22 4~ I1 S ~2 5~ d 1531.97 g7 ~7 S 41 ~ W 1652.67 O.l~ 49 5 S ~i 32 d 1773.~4 ~.5~ 47 32 S ~2 5 ~ 13~.55 3.67 46 ,4 S 42 25 h 19'92.39 0.4? 47 ~2 S 42 39 'd !0'94.65 2.13 ~ 12 S 41 2~ W 2212.81 49 3~ S ~2 15 ,~ 232~.~5 3.31 ~9 33 3 ~2 2~ ~ Z*47.41 3.3~ 50 3 S 42 13 ~ 2506.53 0.09 50 16 S ~Z 15 ,4 2535.51 30 2~ S 62 1~ ~ 1~07.25 ~.15 30 39 ~ ~ 3 ~ 292{.53 3.3~ 50 39 S ~2 3 W 3051.39 P.33 Sd3-SE& RZ-T&'4 N];~T-t/ FEE 3JL&R T 3.DO N 0.1~ S 0.10 Ni 0.5~, N 1.35 N 1.32 N 0.22 S 5.32 S 13.5? S 3,5. ~5 S 69.19 S 91.33 S 123.~7 S 166.71 S 206.~5 S !52. ~'5 S 308.3~ 3 37~.37 $ 756.10 S 552.17 S 3Rtl ST/ EET I~4TES NEST O.OO 0.05 0.23 0.3~ 0.59 3.58 3.55 7.,39 7.51 73.15 131.35 163.3'9 195.55 235.41 283.08 342.35 ~10.35 480.33 549.95 S 551.15 W 745.19 S 622.13 w 941.21 S 693.04 W ~34.55 S 753.1~ W 1]23.34 S 84~.93 W 1110.71 S 915.91 N 1195.38 S 990.08 W 1279.3~ S 1062.79 W 1353.50 S 1135.0~ W 1~45.D4 S 1210.D3 W 1525.72 S 1282.51 1504.03 S 135~.35 1585.16 S 1431.5~ 177~.27 S 1510.23 1351.39 S 15B~.77 1949.53 S 1670.05 2338.25 S 1750.70 2127.57 S 1~31.95 2217.~5 S 1913.33 2'308.3~ S 1'795.7~ H]RIZ. 0I~T. 0.00 0.15 0.22 3.54 1.17 1.57 3.38 1~.~6 33.52 50.13 DEP~RTJRE ~ZIMUTH S 26 7 ~ ~ 52 34 =_ ~ 32 37 - q 25 56 E ~ 26 2~ : S 56 5g W S 55 20 ~ S 52 11 ~ g4.7~ 3 53 33 ~ 135.23 S 47 32 N 1~3.74 S 45 33 d 233.43 S 4% 25 N 285.43 S 43 32 4 345.22 S 43 3 ~ ~1~.36 5 42 34 ~ 507.09 3 ~2 27 ~ 513.57 5 41 5~ ~ 731.85 3 ~1 1 ~ 851.50 1]91.20 1209.72 1324.5~ 1~39.55 1552.~3 1563.51 1774.~5 1~35.52 19'~3.15 2399.33 2213.~1 2329.~8 2~47.89 2567.05 25~6.39 2307.5'~ 2)2~.~5 3251.51 S 37 51 ~ S 3~ 33 ~ S 39 25 ~ S 3~ 24 ~ 3 39 30 ' S 3} 3a i S 3~ ~2 , S 39 47 ~ S 39 55 A 3 43 3 N S 40 10 ~ 3 43 17 ~ 3 43 29 4 $ 43 39 ~ S 43 43 ~ ~ 40 47 4 3 42 50 ~ 3=-Ii KJPARJK, N]~TH SL3:~E,~L~S~4 CO~PUT~TI3N 1Z-~--B-8$ D~T~ 3= SJR~E¥: Z3-DzC-t5 4ELLY BUSHIN3 ELEW~TIJN: EN:3I~EER: T. WEST $ 93.00 FT INTErPOLaTED V~LJES ;OR ~VEq lOO FEET TRJ[ SJ3-S]~ ME~SURE] VERTI:~L VERT[:~L ]EPTt DEPT~ 53Q9.$8 39g3.90 ]909.00 5510.~$ ~Og3.00 ~009.00 555'9.52 ~193.J0 ~103.00 5~26.g5 ~293.30 ~209.00 5~4.3B ~393.00 ~303.00 61~1.07 ~493.30 ~4O}.OO 62~6.50 $5~3.30 ~500.00 5~50.53 ~6~3.00 ~503.00 6532.5~ ~793.30 ~703.00 6153.53 ~8~3.30 ~803.00 6)32.83 ~993.00 $g00.00 7351.Z3 50)3.00 5009.00 719).~ 5193.00 73~9.75 52~3.00 520~.00 7~9.95 53~3.00 5303.00 75~9.13 5G93.30 5~0].00 77)6.9Z 55~3.30 5503.00 7~Z.3~ 55~3.00 550].00 8036.)Z 5793.00 ~703.00 3230.97 58~3.30 533).00 8375.1~ 5993.00 5~00.00 9519.55 50~3.00 5OO].O0 8500.03 514~.72 5055.72 C]JRSE ]EVlITI3q AZIMJTq lEG v~IN OE3 45 9 S 35 5~ 45 9 S 35 51 45 ~ S 33 5~ VERTICAL SECTION ~EET 3175.41 3302.32 3425.00 35~7.58 356g.17 378g.80 399~.92 ~,325.93 ~163.4B ~253.51 ~354.41 ~4T~.O1 ~583.4~+ ;595.55 ~307.71 ~91~.41 3027.20 5133.~+1 5237.0B 3343.65 3548.~7 5535.~3 933LEG SEVS~ITY 3.20 3.23 3.23 3.67 3.33 0.35 3.52 3.25 l.lZ 1.71 3.23 3.5G 3.43 0.51 0.57 3.3~ 3.7D O.OO 3.03 SU3-SEa RESTAN N]RTH/ 2~01. 2~95. 2387. 2577. 2767. 2357. 2945. 3332 · 311~. 3203. 3~_87. 3357. 3~,52. 3535. 3519. 3703. 3785. 3~67. 3~47. 632~. ~109. 6190. ~235. D~PTH %IJLAR CDJROI~ATES SOJTq E~ST/4EST T FEET HSRIZ. DIST. nEET 55 S 207g.25 35 S 2163.37 14 S 2265.219 25 S 2327.91 54 S 2409.35 03 S 2499.22 59 S 256~.91 ~5 S 25~1.75 75 S 2723.5~ 39 S 279~.33 aZI~UT~ 953 MIN D1 S 2871.~2 W 71 S 29t, 3.33 W 23 S 3015.22 W 72 S 3090.22 w 53 S 3164.47 W 5.5 S 3235.6~ W 56 S 3307.05 W 37 S 3375.~5 w ~6 S 3~41.50 W 21 S 3507.00 ~ 3176.53 S 49 53 W 3302.51 S 63 55 ~ 3625.23 S 49 57 N 3367.7'9 S ~1 0 4 3563.35 S 41 2 4 3739.~8 3 41 4 3909.38 S 41 ~ 4D25.3~ S al 7 4 ~140.5~ S ~1 7 ~ ~Z53.57 ~ 41 3 4 99 S 357Z.28 11 S 3537.53 25 S 367~.13 4364.57 4~7¢.17 4383.51 4595.33 ~07.87 5927.39 5133.53 5Z37.32 5340.93 5~4~.79 554~.35 5505.33 541 8 d 541 8 4 S 41 9 ~ S 41 '9 4 S 41 7 ~ 541 4 4 541 2 ~ 541 OW S ~3 57 ,~ " 55 4 S 4,, 3:-11 N]RTH SLJOE,~L~SK~k C]~mUT~TI]~ O~TE: DATE IF SJRVE¥: 23-3{C-83 q~LLY ~USHIqS ELECATI]N: ENSI~EER: T. WEST 7 g3.00 F:,T TOP TOP T3 M~KER qUP&RJK ' KUm~RUK C KUP~RJK ~ INTEqPOL~TS3 V~LJES :OR qE~SJ~] 9E~TH 7~2.0D tO~7.DO 8276.90 ~500.09 :HDSEN HDRIZDNS ]RIgIN: ~Z' =SL, K'~ SJB-SEA 5720.10 5777.05 57~3.05 592~.Z7 51~$.7Z 5527.19 558~.35 5700.05 53)1.Z? 5355.72 SJ2F& SEC 1 R~CTaNJJ N;]RTH/S 33~9.5 3~35.1 3g~7.~ ~353.4 4133.3 ~Z35.2 SE .DC& qT 9, F1ZN L~R 3UTq 3 S 3 3 S 3 1 S 3 3 S 3 $ S 3 TI]N , ~gE, UM ~]IN~T~ ~ST/4~ST 3~3.55 ~31.35 ~1.53 557.55 3:-11 N]]TH SLOPE,aL~SK~ qELLY BUSqI~3 ENGIIEER: T. WES1, ~3.00 :I' M~RKER 3RI3I~: 32' :SL, 112' =EL, SJRF SE~ T~NS RTH/ :1SE .OCaTI3N ~T J_Aq S]UTt E~ S1'/,45 ST TOP TOP 5~S£ ~BTD 1,0 KUP~RJK ' K~P~RUq C KJP~RUK ~ KUP~RU{ a 79~2.30 5729.10 5527.10 835~.90 5777.95 55~.05 ~0B7.90 579Z.95 5700.D5 8Z76.DO 592¢.27 5~31.27 8365.90 5935.94 5~9Z.~4 8530.00 ~148.72 5355.72 ~2 ~9. 35. ~7. 53. 93. 35. ~IN~L WELL LO-aTI]N ~T TD: rRJ_= SJE-S:a ~EaSJRE3 VERTICAL ~/:RTI-~L DEPTH D=OTH 9'~P TH F-F_T 353 8600.00 51~3.72 5353.72 5535.~3 5 ~9 55 ,~ SCHLUMBEROER O I RECT I ONAL SURVEY COMPANY ARCO ALASKA INC WELL 3F-11 FIELD KUPARUK COUNTRY USA RUN ONE DATE LOOOEO REFERENCE 0000712S8 WELL 3F-11 (~2, FSL, 112' FEL, S19, TI?N, R9E) HORIZONTAL PROJECTION W-B~L 3F- 11 _ (32' ESL, 112' FEL, S19, ? ', R9E) VERTICAL PROJECTION 41. PROOECTION ON VERTICAL PLANE 221. - 41. SCRLE0 IN VERTICI:~. 0EPTHS HORIZ SCI::ILE = 1/ I000 IN/FT Su§§ested form to be :inserted :in each "Active" well folder to check for t:imely compl:iance with our regulationS. · . OPE~TOR, ~ELL ~ ~D ~U Required Date Received Remarks Mud Log Core Chips cbre ' Description Inclination Survey -~~ .... ~ ~ ste~-~'est Log Run., L.FJ. 04 ARCO Alaska, Inc.'~[~' Post Office B~^ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 14, 1986 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr. Chatterton: Enclosed are the December monthly reports for the following wells: 1A-7 2H-6 3A-13 3F-12 3J-11 4-29 L2-29 1A-13 2H-7 3A-14 3F-13 3J-12 16-15 L3-5 1A-14 2H-8 3A-15 3F-14 4-23 16-19 L3-19 1H-4 2H-9 3A-16 3F-15 4-24 16-20 1H-8 2X-8 3F-11 3J-10 4-27 L2-21 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU13/L05 Enclosures RECEIVED JAN 1 4 1986 Oil & Gas Cons. ~urnmLss/orl ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany -- STATE OF ALASKA - ALASKA C,. _ AND GAS CONSERVATION CO~,.,vllSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well X~_ Workover operation Z 1. 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-272 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21482 4. Locat;on of Well 9. Unit or Lease Name atsur;ace 32' FSL, 112' FEL, Sec.19, T12N, R9E, UP.. Kuparuk River Unit 5. Elevation in feet (indicate KB, DF, etc.) 1 6. Lease Designation and Serial No. 93' RKB ADL 25643 ALK 2574 10. Well No. 3F-11 1 1. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of. December , 19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 2300 hfs, 11/29/85. Drld 12-1/4" hole to 3860'. Ran, cmtd, & tstd 9-5/8" csg. Drld 8-1/2" hole to 8600'TD (12/04/85). Ran logs. Ran, cmtd, & tstd 7" csg. PBTD = 8365' Secured well & RR ~ 1100 hfs, 12/06/85. 13. Casing or liner run and quantities of cement, results of pressure tests 16", 62.5#/ft, H-40, weld conductor set @ 115'. Conductor report not yet received. 9-5/8", 36.0#/ft, J-55, BTC csg w/shoe ~ 3843'. Cmtd w/lO20 sx PF "E" & 445 sx PF "C". Performed top job w/60 sx PF "C". 7", 26.0#/ft, J-55, BTC csg w/shoe ~ 8454'. Cmtd w/250 sx Class "G" & 175 sx PF "C". 14. Coring resume and brief description None 15. Logs run and depth where run DIL/SFL/SP/GR f/8588' - 3850' FDC f/8563' - 7750' CNL f/8548' - 7750' Cal f/8588' - 6650' GR f/8588' - 150' RECEIVED JAN 1 4 ].986 1 6. DST data, perforating data, shows of H2S, miscellaneous data None 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED TITLE Associate Engineer DATE )Z'2~ '~' NOTE- Repor(~/on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. F~m I n~nz~ TEMP3/MR06 Submit in duplicate ARCO Alaska, Inc. Post Office B. .o0360 Anchorage. Alaska 99510-0360 Tetept~one 907 276 1215 TO: ARCO ALASKA, INC, ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE12-19-85. TRANSMITTAL # 5473 Tre_nsmitted herewith are t. he following items. Please acknowledge receipt ~nd return one signed copy of this transmittal. Open Hole LIS Tape plus listing/ schl/ One copy of each lQ-4 /w 03-18-85 Run ,%1 4570.0-9471.0 re f# ' 7099 7 -£~kd ~ p~ed ~2H-9// 12-02-85 Run #1 1800.0-8113.0 ref# 71048 ~2H-10~/ 11-23-85 Run .%1 2856.0-7960.0 ref# 71002 '~2H-12 /- 11-07-85 Run #1 2743.0-6829.0 ref# 70947 ~2U-7:/ 03-19-85 Run #1 3594.5-8179.5 ref# ~2V-16/! 06-03-85 Run #1 2973.0-7168.0 ref# 70952-~~p ~3A-10]! 1!-09-85 Run #1 3179.0-7014.0 ref# 70960 ~3A-!lw, 11-16-85 Run #1 3208.0-7330.0 ref# 70989 3A-12;/ 11-23-85 Run = ~.1 3797.0-8006.0 ref# 71003 '~3A-13;/ 12-01-85 Eun #1 1800.0-7597.0 ref# 71047 ~3A-14'/ 12-09-85 Run #1 0144.5-7818.0 ref# 71073 ~-3C-9O 07-10-85 Rua3 #1 3920.0-8332.5 ref# 70996--~ 3F-8~! 11-09-85 Run #l&2 0115.0-7040.0 ref~ ?0994 ,,~3F-9/~ 11-17-85 Run #1 3410.0-7770.0 ref# 70990 3F-10;~ 11-27-85 Run #1 1800.0-6631.0 ref# 71037 3F-11w 12-05-85 Run ~,1 0148.0-8618.5 ref# 71061 3J-9,/ 11-24-85 Run #1&2 0~91.0-6789.0 ref# 71034 3J-10'~ 12-08-85 Run #1 0096.5-7348.5 ref# 71074 Receipt Acknowledced: 3 f--?/ 7?? z- ,5_ - /.4, o°` .3 J'- P c g a a - ,3 -o n - ?I- d 7 R? ~TATE OF ~S~* Date: M EMORAN OUM Statu of Alaska ALAS~--OIL A/~D GAS CONSERVATION CO~,~ISSION / i' C. V. ~~erton TO: Chairman THRU: Lonnie C. Smith Commi s s loner FROM' Edgar W. Sipple Petroleum Insp~ z~..~9r John F. Boyl%jf?' ¢-~ Pet. Engineer Assistant D~-rE: December 9, 1985 F.LE~O: D.EWS.58 TELEPHONE NO: SUBJECT: BOP Test ARCO KRU 3F- 11 Permit 85-272 December 1, 1985: Ed Sipple and I departed Rowan Rig 34, and trav- el6d to Doyon Rig 9, ARCO Kuparuk. December 2, 1985: The BOP test commenced at 5:45 A~-I and concluded at 6:50 A/[. There were no failures. We filled out the AOGCC BOP inspection report which is attached to this report. In summary, Ed Sipple and I witnessed the BOP test on ARCO Kuparuk, 3F-11, Doyon Rig 9. Attachment O&G · #4 5/84 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COM>IISSION B.O.P.E. Inspection Report Operator Well ~ Location: Sec /~ Drillin~ Contractor Location, General Well ',~ ~--' !/ Representative Permit # ~,~- 2_ Well Sign OZz 9 ~Casing Set @ 36 9'2 ft.~O Representative ~o ~ L~!~0 ! ACCUMULATOR SYSTEM General Housekeeping~_~__Rig ~ Reserve Pit ~ ~Iud Systems Visual Trip Tank Pit Gauge Flow Monitor ,BOPE Stack A~ ~r P_r event e~--~O ~ Pipe Rams Blind Rams Audio Test Pressure Choke Line Valves .C.R. Valve O · t,,..,'~~_ ~-~- mill Line Valves ~ jj Che~ ~ck Valvecz~ ~j ~~~ Test Results: Failures Full Charge Pressure ~~ Pressure After Closure /~-oo Pump incr. clos. pres. 200 psig Full Charge ~ressu_!re Attained: N . ~/~OOOl~lOo,. 2t~o,,~c-' Controls: Master Remote ~, psig .. Blinds switch cover ~ ~ Kelly and Floor Safety Valves Upper Kelly ~'~Test Pressure Lower Kelly ~/Test Pressure Ball Type O/i/Test Pressure Inside BOP est Pressure Choke Manifold ~- Test Pressure No. Valves /~ (~ No. flanges~ Adjustable Chokes Hvdrauicaliy operated choke ~ ~ Test Time j hrs. 0 ~' ~ .~.,,, Repair or Replacement of failed equipment to be made within--~-~ Commission office notified. ~ays and Inspector/ Remarks: Distribution orig. - AO&GCC cc - Operator cc - Supervisor ~-ovember 12, 1985 Mr. Jeffrey B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 3F-11 ARCO Alaska, Inc. Permit No. 85 27° Sur. Loc. 32'FSL, ll2'FEL, Sec.19, T12N, R9E, UM. Btmhole Loc. ll04'FSL, 1018'F%-~, Sec.30, T12N, R9E, Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface 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. VersL_. truly v~c~ur s, .,: I f ,,/ ...,,-~/.,--' ,x..,× · / C. V. Chatterton Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE CObR.~ISSION dlf Enclosure cc: Departme~t of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ARCO Alaska, Inc. Dost Office B~_ _)0360 ~r. ch.:,rage. Alaska 99510-0360 ?eiec-r~c.,-,e 907 276 1215 November 5, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 3F-11 Dear Mr. Chatterton: Enclosed are: An application for Permit to a $100 application fee Diagrams showing the proposed projections ° A proximity o Diagram and system o Diagram and of the wellbore plot description of description of 'We estimate spudding this any questions, please call Sincerely, J. B. Kewin Regional Drilling Engineer JBK/LWK/tw PD/L187 Enclosures Drill Kuparuk horizontal and the surface hole 3F-11, along with vertical I f you diverter the BOP equipment well on November 26, 1985. me at 263-4970. have STATE OF ALASKA ALASKA ~_-,b AND GAS CONSERVATION CO~MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. I DRILL ~X I lb. Type of well EXPLORATORY -- REDRILL DEVELOPMENT OIL -~X - I - DEEPEN ~ DEVELOPMENT GAS ~ 2. Name of operator ARCO Alaska, Inc. SERVICE ~ STRATIGR ,/~HIC SINGLE ZON~( MULTIPLE ZONE 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 32' FSL, 112' FEL, Sec.19, T12N, RgE, UH At top of proposed producing interval 1343' FSL, 1231' F~L, Sec.30, T12N, RgE, UN At total depth 1104' FSL, 1018' FWL, Sec.30, T12N, RgE, UM 5. Elevation in feet (indicate KB, DF etc.) RKB 93', PAD 56' 6. Lease designation and serial no. ADL 25643 ALK 2574 9. Unit or lease name Kuparuk River Unit 10. Well number 3F-11 11. Field and pool ! Kuparuk River Field 12. Bond information (see 20AAC25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 30 mi. NW of Deadhorse miles 32' ~ surface feet i3F-10well 24' ~ surface feet 17. Number of acres in lease I 18. Approximate spud date fe~t 2560 20. Anticipated pressures MAXIMUM HOLE ANGLE 50 o (see 20 AAC 25.035 (c) (2} 16. Proposed depth (MD & TVD) 8594' MD, 6066' TVD 19. If oeviated (see 20 AAC 25.050) KICK OFF POINT 500 feet. 21 11/26/85 psig@ 80OF Surface psig@ 5938 ft. TD (TV D) Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole j Casing Weight i Grade [ C°upling Length MD TOP TVD t MDBOTTOMTVDI t (includestagedata) 24" i 16" 62.5// i H-40 Weld 80' 35' J 35' 115!~ 115' ± 200 cf 12-1/4" 9-5/8" 36.0# ~-55/HF-El~W BTC 3792' 35' ,, i 35' 38271 3023' 1020 ~x PF "E" & ,j ~ [ ,' ', 445 sx PF"C" 8-1/2" 7" 26.0# -55/HF-E W BTC 8560' 34 I 34' 85944 6066' 300 sx Class "G" neat 22. Describe proposed program: ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 8594' ND (6066' 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 BOP stack will be installed on the 9-5/8" surface casing. The stack and related equipment will be tested to 3000 psig upon installation and weekly thereafter. Expected maximum surface pressure is 2663 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 3500 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 3F-11 will be 24' away from 3F-10 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 interruptions in the disposal process. (continued on attached sheet} 23. I hereby cert.ify that the foregoing is true and correct to the best of my knowledge The space t~elow for Commission use~ ¢ ~/' Reqional Drilling Engineer DATE ////~h-~. CONDITIONS OF APPROVAL Samples required Mud log required Directional Survey required / APl number ~YES ~iNO %YES ~NO ~YES '--NO ~ 50- C ~'~ - Permit number Approval da~e __ _ ~F'PROV ED BY (LWK) PD/PD~'~7 SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE November 12, 1985 by order of the Commission Form I0-401 Submit in triplicate PERMIT TO DRILL 3F-11 (cont'd) Upon completion of the disposal process, the 9-5/8" x 7" annulus will be sealed with a minimum of 200 sx cement followed by Arctic Pack. The well will be completed by the workover rig using 3-1/2" or 2-7/8" tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. ARCO ~ALASKA.- INC. - .... 4 ....... ? ..... ~ ....... PAD _3F, _ 14ELL NOG ~1 1 ~ ~ PROPOSED ! --/-~/-II __x,,. KUPARUK-FIELD,~-NORTH-SUOPE, - ALASKA ..... / _.,/k.- ",,. EASTMAN- I,/H I PSTOCK,. -- I NC .... ; - __Kd3P____T VD-5 00__TJ'~J:) =_50 IZ_DEP-- 0 ..... PER _ ..... D~I$2B T-19D-'1 $80--DEP-297'-' 3945 -~O~-uGNu 'SNDS--/TVD=ier3 TMD=2032 DEP=582 .................. ~. ............... m _3013[ - - .... TO?_~_SAK SNDS -- TVD=2483 THD=2981 DEP=1 309 ..... ;K'--12 TVD=2823 TI90=3514 DEP"1719 "--CSG-PT ___-' ~Z - __- -_~_-__-_¥-_- '/', - ~TVD=3023 Tt'10=3827 DEP=1960 --A-V ERAGE--AN GI--E 50 DEG 20 1'!3 - K-S TVD-4448 T,D-6060 DEP=3679 __ ''-T/ ZONE--C - TVD=$T13' TMD=80421 DEP=5205 ............ T/ -ZONE ;-A - T7¢D=-5~00 TI90=817'8 DEP=$309 ..... -RODO _ ' , .... !' ........ ...... :-?oOo:J ....... , - .:- .-:'-'i--- __ .... ....... I ........... I ............ [ ...... i ...... I _ ~_ _:_ -'~'_ o: ~_~: __ . ~- !ooo_'-2: ~-~ooo:~ - 3000_ _ 4000 V ER TtCAL- ~-T-iON T.*.RGET CNT-R: ;~ T-VO=5826-T4~D-~821-9 - DEP=534~ - - BASE KUP SNDS .~ _'TVD=Sg3ByTHD=8394'-DEP=5476 _ --TD --(LOGG ! NG -PT) --- TVD=6066--TMD=8594 DEP=5630 i I 5000 6000 _ ARCO -ALAS:KA,-- tNC. ::- i ' - ;/lA, ..... P AD-3F.Lii WELL-- N 0 _=-L--11 ~ i-.:-PROPOSED--_-:.' , /__2.-!]-'~__ -KUPARUK- F ! ELD-.-NOR TH.-~S LOPE,--ALaSKa:. F//~---~~. E,'~St:I'I--AN--&WH i P ~TO-CK ;~! NC-,, _4000 -- WES~--E-AST :3000_- .... _-20_00 . . i _5OO0 · ~ _f 500: I 200 . , r [ :1 O0 ~" ', I;^RCO !^LASKA,i INC· '~ ' I~RbP ' ' ' i PAD 13F,! ,t~ELU N,O, 9-10- 0 ' l il !Iii R' 'KUP;,~RU, K F~IELD,,' ' NORTH kOI ALASKA ~'-'~ ...... ,--~-' ~"-'l"? -~ ..... ~'~ ..... ,' ' ' . i ....... T' " t'EAS~MAN WHIPSTOCK. INC ' .. t I~OTE, IWELL PATHS EXTEND BE,~OND~HI S"~' ';IEW!' ' '10 WINDOW' ' l "' "' ...... ' '" ' ............. ~ ...... : ....... ~-.L~--~-~.~-~ ....... ~ : ': .' '.1...,..'-. ..... 1..;. ~.. ~...I._.;. ~ .... ~. ~ .',..' ~.~ :~. 1890 :...". ~....~ ./,-.~ ...... :~:: , ,, ,, , ,~ · ,, ,, ~ ',1 :~. I, ;,!l~' ', : ~'¢' '~t, '' .,:~ . ',f, ~.~ / ) .- , . . , ~ . ~., ,' ~ ~' ~'.,/ , ' ~, . I~ ri' ' '' .' ' ~ I'. ' ' ' -- '', : :'.i '' ' : ' . ' . : _l..I._:..,. ....... :'""~ .... ; ....... I' '~ .... . ~ ' '~ .......... f ........................ ' ..... ~ l'r~ ...... . ''- ''' ~ ' ( ,/ / ' ~ . t / "~'-~'-: ....... .-r'~")-~": ..... , ', "" i': ",'"~' = ..... ~ . , , ~ ~ ~ ', , ~ ' , , ~ · , , · -~-t'~ ~- ~'~ .... ~" ", I.': ~ ..... ~ ~ ' ,- ' ~ . I . . . ~: . .. '. " *"I'-r *'~'+- '"' "f"' ~ · ' ',~ , ~ ' ' . ''' ' ' ~ . I i ~ . ~ ' . , ~, . )""'~ '-?~T'~"!'-~ .... ,~ i1~°~ ~ I~I .... :',~""~ "~ ~ '~ , ~ I -{ ~ ~ ~ , ~ ~0 I OH~O0100 I I , ' ' i ' ........ i'~ i ........ . ' :~, ~ ~o0~ I >' So0 I:',, ~ oo: ~oo'~, , 2o0 , , ~ } , ~ , , w _ KUPARUK R VER UNIT 20" D VEJ TER SCHEMATIC DE S CR Z P T Z ON I. I 6' CCN::XJCTOR. 2. TANi,(O STARTER HE:AD. 3. TANKO SAVER SUB. 4. TANKO LO~R QUICK-C~CT ASSY. 5. TANI<O UPPER QU]CK-CONN~CT ASSY. 6. 20" 2000 PSI DRILLING SPOOL W/lO' OUTLETS. 7. I0' MCR BALL VALVES W/lO' / DIVERTER LINES, VALVES OPEN AUTOMATICALLY UPON CLOSURE OF ANNA_AR PREVENTER. 8. 20' 2000 PSI AhI'4ULAR PREVENTER. 6 MAINTENANCE & OPERAT}ON I. UP'ON INITIAL INSTALLATION. CLOSE PREVENTER AND VERIFY THAT VALVES HAVE OPENED PROPERLY. 2. CLOSE AhlNULAR PREVENTER Ah[) BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE AhINULAR PREVENTER IN THE EVENT THAT AN INF'LUX OF WELLBOI~ FLUIDS OR GAS IS DETECTED. IF NECESSARY, MAh/JALLY OVERRIDE AND CLOSE APPEOPR I ATE VALVE TO ACHIEVE DONNWINE) DIVERSION. DO NOT SHUT IN ~LL UNDER ANY CIRCUMSTANCES. 7 L_ 6 ACCLMJLATOR CAPACITY TEST I. O-ECX AhD F~LL ACO.MJLATCR RF. SERVO~R TO ~ LEVEL W~TH HYDRAULIC FLUID. 2. ASSLI;~ THAT A~TCR P~r_~_~_I~E IS _3C09__ PSI WITH REC~ C~ ~ REPORT, TIE A~~ LCI~R LIMIT IS 45 SE~ CLOSING TII~5 ~ 12DO PSI RE~AINING PRESSLRE. 5 4 2 13-5/8" BCP STACX Tg$'r 1. FILL BOm STAO< AhD C]-O<E MANIFCLD WITH ARCTIC DIF, SEL. 2_ 0450< TI-iA? ALL LOCK ~ SC~ IN ~ELU-EAD ARE FLLLY RETRACTED. SEAT TEST PLUG IN WE].LPEAD WITH ~ING JT ~ RtJN IN LOCXDC]~IN LII~ VALVES ~ TO BO: STA(:X. ALL OTI-ER 4. PI::~E~ UP TO ~ FOR I0 MIN. IN- 0:~ PRESSL~ TO~Q.J~T.}AI',D HOLD FOR I0 MIN. BLC'm'~ t:~E~ TO 0 I:~I. LI~E VALVES. CLOSE TCP PIPE ~ AAD HCR VALVES ON KILL AND 0-~ LI~ 6.TEST TO 250 PSI AAD~5OCD PSIh%S IN STEP 4. 7.CCt~TIhAJE TESTING WITH A 2._50 PS! LCIN AAD_ 5000 PSI HIGH. TEST AS IN STEP 4. CD N~T P~~ T~ ANY ~OT A FULL C~.OSING POSITIVE SEAL CHCKE. ON_Y 8. O:~EN TCP PIPE RA/~S AAD CLCEE BOT'FC~ PIPE RAMS. TEST BOTTOM PIPE RAMS TO 2.50 PSI AhD 3000 PSI. 9. OPEN BOTTC~ PIPE RAMS, BACX CUT RUNNING JT AND I0. CLOSE BLIhD RAMS AND TEST TO 250 PSI AND 3000 PSI. 'MANIFOLD Ahl] LI~ES ARE FULL CF hI3~ING FLUID. SET ALL VALVES IN CRILLING POSITION. I P_TEST STAh~IPE VALVES, K~_I Y, KELLY COCKS, DRILL PIPE SAFETY VALVE, AAD I~IDE ~ TO 250 PSl AND 3000 PSI. 13. RE~ TEST IhF~TION CIN BLOM3JT ;:~ TEST FO~4o SIGN, AJ~) SEND TO DRILLING SUPE]i~ISCR. ~ :-~ WEEKLY T~ FLt~CTICNALLY C~TE ~ DAII. Y. REV. 2 ARCO Alaska, Post Office~-. ~x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 21, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Bui'it Location Plat - 3F Pad Wel 1 s 1-16 · Dear Mr. Chatterton: Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, , Gruber Associate Engineer JG/tw GRU!l/L22 Enclosure If RECEIVED OCT 2 Alaska 0jj & Gas Cons. C0mmJssJ0n Anchorage ARCO A,~aska, Inc. is a Subsidiary of AtlanticRichfieldCompany I L ~ ~in': .~ ~ "~ 1111 NOTES I. COORDINATtr$ ARE A.$.P.,ZONI:' 4. 2.. SECTION LINE DISTANCES ARE TRUE. 3. HORIZONTAL AND VERTICAL POSITIONS ARE BASED ON IdONUIdENTS SF-tdlDDLE a, 3F-EAST PER L.H.n&Assoc. 4. 0.~. ELEVATION$ INTERPOLATED FROM S~C DWG. NO. AS Bt ' CONDUCTORS I-II IN SECTIO 1- Y=5, ~85,734.98 LAT=70°22 ' 20 X= 508,662 89 FNL, 162 2- Y=5,985,745 X= 508,638 78 FNL, 139 3- Y=5,985,754 X= 508,616 69 FNL, 116 4- Y=5,985,764 N Z9 .0858" .35 LONG=149°55'46.549'' FWL, 52 O.G., 56.1 PAD- .lO LAT=70°22'20.1856'' .99 LONG=lag°55'47.233'' FWL, 52 O.G., 56.3 PAD .79 LAT=7OO22 20.2812" .29 LONG=149°55 47.896" FWL, 52 O.G. 56.3 PAD .77 LAT=70°22 20.3796" X= 508,593.66 59 FNL, 93 FWL, 5- Y=5,985,774.87 X= 508,570.43 49 FNL, 70 FWL, 6- Y=5,985,784.84 X= 508,547.58 39 FNL, 48 FWL, 7- Y=5,985,794.93 X= 508,524.44 28 FNL, 24 FWL, 8- Y=5,985,804.81 X= 508,501.41 LONG=149°55 48.558" 52 O.G. 56.2 PAD LAT=70°22 20.4792" LONG=149°55 49.237 52 O.G. 56.2 PAD LAT=70°22 20.5776" LONG=149°55 49.906" 52 O.G. 56.1 PAD LAT=70°22 20.6771" LONG.149°55 50.582" 52 O.G.,55.9 PAD LAT=70°22 20.7744" LONG=149°55 51.256" 18 FNL, 1 FWL, 52 O.G.,55.9 PAD /~.Tv,~._ :_~ ~. co.ouc~o...-,. ,..~c.,~. ,. , 5,834.85' LAT=70°22'2[.OTb8'' X= 508,432.81 12 FSL, 67 FEL, 10- Y=5,985,844.70 X= 508,410.73 21' FSL, 89 FEL, 11- Y=5,985,855.14 X= 508,387.41 32 FSL, 112 FEL, 12- Y=5,985,865.19 X= 508,364.05 I HEREBY'CERTIFY THAT I AM I,~'OI~:RLY Illl}III~RID ANO LIC~SED TO P~CTICE LAND BVEYIN'IN 13- ~l .ITA~ OF A~~ ~AT ~ll ~T ~~~NT8 A SURVEY ~DE U~R MY DI~CT ~NV~ AND THAT CQND~TOH8 I ~ ~ A~IC~CT A8 ~ '~_ SEP~ER 10,1088 A~.C~T~ t ~U 1l CONDUCTORS I THRU8 LOCATED IN PROTRACTEDI SEC. 29, T. 12 N.,R.9 E., U. MER. i CONDUCTORS 9 THRU 16 LOCATED IN PROTRACTEDI SEC. 19, T. 12.-N., R.9 E., U. MER.! ~., l.* *re.sm LONG=149°55 53.26~" 51.20.G., 56.1 PAD LAT=70°22 21.1678" LONG=149°55 53.908" 51.20.G., 56.2 PAD LAT=70°22 21.2708" LONG=149°55 54.590" 51.20.G , 56.3 PAD LAT=70°22 21.3699" LONG=149°55 55.273" 42 FSL,136 FEL,51.1 O.G.56.2 PAD Y=5,985,874.97 LAT=70°22 21.4663" X= 508,341.36 LONG=149°55 55.937" 52 FSL, 158 FEL,51.10.G. 56.3 PAD Y=5,985,885.O8 LAT=70°22 2 .5660" X= 508,318.27 LONG=la9°55 56.6!2" TIllS_ hS.38 J-J~ ('"~ !~ I ~ ' 15- Y=5,q85,894.96 LAT=70°22 2 .6635" ~~0 I~~ ~[~Z~ ~X E IVED X: 508,295.72 LONG:lag°55 57.271" ~/ % I %1 ! % ~1~ ~ 72 FSL, 204 FEn, 51 O.G. 56.1 PAD =~'k ~] i -I ~ ~LS-~.:..~ 16-Y:5,985,904.95 LAT:70°22'21.7619'' -- ~l- w/~~ c ~ :~ I i~ DRILL Sl~ 3 F ~ /~ ~4 z~l~ ~ ~ 2~ ID'SI~ .~ CONDUCTOR AS-B~LT · ; -.. llill[ Dire: to.r ,,. 1985 J 8...: ,.T.S. , Dre~ed by: Sydney2 ~l- h. N~ 85-26 CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (1) Fee (2) Loc (4) Casg/~.~,~., ~J-~o~ (13 thru 21) (5) BOPE (22 thru 26) Company Lease & Well No. YES NO REMARKS 1. Is the permit fee attached ................................ .......... ~-~ 2. Is well to be located in a defined pool ............................. 3. Is well located proper distance from property line .................. /] 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8 Can permit be approved before ten-day wait · ...e......®®®®.....i®.®.®. 13. -14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. Does operator have a bond in force .................................. </~ Is a conservation order needed ...................................... ~_~. Is administrative approval needed ................................... ~ Is the lease number appropriate ..................................... ~ Is conductor string provided ........................................ /~ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons .... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....... ;;~ ~$~' ;;;;;~;~'~ii~~ ~ Are necessary diagrams of diverter ;;;i~;;~; Does BOPE have sufficient pressure rating - Test to ~6) psig .. 4~ Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. Additional requirements ............................................. Additional Remarks: o Geology: En gj~ eering: HWK .~-~ LCS ~ ~ WVA~MTM ~- HJH ~ JAL rev: 03/13/85 6.011 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. i:!:i'.i?::? ~' :'.i ~::.':. i .i i'..i:i~. :'i ?~i'~ii~.~.~~':'ii:: ~:i;;'? :~ '.i.?~.. ~:!.:i:. :i:.i '?:!'. i' ::.~. i' ?:... ,..,.'."..,.,',..,,,,.,','..,. !.. :.?~-~-`~--~-~.*`~.~`-:~*~`-~-~`~`,~?~`*.~-~`*`~%.~-~`-.`~.-~`~*~--~;`~*~`:~,~-~*~-~-~:~`~-~-:~?: ..... ?~?~?:~:~:"-. 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