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Home My WebLink About182-130MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, August 5, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Josh Hunt P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1G-01 KUPARUK RIV UNIT 1G-01 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/05/2025 1G-01 50-029-20805-00-00 182-130-0 W SPT 6136 1821300 3000 2450 2445 2444 2460 475 620 630 610 REQVAR P Josh Hunt 7/8/2025 2-year MIT-IA required by AIO 2B.035 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 1G-01 Inspection Date: Tubing OA Packer Depth 980 3280 3140 3100IA 45 Min 60 Min Rel Insp Num: Insp Num:mitJDH250709091939 BBL Pumped:3 BBL Returned:3 Tuesday, August 5, 2025 Page 1 of 1            Originated: Delivered to:2-Jan-25 Alaska Oil & Gas Conservation Commiss 02Jan25-NR ATTN: Meredith Guhl 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 1G-103 50-029-20824-01-00 219-110 Kuparuk River WL WFL FINAL FIELD 9-Dec-24 1G-01 50-029-20805-00-00 182-130 Kuparuk River WL IPROF FINAL FIELD 11-Dec-24 1F-08 50-029-20836-00-00 182-162 Kuparuk River WL RBP FINAL FIELD 15-Dec-24 1F-14 50-029-21022-00-00 183-146 Kuparuk River WL PPROF FINAL FIELD 17-Dec-24 1F-08 50-029-20836-00-00 182-162 Kuparuk River WL RBP FINAL FIELD 18-Dec-24 1L-05 50-029-21155-00-00 184-123 Kuparuk River WL IPROF FINAL FIELD 19-Dec-24 1Y-29 50-029-21852-00-00 188-091 Kuparuk River WL PPROF FINAL FIELD 20-Dec-24 2T-10 50-103-20064-00-00 186-096 Kuparuk River WL IPROF FINAL FIELD 21-Dec-24 2H-05 50-103-20043-00-00 185-168 Kuparuk River WL PPROF FINAL FIELD 22-Dec-24 1Q-12 50-029-21210-00-00 184-193 Kuparuk River WL LEE-IPROF FINAL FIELD 23-Dec-24 MT7-91 50-103-20881-00-00 224-020 Greater Mooses Tooth WL TTiX-IPROF FINAL FIELD 29-Dec-24 MT7-92 50-103-20872-00-00 223-114 Greater Mooses Tooth WL TTiX-PPROF FINAL FIELD 31-Dec-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 T39899 T39900 T39901 T39902 T39901 T39903 T39904 T39905 T39906 T39907T39908 T39909 1G-01 50-029-20805-00-00 182-130 Kuparuk River WL IPROF FINAL FIELD 11-Dec-24 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.01.03 08:13:20 -09'00' 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 1G-01 (PTD 182-130) Report of suspect IA pressure increase Update 11/6/24 Date:Wednesday, November 6, 2024 7:56:35 AM Attachments:1G-01 90 Day TIO Plot & Schematic.pdf From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Wednesday, November 6, 2024 7:19 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU 1G-01 (PTD 182-130) Report of suspect IA pressure increase Update 11/6/24 Chris, KRU 1G-01 (PTD 182-130) (AIO 2B.035) completed its second 30 day monitor today 11/6/24. The IA pressure was bled down 10/8/24 for the monitor period. During the monitor period the IA pressure stabilized and required no further bleeds. CPAI plans to return the well to “normal” status. Any future annular communication issue will be reported if and when it is observed. Attached is a 90 day TIO plot and wellbore schematic for reference. Please let me know if you disagree or have any questions with this plan. Thank you, Shelby Sumrall Well Integrity Specialist | ConocoPhillips Alaska O: (907) 265-6678 | M: (907) 301-9374 From: Well Integrity Specialist CPF1 & CPF3 Sent: Monday, October 7, 2024 12:30 PM To: Wallace, Chris D (DOA) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU 1G-01 (PTD 182-130) Report of suspect IA pressure increase Update 10/7/24 Chris, KRU 1G-01 (PTD 182-130) (AIO 2B.035) was bought on injection 9/7/24 and completed it’s 30 day monitor today 10/7/24. For the first 3 weeks of the monitor period the IA appeared stable but during the 4th week the IA pressure increased ~350 psi, which is believed to be a thermal response that coincides with a ~10 degree increase in injection temperature. CPAI plans to bleed the IA pressure and extend the monitor period for another 30 days. Any proper paperwork for continued injection or corrective action will be submitted once diagnostics and the 30-day monitor has been completed and a plan forward is determined. Attached is a 90 day TIO plot and wellbore schematic for reference. Please let me know if you disagree or have any questions with this plan. Thank you, Shelby Sumrall Well Integrity Specialist | ConocoPhillips Alaska O: (907) 265-6678 | M: (907) 301-9374 From: Well Integrity Specialist CPF1 & CPF3 Sent: Monday, August 5, 2024 11:21 AM To: Wallace, Chris D (DOA) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: RE: KRU 1G-01 (PTD 182-130) Report of suspect IA pressure increase Update 8/5/24 Chris, After reporting 1G-01 (PTD 182-130) (AIO 2B.035) last month the well passed pack off tests, a diagnostic MITIA to 3310 psi (see attached 10-426) and a diagnostic MITT to 3025 psi (see attached 10-426). CPAI plans to pull the tubing plug and bring the well back on injection for a 30-day monitor. Any proper paperwork for continued injection or corrective action will be submitted once diagnostics and the 30-day monitor has been completed and a plan forward is determined. Attached is a 90 day TIO plot and wellbore schematic for reference. Please let me know if you disagree or have any questions with this plan. Thank you, Shelby Sumrall Well Integrity Specialist | ConocoPhillips Alaska O: (907) 265-6678 | M: (907) 301-9374 From: Well Integrity Specialist CPF1 & CPF3 Sent: Tuesday, July 16, 2024 11:56 AM To: Wallace, Chris D (DOA) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU 1G-01 (PTD 182-130) Report of suspect IA pressure increase Chris, KRU 1G-01 (PTD 182-130) (AIO 2B.035) DHD performed an IA bleed today 7/16/24 that appears to be re-charging quickly. CPAI plans to have the well shut in as soon as possible and have DHD perform diagnostics including POT’s, MITIA and IA DDT. Any proper paperwork for continued injection or corrective action will be submitted once diagnostics have been completed and a plan forward is determined. Attached is a 90 day TIO plot and wellbore schematic for reference. Please let me know if you disagree or have any questions with this plan. Thank you, Shelby Sumrall Well Integrity Specialist | ConocoPhillips Alaska O: (907) 265-6678 | M: (907) 301-9374 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (EST. 44' of FILL) 7,318.0 1G-01 5/5/2017 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled RBP 1G-01 9/6/2024 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: WAIVERED WELL TxIA COMMUNICATION 8/26/2008 ninam Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 29.0 80.0 80.0 62.50 H-40 WELDED SURFACE 10 3/4 9.95 28.7 2,238.8 2,238.7 45.50 K-55 BTC PRODUCTION 7 6.28 26.7 7,956.9 6,992.0 26.00 K-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 23.8 Set Depth … 7,219.8 Set Depth … 6,408.7 String Max No… 3 1/2 Tubing Description TUBING 3.5x2.875 Wt (lb/ft) 9.30 Grade L-80 Top Connection BTC-MOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 23.8 23.8 0.05 HANGER 8.000 MCEVOY GEN IV HANGER 3.500 1,789.4 1,789.3 0.85 SAFETY VLV 5.938 CAMCO TRDP-1AE SAFETY VALVE 2.812 2,959.0 2,957.1 10.98 GAS LIFT 5.390 CAMCO KBUG 2.920 4,565.3 4,360.5 43.22 GAS LIFT 5.390 CAMCO KBUG 2.920 6,816.6 6,084.5 35.44 GAS LIFT 5.968 CAMCO MMG-2 2.920 6,867.0 6,125.5 35.49 PBR 5.625 CAMCO PBR 2.937 6,880.4 6,136.4 35.50 PACKER 5.938 CAMCO HRP-1-SP RETRIEVABLE PACKER 2.937 6,926.8 6,174.2 35.78 INJECTION 5.968 CAMCO MMG 2.920 6,970.9 6,209.9 36.20 BLAST JTS 3.500 STEEL BLAST JOINTS 2.992 7,062.2 6,283.1 37.02 BLAST JTS 3.500 STEEL BLAST JOINTS 2.992 7,153.6 6,355.9 37.20 NIPPLE 4.540 AVA PORTED NIPPLE (2.75" AVA BPI W/ 3-3/16" PORTS) 2.750 7,187.4 6,382.8 37.11 SEAL ASSY 4.000 BAKER GBH-22 LOCATOR SEAL ASSEMBLY 2.405 7,188.6 6,383.8 37.10 PACKER 6.156 BAKER D PERMANENT PACKER 3.250 7,207.4 6,398.8 37.08 NIPPLE 3.668 CAMCO D NIPPLE NO GO 2.250 7,219.0 6,408.1 37.10 SOS 3.750 BAKER SHEAR OUT SUB, ELMD TTL @ 7214' during IPROF on 05/02/2006 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 7,051.0 6,274.2 36.92 LEAK - C - Sand Leak in straddle at 7051.5', and determined the injection split to be 100% into C sands (60% at leak, 40% at AVA). 5/3/2006 0.000 7,138.0 6,343.5 37.24 LEAK - TUBING TUBING LEAK WAS OBSERVED AT 7058' 2/21/2012 0.000 7,153.6 6,355.9 37.20 SLEEVE-C 2.75" AVA BPI w/ 3, 3/16" ports 7/4/2014 7,158.0 6,359.4 37.19 LEAK - TUBING POSSIBLE LEAK IDENTIFIED AT 7138' 2/21/2012 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,970.0 7,019.0 6,209.1 6,248.6 C-4, C-3, 1G-01 8/30/1982 12.0 IPERF Geo Vann TCP; 120° Ph 7,063.0 7,104.0 6,283.8 6,316.4 C-1, 1G-01 8/30/1982 12.0 IPERF Geo Vann TCP; 120° Ph 7,297.0 7,301.0 6,470.2 6,473.4 A-5, 1G-01 8/30/1982 12.0 IPERF Geo Vann TCP; 120° Ph 7,311.0 7,329.0 6,481.4 6,495.7 A-4, 1G-01 8/30/1982 12.0 IPERF Geo Vann TCP; 120° Ph 7,346.0 7,362.0 6,509.3 6,522.1 A-3, 1G-01 8/2/1993 4.0 APERF 28 deg CCW 1G-01, 9/7/2024 7:44:49 AM Vertical schematic (actual) PRODUCTION; 26.7-7,956.9 FLOAT SHOE; 7,954.8-7,956.9 FLOAT COLLAR; 7,858.8- 7,860.3 APERF; 7,346.0-7,362.0 IPERF; 7,311.0-7,329.0 IPERF; 7,297.0-7,301.0 SOS; 7,219.0 NIPPLE; 7,207.4 PACKER; 7,188.6 SEAL ASSY; 7,187.4 LEAK - TUBING; 7,158.0 SLEEVE-C; 7,153.6 NIPPLE; 7,153.6 LEAK - TUBING; 7,138.0 IPERF; 7,063.0-7,104.0 LEAK - C - Sand; 7,051.0 IPERF; 6,970.0-7,019.0 INJECTION; 6,926.8 PACKER; 6,880.3 PBR; 6,867.0 GAS LIFT; 6,816.6 GAS LIFT; 4,565.3 GAS LIFT; 2,959.0 SURFACE; 28.7-2,238.8 FLOAT SHOE; 2,236.8-2,238.8 FLOAT COLLAR; 2,152.3- 2,153.8 SAFETY VLV; 1,789.4 CONDUCTOR; 29.0-80.0 HANGER; 28.7-33.2 HANGER; 26.7-31.3 HANGER; 23.8 KUP INJ KB-Grd (ft) 30.50 RR Date 8/30/1982 Other Elev… 1G-01 ... TD Act Btm (ftKB) 7,970.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292080500 Wellbore Status INJ Max Angle & MD Incl (°) 45.18 MD (ftKB) 4,700.00 WELLNAME WELLBORE1G-01 Annotation Last WO: End Date 8/2/1993 H2S (ppm) DateComment SSSV: TRDP 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 1G-01 (PTD 182-130) Report of suspect IA pressure increase Update 10/7/24 Date:Monday, October 7, 2024 2:27:33 PM Attachments:1G-01 90 Day TIO Plot & Schematic.pdf From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Monday, October 7, 2024 12:30 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU 1G-01 (PTD 182-130) Report of suspect IA pressure increase Update 10/7/24 Chris, KRU 1G-01 (PTD 182-130) (AIO 2B.035) was bought on injection 9/7/24 and completed it’s 30 day monitor today 10/7/24. For the first 3 weeks of the monitor period the IA appeared stable but during the 4th week the IA pressure increased ~350 psi, which is believed to be a thermal response that coincides with a ~10 degree increase in injection temperature. CPAI plans to bleed the IA pressure and extend the monitor period for another 30 days. Any proper paperwork for continued injection or corrective action will be submitted once diagnostics and the 30-day monitor has been completed and a plan forward is determined. Attached is a 90 day TIO plot and wellbore schematic for reference. Please let me know if you disagree or have any questions with this plan. Thank you, Shelby Sumrall Well Integrity Specialist | ConocoPhillips Alaska O: (907) 265-6678 | M: (907) 301-9374 From: Well Integrity Specialist CPF1 & CPF3 Sent: Monday, August 5, 2024 11:21 AM To: Wallace, Chris D (DOA) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: RE: KRU 1G-01 (PTD 182-130) Report of suspect IA pressure increase Update 8/5/24 Chris, After reporting 1G-01 (PTD 182-130) (AIO 2B.035) last month the well passed pack off tests, a diagnostic MITIA to 3310 psi (see attached 10-426) and a diagnostic MITT to 3025 psi (see attached 10-426). CPAI plans to pull the tubing plug and bring the well back on injection for a 30-day monitor. Any proper paperwork for continued injection or corrective action will be submitted once diagnostics and the 30-day monitor has been completed and a plan forward is determined. Attached is a 90 day TIO plot and wellbore schematic for reference. Please let me know if you disagree or have any questions with this plan. Thank you, Shelby Sumrall Well Integrity Specialist | ConocoPhillips Alaska O: (907) 265-6678 | M: (907) 301-9374 From: Well Integrity Specialist CPF1 & CPF3 Sent: Tuesday, July 16, 2024 11:56 AM To: Wallace, Chris D (DOA) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU 1G-01 (PTD 182-130) Report of suspect IA pressure increase Chris, KRU 1G-01 (PTD 182-130) (AIO 2B.035) DHD performed an IA bleed today 7/16/24 that appears to be re-charging quickly. CPAI plans to have the well shut in as soon as possible and have DHD perform diagnostics including POT’s, MITIA and IA DDT. Any proper paperwork for continued injection or corrective action will be submitted once diagnostics have been completed and a plan forward is determined. Attached is a 90 day TIO plot and wellbore schematic for reference. Please let me know if you disagree or have any questions with this plan. Thank you, Shelby Sumrall Well Integrity Specialist | ConocoPhillips Alaska O: (907) 265-6678 | M: (907) 301-9374 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (EST. 44' of FILL) 7,318.0 1G-01 5/5/2017 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled RBP 1G-01 9/6/2024 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: WAIVERED WELL TxIA COMMUNICATION 8/26/2008 ninam Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 29.0 80.0 80.0 62.50 H-40 WELDED SURFACE 10 3/4 9.95 28.7 2,238.8 2,238.7 45.50 K-55 BTC PRODUCTION 7 6.28 26.7 7,956.9 6,992.0 26.00 K-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 23.8 Set Depth … 7,219.8 Set Depth … 6,408.7 String Max No… 3 1/2 Tubing Description TUBING 3.5x2.875 Wt (lb/ft) 9.30 Grade L-80 Top Connection BTC-MOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 23.8 23.8 0.05 HANGER 8.000 MCEVOY GEN IV HANGER 3.500 1,789.4 1,789.3 0.85 SAFETY VLV 5.938 CAMCO TRDP-1AE SAFETY VALVE 2.812 2,959.0 2,957.1 10.98 GAS LIFT 5.390 CAMCO KBUG 2.920 4,565.3 4,360.5 43.22 GAS LIFT 5.390 CAMCO KBUG 2.920 6,816.6 6,084.5 35.44 GAS LIFT 5.968 CAMCO MMG-2 2.920 6,867.0 6,125.5 35.49 PBR 5.625 CAMCO PBR 2.937 6,880.4 6,136.4 35.50 PACKER 5.938 CAMCO HRP-1-SP RETRIEVABLE PACKER 2.937 6,926.8 6,174.2 35.78 INJECTION 5.968 CAMCO MMG 2.920 6,970.9 6,209.9 36.20 BLAST JTS 3.500 STEEL BLAST JOINTS 2.992 7,062.2 6,283.1 37.02 BLAST JTS 3.500 STEEL BLAST JOINTS 2.992 7,153.6 6,355.9 37.20 NIPPLE 4.540 AVA PORTED NIPPLE (2.75" AVA BPI W/ 3-3/16" PORTS) 2.750 7,187.4 6,382.8 37.11 SEAL ASSY 4.000 BAKER GBH-22 LOCATOR SEAL ASSEMBLY 2.405 7,188.6 6,383.8 37.10 PACKER 6.156 BAKER D PERMANENT PACKER 3.250 7,207.4 6,398.8 37.08 NIPPLE 3.668 CAMCO D NIPPLE NO GO 2.250 7,219.0 6,408.1 37.10 SOS 3.750 BAKER SHEAR OUT SUB, ELMD TTL @ 7214' during IPROF on 05/02/2006 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 7,051.0 6,274.2 36.92 LEAK - C - Sand Leak in straddle at 7051.5', and determined the injection split to be 100% into C sands (60% at leak, 40% at AVA). 5/3/2006 0.000 7,138.0 6,343.5 37.24 LEAK - TUBING TUBING LEAK WAS OBSERVED AT 7058' 2/21/2012 0.000 7,153.6 6,355.9 37.20 SLEEVE-C 2.75" AVA BPI w/ 3, 3/16" ports 7/4/2014 7,158.0 6,359.4 37.19 LEAK - TUBING POSSIBLE LEAK IDENTIFIED AT 7138' 2/21/2012 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,970.0 7,019.0 6,209.1 6,248.6 C-4, C-3, 1G-01 8/30/1982 12.0 IPERF Geo Vann TCP; 120° Ph 7,063.0 7,104.0 6,283.8 6,316.4 C-1, 1G-01 8/30/1982 12.0 IPERF Geo Vann TCP; 120° Ph 7,297.0 7,301.0 6,470.2 6,473.4 A-5, 1G-01 8/30/1982 12.0 IPERF Geo Vann TCP; 120° Ph 7,311.0 7,329.0 6,481.4 6,495.7 A-4, 1G-01 8/30/1982 12.0 IPERF Geo Vann TCP; 120° Ph 7,346.0 7,362.0 6,509.3 6,522.1 A-3, 1G-01 8/2/1993 4.0 APERF 28 deg CCW 1G-01, 9/7/2024 7:44:49 AM Vertical schematic (actual) PRODUCTION; 26.7-7,956.9 FLOAT SHOE; 7,954.8-7,956.9 FLOAT COLLAR; 7,858.8- 7,860.3 APERF; 7,346.0-7,362.0 IPERF; 7,311.0-7,329.0 IPERF; 7,297.0-7,301.0 SOS; 7,219.0 NIPPLE; 7,207.4 PACKER; 7,188.6 SEAL ASSY; 7,187.4 LEAK - TUBING; 7,158.0 SLEEVE-C; 7,153.6 NIPPLE; 7,153.6 LEAK - TUBING; 7,138.0 IPERF; 7,063.0-7,104.0 LEAK - C - Sand; 7,051.0 IPERF; 6,970.0-7,019.0 INJECTION; 6,926.8 PACKER; 6,880.3 PBR; 6,867.0 GAS LIFT; 6,816.6 GAS LIFT; 4,565.3 GAS LIFT; 2,959.0 SURFACE; 28.7-2,238.8 FLOAT SHOE; 2,236.8-2,238.8 FLOAT COLLAR; 2,152.3- 2,153.8 SAFETY VLV; 1,789.4 CONDUCTOR; 29.0-80.0 HANGER; 28.7-33.2 HANGER; 26.7-31.3 HANGER; 23.8 KUP INJ KB-Grd (ft) 30.50 RR Date 8/30/1982 Other Elev… 1G-01 ... TD Act Btm (ftKB) 7,970.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292080500 Wellbore Status INJ Max Angle & MD Incl (°) 45.18 MD (ftKB) 4,700.00 WELLNAME WELLBORE1G-01 Annotation Last WO: End Date 8/2/1993 H2S (ppm) DateComment SSSV: TRDP Originated: Delivered to:13-Aug-24 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd. Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET# 1 1A-26 50-029-22115-00 909422974 Kuparuk River Leak Detect Log Field- Final 18-Jul-24 0 1 2 1A-26 50-029-22115-00 909422974 Kuparuk River Multi Finger Caliper Field & Processed 18-Jul-24 0 1 3 1D-12 50-029-22948-00 909422973 Kuparuk River Leak Detect Log Field- Final 15-Jul-24 0 1 4 1D-12 50-029-22948-00 909422973 Kuparuk River Multi Finger Caliper Field & Processed 15-Jul-24 0 1 5 1D-101 50-029-22988-00 909422480 Kuparuk River Patch Setting Record Field- Final 9-Jul-24 0 1 6 1F-03A 50-029-20853-01 909423152 Kuparuk River Packer Setting Record Field- Final 20-Jul-24 0 1 7 1G-01 50-029-20805-00 909469740 Kuparuk River Multi Finger Caliper Field & Processed 31-Jul-24 0 1 8 1G-01 50-029-20805-00 909469740 Kuparuk River Packer Setting Record Field- Final 30-Jul-24 0 1 9 1G-07A 50-029-20872-01 909383029 Kuparuk River Leak Detect Log Field- Final 2-Jul-24 0 1 10 1G-07A 50-029-20872-01 909383029 Kuparuk River Multi Finger Caliper Field & Processed 11-Jul-24 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: T39431 T39431 T39432 T39432 T39433 T39434 T39435 T39435 T39436 T39436 190-166 199-084 200-183 196-096 182-130 218-051 8-14-2024 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.08.14 08:29:49 -08'00' 71G-01 50-029-20805-00 909469740 Kuparuk River Multi Finger Caliper Field & Processed 31-Jul-24 0 1 81G-01 50-029-20805-00 909469740 Kuparuk River Packer Setting Record Field- Final 30-Jul-24 0 1 182-130 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 1G-01 (PTD 182-130) Report of suspect IA pressure increase Update 8/5/24 Date:Monday, August 5, 2024 12:15:30 PM Attachments:1G-01 90 day TIO plot & schematic.pdf Diagnostic MITIA KRU 1G-01 7-18-24.xlsx Diagnostic MITT KRU 1G-01 7-31-24.xlsx From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Monday, August 5, 2024 11:21 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: RE: KRU 1G-01 (PTD 182-130) Report of suspect IA pressure increase Update 8/5/24 Chris, After reporting 1G-01 (PTD 182-130) (AIO 2B.035) last month the well passed pack off tests, a diagnostic MITIA to 3310 psi (see attached 10-426) and a diagnostic MITT to 3025 psi (see attached 10-426). CPAI plans to pull the tubing plug and bring the well back on injection for a 30-day monitor. Any proper paperwork for continued injection or corrective action will be submitted once diagnostics and the 30-day monitor has been completed and a plan forward is determined. Attached is a 90 day TIO plot and wellbore schematic for reference. Please let me know if you disagree or have any questions with this plan. Thank you, Shelby Sumrall Well Integrity Specialist | ConocoPhillips Alaska O: (907) 265-6678 | M: (907) 301-9374 From: Well Integrity Specialist CPF1 & CPF3 Sent: Tuesday, July 16, 2024 11:56 AM To: Wallace, Chris D (DOA) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU 1G-01 (PTD 182-130) Report of suspect IA pressure increase Chris, KRU 1G-01 (PTD 182-130) (AIO 2B.035) DHD performed an IA bleed today 7/16/24 that appears to be re-charging quickly. CPAI plans to have the well shut in as soon as possible and have DHD perform diagnostics including POT’s, MITIA and IA DDT. Any proper paperwork for continued injection or corrective action will be submitted once diagnostics have been completed and a plan forward is determined. Attached is a 90 day TIO plot and wellbore schematic for reference. Please let me know if you disagree or have any questions with this plan. Thank you, Shelby Sumrall Well Integrity Specialist | ConocoPhillips Alaska O: (907) 265-6678 | M: (907) 301-9374 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (EST. 44' of FILL) 7,318.0 1G-01 5/5/2017 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set RBP at 6905' RKB 1G-01 7/30/2024 rmoore22 Notes: General & Safety Annotation End Date Last Mod By NOTE: WAIVERED WELL TxIA COMMUNICATION 8/26/2008 ninam Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 29.0 80.0 80.0 62.50 H-40 WELDED SURFACE 10 3/4 9.95 28.7 2,238.8 2,238.7 45.50 K-55 BTC PRODUCTION 7 6.28 26.7 7,956.9 6,992.0 26.00 K-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 23.8 Set Depth … 7,219.8 Set Depth … 6,408.7 String Max No… 3 1/2 Tubing Description TUBING 3.5x2.875 Wt (lb/ft) 9.30 Grade L-80 Top Connection BTC-MOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 23.8 23.8 0.05 HANGER 8.000 MCEVOY GEN IV HANGER 3.500 1,789.4 1,789.3 0.85 SAFETY VLV 5.938 CAMCO TRDP-1AE SAFETY VALVE 2.812 2,959.0 2,957.1 10.98 GAS LIFT 5.390 CAMCO KBUG 2.920 4,565.3 4,360.5 43.22 GAS LIFT 5.390 CAMCO KBUG 2.920 6,816.6 6,084.5 35.44 GAS LIFT 5.968 CAMCO MMG-2 2.920 6,867.0 6,125.5 35.49 PBR 5.625 CAMCO PBR 2.937 6,880.4 6,136.4 35.50 PACKER 5.938 CAMCO HRP-1-SP RETRIEVABLE PACKER 2.937 6,926.8 6,174.2 35.78 INJECTION 5.968 CAMCO MMG 2.920 6,970.9 6,209.9 36.20 BLAST JTS 3.500 STEEL BLAST JOINTS 2.992 7,062.2 6,283.1 37.02 BLAST JTS 3.500 STEEL BLAST JOINTS 2.992 7,153.6 6,355.9 37.20 NIPPLE 4.540 AVA PORTED NIPPLE (2.75" AVA BPI W/ 3-3/16" PORTS) 2.750 7,187.4 6,382.8 37.11 SEAL ASSY 4.000 BAKER GBH-22 LOCATOR SEAL ASSEMBLY 2.405 7,188.6 6,383.8 37.10 PACKER 6.156 BAKER D PERMANENT PACKER 3.250 7,207.4 6,398.8 37.08 NIPPLE 3.668 CAMCO D NIPPLE NO GO 2.250 7,219.0 6,408.1 37.10 SOS 3.750 BAKER SHEAR OUT SUB, ELMD TTL @ 7214' during IPROF on 05/02/2006 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 6,905.0 6,156.5 35.57 RBP RBP ME at 6905' RKB. (OAL=5.18 ft) 7/30/2024 0.000 7,051.0 6,274.2 36.92 LEAK - C - Sand Leak in straddle at 7051.5', and determined the injection split to be 100% into C sands (60% at leak, 40% at AVA). 5/3/2006 0.000 7,138.0 6,343.5 37.24 LEAK - TUBING TUBING LEAK WAS OBSERVED AT 7058' 2/21/2012 0.000 7,153.6 6,355.9 37.20 SLEEVE-C 2.75" AVA BPI w/ 3, 3/16" ports 7/4/2014 7,158.0 6,359.4 37.19 LEAK - TUBING POSSIBLE LEAK IDENTIFIED AT 7138' 2/21/2012 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,970.0 7,019.0 6,209.1 6,248.6 C-4, C-3, 1G-01 8/30/1982 12.0 IPERF Geo Vann TCP; 120° Ph 7,063.0 7,104.0 6,283.8 6,316.4 C-1, 1G-01 8/30/1982 12.0 IPERF Geo Vann TCP; 120° Ph 7,297.0 7,301.0 6,470.2 6,473.4 A-5, 1G-01 8/30/1982 12.0 IPERF Geo Vann TCP; 120° Ph 7,311.0 7,329.0 6,481.4 6,495.7 A-4, 1G-01 8/30/1982 12.0 IPERF Geo Vann TCP; 120° Ph 7,346.0 7,362.0 6,509.3 6,522.1 A-3, 1G-01 8/2/1993 4.0 APERF 28 deg CCW 1G-01, 7/31/2024 8:29:44 AM Vertical schematic (actual) PRODUCTION; 26.7-7,956.9 APERF; 7,346.0-7,362.0 IPERF; 7,311.0-7,329.0 IPERF; 7,297.0-7,301.0 PACKER; 7,188.6 LEAK - TUBING; 7,158.0 SLEEVE-C; 7,153.6 LEAK - TUBING; 7,138.0 IPERF; 7,063.0-7,104.0 LEAK - C - Sand; 7,051.0 IPERF; 6,970.0-7,019.0 INJECTION; 6,926.8 RBP; 6,905.0 PACKER; 6,880.3 PBR; 6,867.0 GAS LIFT; 6,816.6 GAS LIFT; 4,565.3 GAS LIFT; 2,959.0 SURFACE; 28.7-2,238.8 SAFETY VLV; 1,789.4 CONDUCTOR; 29.0-80.0 KUP INJ KB-Grd (ft) 30.50 RR Date 8/30/1982 Other Elev… 1G-01 ... TD Act Btm (ftKB) 7,970.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292080500 Wellbore Status INJ Max Angle & MD Incl (°) 45.18 MD (ftKB) 4,700.00 WELLNAME WELLBORE1G-01 Annotation Last WO: End Date 8/2/1993 H2S (ppm) DateComment SSSV: TRDP Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 1821300 Type Inj N Tubing 1400 1400 1400 1400 Type Test P Packer TVD 6136 BBL Pump 2.9 IA 387 3310 3263 3244 Interval O Test psi 1534 BBL Return 2.9 OA 60 60 60 60 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 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 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 Notes:Diagnostic MITIA to 3310 psi. Notes: 1G-01 Notes: Notes: Notes: ConocoPhillips Alaska Inc, Kuparuk / KRU / 1G Pad Burton / Casey 07/18/24 Form 10-426 (Revised 01/2017)Diagnostic MITIA KRU 1G-01 7-18-24 Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 1821300 Type Inj N Tubing 1325 3025 2925 2900 Type Test P Packer TVD 6136 BBL Pump 0.6 IA 12 15 14 14 Interval O Test psi 1534 BBL Return OA 40 40 40 40 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 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 / 1G Pad Moore 07/31/24 Notes:Diagnostic MITT to 3025 psi. Notes: 1G-01 Notes: 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)Diagnostic MITT KRU 1G-01 7-31-24 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 1G-01 (PTD 182-130) Report of suspect IA pressure increase Date:Tuesday, July 16, 2024 1:05:55 PM Attachments:1G-01 90 day TIO plot & schematic.pdf From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Tuesday, July 16, 2024 11:56 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU 1G-01 (PTD 182-130) Report of suspect IA pressure increase Chris, KRU 1G-01 (PTD 182-130) (AIO 2B.035) DHD performed an IA bleed today 7/16/24 that appears to be re-charging quickly. CPAI plans to have the well shut in as soon as possible and have DHD perform diagnostics including POT’s, MITIA and IA DDT. Any proper paperwork for continued injection or corrective action will be submitted once diagnostics have been completed and a plan forward is determined. Attached is a 90 day TIO plot and wellbore schematic for reference. Please let me know if you disagree or have any questions with this plan. Thank you, Shelby Sumrall Well Integrity Specialist | ConocoPhillips Alaska O: (907) 265-6678 | M: (907) 301-9374 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (EST. 44' of FILL) 7,318.0 1G-01 5/5/2017 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled CA2 plug body 1G-01 6/27/2024 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: WAIVERED WELL TxIA COMMUNICATION 8/26/2008 ninam Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 29.0 80.0 80.0 62.50 H-40 WELDED SURFACE 10 3/4 9.95 28.7 2,238.8 2,238.7 45.50 K-55 BTC PRODUCTION 7 6.28 26.7 7,956.9 6,992.0 26.00 K-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 23.8 Set Depth … 7,219.8 Set Depth … 6,408.7 String Max No… 3 1/2 Tubing Description TUBING 3.5x2.875 Wt (lb/ft) 9.30 Grade L-80 Top Connection BTC-MOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 23.8 23.8 0.05 HANGER 8.000 MCEVOY GEN IV HANGER 3.500 1,789.4 1,789.3 0.85 SAFETY VLV 5.938 CAMCO TRDP-1AE SAFETY VALVE 2.812 2,959.0 2,957.1 10.98 GAS LIFT 5.390 CAMCO KBUG 2.920 4,565.3 4,360.5 43.22 GAS LIFT 5.390 CAMCO KBUG 2.920 6,816.6 6,084.5 35.44 GAS LIFT 5.968 CAMCO MMG-2 2.920 6,867.0 6,125.5 35.49 PBR 5.625 CAMCO PBR 2.937 6,880.4 6,136.4 35.50 PACKER 5.938 CAMCO HRP-1-SP RETRIEVABLE PACKER 2.937 6,926.8 6,174.2 35.78 INJECTION 5.968 CAMCO MMG 2.920 6,970.9 6,209.9 36.20 BLAST JTS 3.500 STEEL BLAST JOINTS 2.992 7,062.2 6,283.1 37.02 BLAST JTS 3.500 STEEL BLAST JOINTS 2.992 7,153.6 6,355.9 37.20 NIPPLE 4.540 AVA PORTED NIPPLE (2.75" AVA BPI W/ 3-3/16" PORTS) 2.750 7,187.4 6,382.8 37.11 SEAL ASSY 4.000 BAKER GBH-22 LOCATOR SEAL ASSEMBLY 2.405 7,188.6 6,383.8 37.10 PACKER 6.156 BAKER D PERMANENT PACKER 3.250 7,207.4 6,398.8 37.08 NIPPLE 3.668 CAMCO D NIPPLE NO GO 2.250 7,219.0 6,408.1 37.10 SOS 3.750 BAKER SHEAR OUT SUB, ELMD TTL @ 7214' during IPROF on 05/02/2006 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 7,051.0 6,274.2 36.92 LEAK - C - Sand Leak in straddle at 7051.5', and determined the injection split to be 100% into C sands (60% at leak, 40% at AVA). 5/3/2006 0.000 7,138.0 6,343.5 37.24 LEAK - TUBING TUBING LEAK WAS OBSERVED AT 7058' 2/21/2012 0.000 7,153.6 6,355.9 37.20 SLEEVE-C 2.75" AVA BPI w/ 3, 3/16" ports 7/4/2014 7,158.0 6,359.4 37.19 LEAK - TUBING POSSIBLE LEAK IDENTIFIED AT 7138' 2/21/2012 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,970.0 7,019.0 6,209.1 6,248.6 C-4, C-3, 1G-01 8/30/1982 12.0 IPERF Geo Vann TCP; 120° Ph 7,063.0 7,104.0 6,283.8 6,316.4 C-1, 1G-01 8/30/1982 12.0 IPERF Geo Vann TCP; 120° Ph 7,297.0 7,301.0 6,470.2 6,473.4 A-5, 1G-01 8/30/1982 12.0 IPERF Geo Vann TCP; 120° Ph 7,311.0 7,329.0 6,481.4 6,495.7 A-4, 1G-01 8/30/1982 12.0 IPERF Geo Vann TCP; 120° Ph 7,346.0 7,362.0 6,509.3 6,522.1 A-3, 1G-01 8/2/1993 4.0 APERF 28 deg CCW 1G-01, 6/28/2024 8:02:16 AM Vertical schematic (actual) PRODUCTION; 26.7-7,956.9 FLOAT SHOE; 7,954.8-7,956.9 FLOAT COLLAR; 7,858.8- 7,860.3 APERF; 7,346.0-7,362.0 IPERF; 7,311.0-7,329.0 IPERF; 7,297.0-7,301.0 SOS; 7,219.0 NIPPLE; 7,207.4 PACKER; 7,188.6 SEAL ASSY; 7,187.4 LEAK - TUBING; 7,158.0 SLEEVE-C; 7,153.6 NIPPLE; 7,153.6 LEAK - TUBING; 7,138.0 IPERF; 7,063.0-7,104.0 LEAK - C - Sand; 7,051.0 IPERF; 6,970.0-7,019.0 INJECTION; 6,926.8 PACKER; 6,880.3 PBR; 6,867.0 GAS LIFT; 6,816.6 GAS LIFT; 4,565.3 GAS LIFT; 2,959.0 SURFACE; 28.7-2,238.8 FLOAT SHOE; 2,236.8-2,238.8 FLOAT COLLAR; 2,152.3- 2,153.8 SAFETY VLV; 1,789.4 CONDUCTOR; 29.0-80.0 HANGER; 28.7-33.2 HANGER; 26.7-31.3 HANGER; 23.8 KUP INJ KB-Grd (ft) 30.50 RR Date 8/30/1982 Other Elev… 1G-01 ... TD Act Btm (ftKB) 7,970.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292080500 Wellbore Status INJ Max Angle & MD Incl (°) 45.18 MD (ftKB) 4,700.00 WELLNAME WELLBORE1G-01 Annotation Last WO: End Date 8/2/1993 H2S (ppm) DateComment SSSV: TRDP 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 1G-01 (PTD 182-130) Report of IA Exceeding DNE Date:Friday, July 5, 2024 12:10:14 PM Attachments:1G-01 90 day TIO plot & schematic.pdf From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Friday, July 5, 2024 12:00 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU 1G-01 (PTD 182-130) Report of IA Exceeding DNE Chris, KRU 1G-01 (PTD 182-130) injector was reported on the 7/3/24 bleed report to have exceeded the IA DNE of 2000 psi during well start up. Operations bled the IA from 2037 psi to 820 psi and CPAI does not intend to conduct diagnostics at this point as it is believed the increased IA pressure was thermally influenced during start up. CPAI will continue to monitor the well closely and report as required if any additional anomalies are observed. The 7” 26 lb/ft, K-55 has a burst rating of 7000 psi (45% burst rating = 3150 psi). Attached is a 90 day TIO plot and wellbore schematic for reference. Please let me know if you disagree or have any questions with this plan. Thank you, Shelby Sumrall Well Integrity Specialist | ConocoPhillips Alaska O: (907) 265-6678 | M: (907) 301-9374 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (EST. 44' of FILL) 7,318.0 1G-01 5/5/2017 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled CA2 plug body 1G-01 6/27/2024 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: WAIVERED WELL TxIA COMMUNICATION 8/26/2008 ninam Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 29.0 80.0 80.0 62.50 H-40 WELDED SURFACE 10 3/4 9.95 28.7 2,238.8 2,238.7 45.50 K-55 BTC PRODUCTION 7 6.28 26.7 7,956.9 6,992.0 26.00 K-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 23.8 Set Depth … 7,219.8 Set Depth … 6,408.7 String Max No… 3 1/2 Tubing Description TUBING 3.5x2.875 Wt (lb/ft) 9.30 Grade L-80 Top Connection BTC-MOD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 23.8 23.8 0.05 HANGER 8.000 MCEVOY GEN IV HANGER 3.500 1,789.4 1,789.3 0.85 SAFETY VLV 5.938 CAMCO TRDP-1AE SAFETY VALVE 2.812 2,959.0 2,957.1 10.98 GAS LIFT 5.390 CAMCO KBUG 2.920 4,565.3 4,360.5 43.22 GAS LIFT 5.390 CAMCO KBUG 2.920 6,816.6 6,084.5 35.44 GAS LIFT 5.968 CAMCO MMG-2 2.920 6,867.0 6,125.5 35.49 PBR 5.625 CAMCO PBR 2.937 6,880.4 6,136.4 35.50 PACKER 5.938 CAMCO HRP-1-SP RETRIEVABLE PACKER 2.937 6,926.8 6,174.2 35.78 INJECTION 5.968 CAMCO MMG 2.920 6,970.9 6,209.9 36.20 BLAST JTS 3.500 STEEL BLAST JOINTS 2.992 7,062.2 6,283.1 37.02 BLAST JTS 3.500 STEEL BLAST JOINTS 2.992 7,153.6 6,355.9 37.20 NIPPLE 4.540 AVA PORTED NIPPLE (2.75" AVA BPI W/ 3-3/16" PORTS) 2.750 7,187.4 6,382.8 37.11 SEAL ASSY 4.000 BAKER GBH-22 LOCATOR SEAL ASSEMBLY 2.405 7,188.6 6,383.8 37.10 PACKER 6.156 BAKER D PERMANENT PACKER 3.250 7,207.4 6,398.8 37.08 NIPPLE 3.668 CAMCO D NIPPLE NO GO 2.250 7,219.0 6,408.1 37.10 SOS 3.750 BAKER SHEAR OUT SUB, ELMD TTL @ 7214' during IPROF on 05/02/2006 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 7,051.0 6,274.2 36.92 LEAK - C - Sand Leak in straddle at 7051.5', and determined the injection split to be 100% into C sands (60% at leak, 40% at AVA). 5/3/2006 0.000 7,138.0 6,343.5 37.24 LEAK - TUBING TUBING LEAK WAS OBSERVED AT 7058' 2/21/2012 0.000 7,153.6 6,355.9 37.20 SLEEVE-C 2.75" AVA BPI w/ 3, 3/16" ports 7/4/2014 7,158.0 6,359.4 37.19 LEAK - TUBING POSSIBLE LEAK IDENTIFIED AT 7138' 2/21/2012 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,970.0 7,019.0 6,209.1 6,248.6 C-4, C-3, 1G-01 8/30/1982 12.0 IPERF Geo Vann TCP; 120° Ph 7,063.0 7,104.0 6,283.8 6,316.4 C-1, 1G-01 8/30/1982 12.0 IPERF Geo Vann TCP; 120° Ph 7,297.0 7,301.0 6,470.2 6,473.4 A-5, 1G-01 8/30/1982 12.0 IPERF Geo Vann TCP; 120° Ph 7,311.0 7,329.0 6,481.4 6,495.7 A-4, 1G-01 8/30/1982 12.0 IPERF Geo Vann TCP; 120° Ph 7,346.0 7,362.0 6,509.3 6,522.1 A-3, 1G-01 8/2/1993 4.0 APERF 28 deg CCW 1G-01, 6/28/2024 8:02:16 AM Vertical schematic (actual) PRODUCTION; 26.7-7,956.9 FLOAT SHOE; 7,954.8-7,956.9 FLOAT COLLAR; 7,858.8- 7,860.3 APERF; 7,346.0-7,362.0 IPERF; 7,311.0-7,329.0 IPERF; 7,297.0-7,301.0 SOS; 7,219.0 NIPPLE; 7,207.4 PACKER; 7,188.6 SEAL ASSY; 7,187.4 LEAK - TUBING; 7,158.0 SLEEVE-C; 7,153.6 NIPPLE; 7,153.6 LEAK - TUBING; 7,138.0 IPERF; 7,063.0-7,104.0 LEAK - C - Sand; 7,051.0 IPERF; 6,970.0-7,019.0 INJECTION; 6,926.8 PACKER; 6,880.3 PBR; 6,867.0 GAS LIFT; 6,816.6 GAS LIFT; 4,565.3 GAS LIFT; 2,959.0 SURFACE; 28.7-2,238.8 FLOAT SHOE; 2,236.8-2,238.8 FLOAT COLLAR; 2,152.3- 2,153.8 SAFETY VLV; 1,789.4 CONDUCTOR; 29.0-80.0 HANGER; 28.7-33.2 HANGER; 26.7-31.3 HANGER; 23.8 KUP INJ KB-Grd (ft) 30.50 RR Date 8/30/1982 Other Elev… 1G-01 ... TD Act Btm (ftKB) 7,970.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292080500 Wellbore Status INJ Max Angle & MD Incl (°) 45.18 MD (ftKB) 4,700.00 WELLNAME WELLBORE1G-01 Annotation Last WO: End Date 8/2/1993 H2S (ppm) DateComment SSSV: TRDP 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 1G-01 (PTD 182-130) Report of suspect IA pressure increase Update 11 Mar 24 Date:Monday, March 11, 2024 10:10:15 AM Attachments:AnnComm Surveillance TIO for 1G-01.pdf MIT KRU 1G-01 Diagnostic MITIA 02-12-24.xlsx From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Monday, March 11, 2024 8:06 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: RE: KRU 1G-01 (PTD 182-130) Report of suspect IA pressure increase Update 11 Mar 24 Chris, After reporting 1G-01 (PTD 182-130) (AIO 2B.035) last month the well passed a diagnostic MITIA to 3300 psi and the IA pressure was bled down for the monitor period. During the monitor period the IA pressure stabilized and required no further bleeds. COPA plans to return the well to ‘normal’ status. Any future annular communication issue will be reported if and when it is observed. Regards, Jan Byrne Well Integrity Specialist | ConocoPhillips Alaska O: (907) 265-6471 | M: (808) 345-6886 From: Byrne, Jan Sent: Tuesday, February 6, 2024 2:26 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU 1G-01 (PTD 182-130) Report of suspect IA pressure increase Chris, KRU 1G-01 (PTD 182-130) (AIO 2B.035) is exhibiting increased IA pressure bleeds (well is waivered for TxIA communication). COPA plans to have DHD perform diagnostics including a MITIA and IA- DDT to set the well up for a 30-day monitor. Any proper paperwork for continued injection or corrective action will be submitted once diagnostics and the 30-day monitor has been completed and a plan forward is determined. 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 1G-01 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 1G-01 2024-01-10 1400.0 900 -500.0 IA 1G-01 2024-01-14 2075.0 975 -1100.0 IA 1G-01 2024-01-18 1800.0 1602 -198.0 IA 1G-01 2024-01-21 1700.0 1000 -700.0 IA 1G-01 2024-02-07 1575.0 483 -1092.0 IA Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB (EST. 44' of FILL) 7,318.0 5/5/2017 1G-01 pproven Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: UPDATED MISSING LEAKS adding GLM's soon 6/19/2020 1G-01 pproven Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 29.0 Set Depth (ftKB) 80.0 Set Depth (TVD) … 80.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 10 3/4 ID (in) 9.95 Top (ftKB) 28.7 Set Depth (ftKB) 2,238.8 Set Depth (TVD) … 2,238.7 Wt/Len (l… 45.50 Grade K-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 26.7 Set Depth (ftKB) 7,956.9 Set Depth (TVD) … 6,992.0 Wt/Len (l… 26.00 Grade K-55 Top Thread BTC Tubing Strings Tubing Description TUBING 3.5x2.875 String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 23.8 Set Depth (ft… 7,219.8 Set Depth (TVD) (… 6,408.7 Wt (lb/ft) 9.30 Grade L-80 Top Connection BTC-MOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 23.8 23.8 0.05 HANGER MCEVOY GEN IV HANGER 3.500 1,789.4 1,789.3 0.85 SAFETY VLV CAMCO TRDP-1AE SAFETY VALVE 2.812 6,867.0 6,125.5 35.49 PBR CAMCO PBR 2.937 6,880.4 6,136.4 35.50 PACKER CAMCO HRP-1-SP RETRIEVABLE PACKER 2.937 6,970.9 6,209.9 36.20 BLAST JTS STEEL BLAST JOINTS 2.992 7,062.2 6,283.1 37.02 BLAST JTS STEEL BLAST JOINTS 2.992 7,153.6 6,355.9 37.20 NIPPLE AVA PORTED NIPPLE (2.75" AVA BPI W/ 3-3/16" PORTS) 2.750 7,187.4 6,382.8 37.11 SEAL ASSY BAKER GBH-22 LOCATOR SEAL ASSEMBLY 2.405 7,188.6 6,383.8 37.10 PACKER BAKER D PERMANENT PACKER 3.250 7,207.4 6,398.8 37.08 NIPPLE CAMCO D NIPPLE NO GO 2.250 7,219.0 6,408.1 37.10 SOS BAKER SHEAR OUT SUB, ELMD TTL @ 7214' during IPROF on 05/02/2006 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 7,051.0 6,274.2 36.92 LEAK - TUBING (7051-7058) E-LINE IPROF IDENTIFIED C-SAND LEAK (Found leak in straddle at 7051.5', and determined the injection split to be 100% into C sands (60% at leak, 40% at AVA). Logged with well shut in, no cross flow detected between sands.) 5/3/2006 0.000 7,138.0 6,343.5 37.24 LEAK - TUBING A TUBING LEAK WAS OBSERVED AT 7058' AND ANOTHER POSSIBLE LEAK IDENTIFIED AT 7138', WHILE INJECTING AT 4500 BWPD 2/21/2012 0.000 7,153.6 6,355.9 37.20 SLEEVE-C 2.75" AVA BPI w/ 3, 3/16" ports 7/4/2014 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 6,970.0 7,019.0 6,209.1 6,248.6 C-4, C-3, 1G-01 8/30/1982 12.0 IPERF Geo Vann TCP; 120 deg Ph 7,063.0 7,104.0 6,283.8 6,316.4 C-1, 1G-01 8/30/1982 12.0 IPERF Geo Vann TCP; 120 deg Ph 7,297.0 7,301.0 6,470.2 6,473.4 A-5, 1G-01 8/30/1982 12.0 IPERF Geo Vann TCP; 120 deg Ph 7,311.0 7,329.0 6,481.4 6,495.7 A-4, 1G-01 8/30/1982 12.0 IPERF Geo Vann TCP; 120 deg Ph 7,346.0 7,362.0 6,509.3 6,522.1 A-3, 1G-01 8/2/1993 4.0 APERF 28 deg CCW Notes: General & Safety End Date Annotation 8/26/2008 NOTE: WAIVERED WELL TxIA COMMUNICATION 1G-01, 6/19/2020 5:49:36 PM Vertical schematic (actual) PRODUCTION; 26.7-7,956.9 APERF; 7,346.0-7,362.0 IPERF; 7,311.0-7,329.0 IPERF; 7,297.0-7,301.0 PACKER; 7,188.6 SLEEVE-C; 7,153.6 LEAK - TUBING; 7,138.0 IPERF; 7,063.0-7,104.0 LEAK - TUBING (7051-7058); 7,051.0 IPERF; 6,970.0-7,019.0 INJECTION; 6,926.8 PACKER; 6,880.3 PBR; 6,867.0 GAS LIFT; 6,816.6 GAS LIFT; 4,565.3 GAS LIFT; 2,959.0 SURFACE; 28.7-2,238.8 SAFETY VLV; 1,789.4 CONDUCTOR; 29.0-80.0 KUP INJ KB-Grd (ft) 30.50 Rig Release Date 8/30/1982 1G-01 ... TD Act Btm (ftKB) 7,970.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292080500 Wellbore Status INJ Max Angle & MD Incl (°) 45.18 MD (ftKB) 4,700.00 WELLNAME WELLBORE1G-01 Annotation Last WO: End Date 8/2/1993 H2S (ppm) DateComment SSSV: TRDP Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 1821300 Type Inj W Tubing 2241 2233 2241 2253 Type Test P Packer TVD 6163 BBL Pump 4.4 IA 40 3300 3200 3175 Interval O Test psi 1541 BBL Return OA 170 360 350 340 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 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 / 1G Pad Richwine 02/12/24 Notes:Diagnostic MITIA Notes: 1G-01 Notes: 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 1G-01 Diagnostic MITIA 02-12-24 (002) 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 1G-01 (PTD 182-130) Report of suspect IA pressure increase Date:Tuesday, February 6, 2024 2:35:06 PM Attachments:AnnComm Surveillance TIO for 1G-01.pdf Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: Byrne, Jan <Jan.Byrne@conocophillips.com> Sent: Tuesday, February 6, 2024 2:26 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU 1G-01 (PTD 182-130) Report of suspect IA pressure increase Chris, KRU 1G-01 (PTD 182-130) (AIO 2B.035) is exhibiting increased IA pressure bleeds (well is waivered for TxIA communication). COPA plans to have DHD perform diagnostics including a MITIA and IA- DDT to set the well up for a 30-day monitor. Any proper paperwork for continued injection or corrective action will be submitted once diagnostics and the 30-day monitor has been completed and a plan forward is determined. 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 1G-01 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 1G-01 2023-11-14 1885.0 150 -1735.0 IA 1G-01 2024-01-10 1400.0 900 -500.0 IA 1G-01 2024-01-14 2075.0 975 -1100.0 IA 1G-01 2024-01-21 1700.0 1000 -700.0 IA 1G-01 2024-01-18 1800.0 1602 -198.0 IA Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB (EST. 44' of FILL) 7,318.0 5/5/2017 1G-01 pproven Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: UPDATED MISSING LEAKS adding GLM's soon 6/19/2020 1G-01 pproven Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 29.0 Set Depth (ftKB) 80.0 Set Depth (TVD) … 80.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 10 3/4 ID (in) 9.95 Top (ftKB) 28.7 Set Depth (ftKB) 2,238.8 Set Depth (TVD) … 2,238.7 Wt/Len (l… 45.50 Grade K-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 26.7 Set Depth (ftKB) 7,956.9 Set Depth (TVD) … 6,992.0 Wt/Len (l… 26.00 Grade K-55 Top Thread BTC Tubing Strings Tubing Description TUBING 3.5x2.875 String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 23.8 Set Depth (ft… 7,219.8 Set Depth (TVD) (… 6,408.7 Wt (lb/ft) 9.30 Grade L-80 Top Connection BTC-MOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 23.8 23.8 0.05 HANGER MCEVOY GEN IV HANGER 3.500 1,789.4 1,789.3 0.85 SAFETY VLV CAMCO TRDP-1AE SAFETY VALVE 2.812 6,867.0 6,125.5 35.49 PBR CAMCO PBR 2.937 6,880.4 6,136.4 35.50 PACKER CAMCO HRP-1-SP RETRIEVABLE PACKER 2.937 6,970.9 6,209.9 36.20 BLAST JTS STEEL BLAST JOINTS 2.992 7,062.2 6,283.1 37.02 BLAST JTS STEEL BLAST JOINTS 2.992 7,153.6 6,355.9 37.20 NIPPLE AVA PORTED NIPPLE (2.75" AVA BPI W/ 3-3/16" PORTS) 2.750 7,187.4 6,382.8 37.11 SEAL ASSY BAKER GBH-22 LOCATOR SEAL ASSEMBLY 2.405 7,188.6 6,383.8 37.10 PACKER BAKER D PERMANENT PACKER 3.250 7,207.4 6,398.8 37.08 NIPPLE CAMCO D NIPPLE NO GO 2.250 7,219.0 6,408.1 37.10 SOS BAKER SHEAR OUT SUB, ELMD TTL @ 7214' during IPROF on 05/02/2006 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 7,051.0 6,274.2 36.92 LEAK - TUBING (7051-7058) E-LINE IPROF IDENTIFIED C-SAND LEAK (Found leak in straddle at 7051.5', and determined the injection split to be 100% into C sands (60% at leak, 40% at AVA). Logged with well shut in, no cross flow detected between sands.) 5/3/2006 0.000 7,138.0 6,343.5 37.24 LEAK - TUBING A TUBING LEAK WAS OBSERVED AT 7058' AND ANOTHER POSSIBLE LEAK IDENTIFIED AT 7138', WHILE INJECTING AT 4500 BWPD 2/21/2012 0.000 7,153.6 6,355.9 37.20 SLEEVE-C 2.75" AVA BPI w/ 3, 3/16" ports 7/4/2014 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 6,970.0 7,019.0 6,209.1 6,248.6 C-4, C-3, 1G-01 8/30/1982 12.0 IPERF Geo Vann TCP; 120 deg Ph 7,063.0 7,104.0 6,283.8 6,316.4 C-1, 1G-01 8/30/1982 12.0 IPERF Geo Vann TCP; 120 deg Ph 7,297.0 7,301.0 6,470.2 6,473.4 A-5, 1G-01 8/30/1982 12.0 IPERF Geo Vann TCP; 120 deg Ph 7,311.0 7,329.0 6,481.4 6,495.7 A-4, 1G-01 8/30/1982 12.0 IPERF Geo Vann TCP; 120 deg Ph 7,346.0 7,362.0 6,509.3 6,522.1 A-3, 1G-01 8/2/1993 4.0 APERF 28 deg CCW Notes: General & Safety End Date Annotation 8/26/2008 NOTE: WAIVERED WELL TxIA COMMUNICATION 1G-01, 6/19/2020 5:49:36 PM Vertical schematic (actual) PRODUCTION; 26.7-7,956.9 APERF; 7,346.0-7,362.0 IPERF; 7,311.0-7,329.0 IPERF; 7,297.0-7,301.0 PACKER; 7,188.6 SLEEVE-C; 7,153.6 LEAK - TUBING; 7,138.0 IPERF; 7,063.0-7,104.0 LEAK - TUBING (7051-7058); 7,051.0 IPERF; 6,970.0-7,019.0 INJECTION; 6,926.8 PACKER; 6,880.3 PBR; 6,867.0 GAS LIFT; 6,816.6 GAS LIFT; 4,565.3 GAS LIFT; 2,959.0 SURFACE; 28.7-2,238.8 SAFETY VLV; 1,789.4 CONDUCTOR; 29.0-80.0 KUP INJ KB-Grd (ft) 30.50 Rig Release Date 8/30/1982 1G-01 ... TD Act Btm (ftKB) 7,970.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292080500 Wellbore Status INJ Max Angle & MD Incl (°) 45.18 MD (ftKB) 4,700.00 WELLNAME WELLBORE1G-01 Annotation Last WO: End Date 8/2/1993 H2S (ppm) DateComment SSSV: TRDP MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, September 1, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1G-01 KUPARUK RIV UNIT 1G-01 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/01/2023 1G-01 50-029-20805-00-00 182-130-0 W SPT 6136 1821300 3000 2280 2280 2280 2280 500 650 650 650 REQVAR P Sully Sullivan 7/1/2023 2 year mitia to maip (3000 psi) per aio 2b.035 PT to 3300 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 1G-01 Inspection Date: Tubing OA Packer Depth 865 3300 3180 3150IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS230703071124 BBL Pumped:2.9 BBL Returned:2.8 Friday, September 1, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 9 aio 2b.035 James B. Regg Digitally signed by James B. Regg Date: 2023.09.01 14:46:37 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 14, 2021 P.I. Supervisor TO: Jim R�p�J I� � SUBJECT: Mechanical Integrity Tests 1 �c ConocoPhillips Alaska, Inc. IG -01 FROM: Austin McLeod KUPARUK RIV UNIT 1G-01 Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv� NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1G-01 API Well Number 50-029-20805-00-00 Inspector Name: Austin McLeod Permit Number: 182-130-0 Inspection Date: 7/3/2021 — Insp Num: mitSAM210704164330 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IG -01 ''Type Inj W TVD 6136 Tubing 2460 , 2465- 1 2470- 1 2470 - _ - -- -- PT 1821300 Type Te SPT Test psi -- 3000 ----- IA i 690 3300 - 3160 - — 3140 - — -- — BBL Pumped: 3.1�BBL Returned: 3 --- OAA 385 560 -' 560 - 550 - Interval ReQvAR P/F P Notes: MITIA to MAIP. AIO 213.035. Wednesday, July 14, 2021 Page I of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, July 15, 2019 TO: Jim Regg •'^lf P.I. Supervisor I`e'r'I SUBJECT: Mechanical Integrity Tests (( ConocoPhillips Alaska, Inc. IG -01 FROM: Brian Bixby - KUPARUKRIV UNIT IG -01 Petroleum Inspector Well Name KUPARUK RIV UNIT IG -01 Insp Num: mitBDB190708070432 Rel Insp Num: Sre: Inspector Reviewed By: P.I. Supry�� NON -CONFIDENTIAL Comm API Well Number 50-029-20805-00-00 Inspector Name: Brian Bixby Permit Number: 182-130-0 Inspection Date: 7/7/2019 ' Packer Depth Pretest Initial I5 Min 30 Min 45 Min 60 Min Well G -0i TypeInj w"TVD 6136 'ITubing ��vo 2300300 2300 PTD 821300 ' Type Test sPT Test psi 3000 IA sso 3300 1175 3150 ' BBL Pumped: 33 BBL Returned: 3.1 OA as o0 700 700 Interval REQVAR P/F P Notes: As per AIO 2B.035 � Monday, July 15, 2019 Page I of I r • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Wednesday, December 6,2017 8:46 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: RE: Report of unexplained drop in OA pressure 1G-01 (AIO 2B.035, PTD 182-130) update 12-6-17 Attachments: MIT KRU 1G-01 Diagnostic MITOA 12-5-17.xlsx Chris, Yesterday, DHD achieved passing outer casing packoff tests and MITOA. There does not appear to be an issue with the surface casing at this time. We intend to return the well to its normally waivered status,governed under AIO 2B.035. Please let us know if you have any questions or disagree with the plan forward. Attached is the MITOA data. Kelly Lyons/Jan Byrne Well Integrity Supervisor SCANNED ConocoPhillips Alaska, Inc. Desk Phone (907)659-7224 From: NSK Well Integrity Supv CPF1 and 2 Sent:Sunday, December 03, 2017 8:38 PM To:Wallace,Chris D (DOA)<chris.wallace@alaska.gov> Cc:Senden, R.Tyler<R.Tyler.Senden@conocophillips.com> Subject: Report of unexplained drop in OA pressure 1G-01 (AIO 26.035, PTD 182-130) 12-3-17 Chris, KRU injector 1G-01 (AIO 26.035, PTD 182-130) is currently waivered for TxIA communication. During a review of the TIO plot during preparation of the monthly report,an unexplained precipitous drop in its OA pressure was identified to have occurred around November 2, 2017. An OA fluid level obtained yesterday was found to be at "36',which is not expected considering a passing MITOA was performed in July 2017. The OA is currently holding around 150 psi and no evidence of an external leak to atmosphere is present. Therefore we intend to keep the well online while we perform initial diagnostics to include an MITOA and/or surface casing leak detect and outer casing packoff tests. At this point, the cement shoe of the surface casing is suspected of letting go. A follow-up email will be provided at the conclusion of the diagnostics. Please let us know if you disagree with the path forward. Attached are the schematic and 90 day TIO plot. Kelly Lyons/Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907)659-7224 1 Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Sunday, December 3, 2017 8:38 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: Report of unexplained drop in OA pressure 1G-01 (AIO 2B.035, PTD 182-130) 12-3-17 Attachments: 1G-01 90 day TIO 12-3-17.JPG; 1G-01 schematic.pdf Chris, KRU injector 1G-01 (AIO 2B.035, PTD 182-130) is currently waivered for TxIA communication. During a review of the TIO plot during preparation of the monthly report,an unexplained precipitous drop in its OA pressure was identified to have occurred around November 2, 2017. An OA fluid level obtained yesterday was found to be at—36',which is not expected considering a passing MITOA was performed in July 2017. The OA is currently holding around 150 psi and no evidence of an external leak to atmosphere is present. Therefore we intend to keep the well online while we perform initial diagnostics to include an MITOA and/or surface casing leak detect and outer casing packoff tests. At this point, the cement shoe of the surface casing is suspected of letting go. A follow-up email will be provided at the conclusion of the diagnostics. Please let us know if you disagree with the path forward. Attached are the schematic and 90 day TIO plot. Kelly Lyons/Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907)659-7224 SCANNED ,.. ,.• 1 PV ConocoPhillips RECEIVED Alaska P.O. BOX 100360 OCT ANCHORAGE,ALASKA 99510-0360 AOGCC 19 2017 7 October 15, 2017 Commissioner Hollis French Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 SCANNED DEC . 4 2017. Commissioner Hollis French: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The attached spread sheet presents the well name,top of cement depth prior to filling and volumes used on each conductor. Please call Roger Mouser or Roger Winter at 907-659-7506, if you have any questions. Sincerely, Roger Mouser ConocoPhillips Well Integrity Field Supervisor + • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10-404) Kuparuk Field Date 10/7/2016 1B-11,1E-32, 1G-01 &1R-16 Corrosion Initial top Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# of cement pumped cement date inhibitor sealant date ft bbls ft gal 1B-11 50029206570000 181-136-0 12" NA 12" NA 3.4 10/14/2017 1E-32 50029227880000 197-132-0 7' 0.5 8" 7/16/2017 2 9/20/2017 1G-01 50029208050000 182-130-0 14'7" 2.50 13" 7/16/2017 3.4 9/20/2017 1R-16 50029213880000 185-153-0 22" 0.25 7.5" 7/17/2017 4.2 9/10/2017 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Tuesday,July 18,2017 P.I.Supervisor 1 fel ?ria--1, 7 SUBJECT: Mechanical Integrity Tests I ' CONOCOPHILLIPS ALASKA,INC. 1G-01 FROM: Jeff Jones KUPARUK RIV UNIT 1G-01 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1G-01 API Well Number 50-029-20805-00-00 Inspector Name: Jeff Jones Permit Number: 182-130-0 Inspection Date: 7/8/2017 Insp Num: mitJJ170718113744 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IG-Ol ' Type Inj W TVD 6136 Tubing 2307 - 2303 2300 - 2287 ' PTD 1821300 Type Test SPT Test psi 3000 - IA 830 3290 " I 3170 - 3130 ------------ BBL Pumped: 3.1 - BBL Returned: 2.8 OA 615 765 755 755 Interval REQVAR P/F P Notes: AIO 02B.035 T x IA communication.2 Year MIT-IA SCANNED SEP 2 5 2017 Tuesday,July 18,2017 Page 1 of 1 STATE OF ALASKA RECEIVED ALTA OIL AND GAS CONSERVATION COMIOION mg y 0 9 2017 REPORT OF SUNDRY WELL OPERATIONS ��`J� 1.Operations Abandon Plug Perforations ❑ Fracture Stimulate ElPull Tubing❑ AQQ Q ons SQtdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well❑ Conductor/Surface casing 0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development ❑ Exploratory ❑ 182-1300 3.Address: Stratigraphic ❑ Service 0 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 50-029-20805-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025640 KRU 1G-01 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NA Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 7970' feet Plugs measured 7153' feet true vertical 7002' feet Junk measured NA feet Effective Depth measured 7295' feet Packer measured 6880',7189' feet true vertical 6468' feet true vertical 6136',6384' feet Casing Length Size MD TVD Burst Collapse Structural NA NA NA NA Conductor 51' 16 80' 80' Surface 2210' 10 3/4 2239' 2239' Intermediate NA NA NA NA Production 7930' 7 7959' 6992' Liner NA NA NA NA Perforation depth Measured depth 6970-7104,7297-7362 feet True Vertical depth 6209-6316,6470-6522 feet Tubing(size,grade,measured and true vertical depth) 2 7/8,L-80,MD 7219,TVD 6408 Camco TRDP-1AE Safety Valve,MD 1789,TVD 1789 Packers and SSSV(type,measured and true vertical depth) Camco HRP-1-SP Retrievable Packer,MD 6880,TVD 6136 Baker D Permanet Packer,MD 7188,TVD 6383 12.Stimulation or cement squeeze summary: Intervals treated(measured): NASCANNED i 1 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: NA NA NA NA NA Subsequent to operation: NA NA NA NA NA 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development❑ Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG 0 GINJ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-153 Authorized Name: Roger Winter Contact Name: Roger Winter/Roger Mouser Authorized Title: WI Field Supervi or Contact Email: N1927 conocophillips.com ,(/ 5/5/2017 659-7506 Authorized Signature: "�-�� Dab Contact Phone: VTL 61W/7- RBDMS Vi MAY 1 6 2017 Form 10-404 Revised 4/20176�7/,� Submit Original Only • RECEIVED May 5, 2017 MAY 0 9 2017 AOGCC Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Cathy Foerster: Enclosed please find the 10-404 for conductor repair on well 1G-01, PTD 182-130, Sundry 317-153 —surface casing did not need any repairs. Please contact me at 907-659-7506 if you have any questions. Sincerely, { Roger Winter ConocoPhillips Well Integrity Field Supervisor Enclosures: Summary of work 10-404 Sundry Pictures of damaged conductor and repaired conductor • • SUMMARY 4/26/2017 Cut and remove 16' of conductor, remove cement and buff surface casing, Kakivik UT surface casing to confirm good pipe. 4/27/2017 Denso wrap surface casing. 4/28/2017 Install 16' of conductor. • . ...-.1:',-.... , ,,r,. ,,i„. , :.,;„....,:,,,,,,*,,,,,,„4„ N......'; ' ., .,..:,..:,11--1.:::::';''',,-,'". ' d , ....,l'if.-',''' ' '' -,';;:tri',,,- -...K.,.:'''''' 'I'N.,.. '''..'.\ I t -''' :: :' ,. ,,,•••:''''''''''; - .,..#,—'''''1,1,,,,'-'11-.0°,. •,' . ,..,,,,.,„....,'..;,‘:,,`,:s,„„--.,;,---,,,-;.,,....,•.„-:::::•......• q <x ` ''''s,,,, \ e m „..1,44tH,t,__,,,,,'-iy;ar,,:',.:::.1,:ir,,,4*,,,,,',.!L,',..i:',,,r i • Y tea.. A y t� t ,ro , ; r- �r h pr f » F I`"t ab Y bj i -"'r,.0 4.,,,,,„'"1441;:t:‘-~'". -, ' ''. :'.4 't: 4 ' --:t ; '4',''. b W ii .,yy, / rJ 3:;'"'f.,:-F:,,t,,',.:"::4;:::,,.::,f--:.',1. it _ ,..r„,,,,:,,,.0!„ gid , photograph is pr ovid , ,,, ' 4 permission to copy fori•t k - ii,-,..,::x �: any other purpos �.or` . ,; r t, ' 4:, • •.' e+` ithout thF u t .:e°ht a iorrpcoPhil{ •s Alaska Inc.:: *' •.,•,,'°:„''.,,,„,.., ' ii 11' t, ... `q � 3.w Yk r „,,,,,,"...::::::1,,,,, ', , , :1- :,-.,,i; ,. ,. ..,...,F.,,,,'',,,;41: , ' 1.. ,' ,.,.• „.,... .. , ... . „.„,,, ., , ...,1t.;.......„:4 , 4i,....... ...: , #. „„ P' ...., ., , i �v r .f ti s az . . s c & '.0 , 4,a .' a �' * {3 F,,,,11'."4 �* es l�i.'a 1.1. a° aph eta peri1?1st1 P � �� ^r . ." G '1°'` IT «ice ,� "1� ��t w ;tri -r: ` . C�r 1 1 r. , r r ,, x • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission 5/tilt TO: Jim Regg 1\6'11 DATE: 4/27/2017 P. I. Supervisor FROM: Matt Herrera SUBJECT: Surface Casing Repair Petroleum Inspector KRU 1G-01 CPAI PTD 1821300; Sundry 317-153 April 27, 2017: Received a submittal from Roger Mouser, CPAI Well Integrity Supervisor for opportunity to inspect the surface casing on injector KRU 1G-01. I travelled out to KRU 1G-pad and met with the Well Integrity Lead. The area surrounding the conductor had been excavated and split section of the conductor had been removed. Cement from the conductor by surface casing annulus had also been removed to inspect the adjoining surface casing. A UT scope had been performed on the surface casing to establish wall loss on the surface casing. A 0.31-inch reading out of the original 0.40-inch pipe wall thickness was verified. CPAI plans to wrap the surface casing from the excavated ground level to the bottom of tubing hanger (as close as possible) with Denso Wrap. The conductor casing will then be patched. Timing for any future MIT testing will be determined upon completion. Attachments: Photos (2) SCONE® SEP 1 017 2017-0427_Casing_RepairKRU_1 G-01_mh.docx Page 1 of 2 • 0 Conductor and Surface Casing Repair KRU 1G-01 (PTD 1821300) Photos by AOGCC Inspector M. Herrera 4/27/2017 V - ''' - , . . f ,i s . t,,� , k 1a Y .,,.. ‘., , ,... fl „, A , k. „ . 0 . :;..: , , , 4 ! , ,0, . a . ,. t , . t'Y , -t-.. „ #, , #•• '. w y . * x it aY� s• a s 'ti~ ar , J it "' I,) t ' - s All 2017-0427_Casing_Repair_KRU_1 G-O 1_mh.docx Page 2 of 2 • • SOF T1, • \ � THE STATE Alaska Oil and Gas k � ��, of LAsKA Conservation Cornmission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Roger Winter WI Field Supervisor ConocoPhillips Alaska, Inc. SCANNED MA:. z'`,, P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1G-01 Permit to Drill Number: 182-130 Sundry Number: 317-153 Dear Mr. Winter: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, i Daniel T. Seamount, Jr. Commissioner DATED this Zct day of April, 2017. RBD 1S U- r„VI - 3 2017 • • RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APR 1 7 2017 APPLICATION FOR SUNDRY APPROVALS � �� 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well 2 • Operations shutdown El Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Apgrowed Program i/ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: P Sim l �L aL7 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development ❑ 182-1300 3.Address: 6.API Number: Stratigraphic ❑ Service ❑ P.O.Box 100360,Anchcorage,Alaska 99510 50-029-20805-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A r Will planned perforations require a spacing exception? Yes ❑ No 0 ✓ KRU 1G-01 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025640 ' Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD MPSP(psi): Plugs(MD): Junk(MD): 7970 ### as 79.95 I 611c% ' 7153' Casing Length Size MD TVD Burst Collapse Structural NA NA NA NA Conductor 51' 16 80' 80' Surface 2210' 10 3/4 2239' 2239' Intermediate NA NA NA NA Production 7930' 7 7957' 6992' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 6970-7104,7297-7362 i 6209-6316,6470-6522 2 7/8 L-80 7219 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): TRDP+CAMCO TRDP-1AE ' MD=1789 TVD=1789 PACKER=CAMCO HRP-1-SP RETRIEVABLE PACKER ` MD=6880 TVD=6136 PACKER=BAKER D PERMANENT PACKER - MD=7189 TVD=6384 12.Attachments: Proposal Summary ❑ Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service I] 14.Estimated Date for 4/15/2017 15.Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: Li-Aq.- 17 7 GAS ❑ WAG 0 ' GSTOR ❑ SPLUG ❑ Commission Representative: 6`''''', S�(.,,_v,_i,-(-L GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing lis true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Roger Winter Contact Name: Roger Winter/Roger Mouser Authorized Title: WI Feld Supervi r Contact Email: N1927( conocophillips.com c Contact Phone: 659-7506 Authorized Signature: Date: 4/12/2017 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test❑ Mechanical Integrity Test ❑ Location Clearance ❑ 144,;c- c-j t si=-t i(i / C w Other: �t a 1-c, CC d 1 �'� /'-c R t y- Post Initial Injection MIT Req'd? Yes ❑ No ❑ i 0 -- "F0 4- Spacing Exception Required? Yes ❑ No d Subsequent Form Required: / RBENVIS (/l-1,%: Y - 3 2017 APPROVED SY / ) 17 Approved by: COMMISSIONER THE COMMISSION Date: ,m6 y'1I /� '� q-/ 44,,,,,,--z 4W 7 C� Submit Form and Form 10-403 Revised 4/2017 RA o JIi1Or�is valid for 12 months from the date of approval. Attachments in Duplicate • • RECEIVED APR 172017 April 12, 2017 AOGCC Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Cathy Foerster: Enclosed please find the 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 1G-01, PTD 182-130 for repairing split conductor—fwe would also like permission to repair surface casing if it is needed after we remove conductor. We have already excavated to 20' to repair the split burst seam on conductor and now we want to remove—18' of conductor to confirm integrity on surface casing. pIf you agree and approve this work can we get a verbal as soon as possible. Please contact me at 907-659-7506 if you have any questions. 1. J14 S i Ise pct"- Sincerely, /V1 , .L"--L7 Roger Winter ConocoPhillips Well Integrity Field Supervisor Enclosures: Description Summary of Proposal 10-403 Application for Sundry Approvals 1R-16 Wellbore Schematic • • ConocoPhillips Alaska, Inc. Kuparuk 1G-01 (PTD 182-130) SUNDRY NOTICE 10-403 APPROVAL REQUEST April 12, 2017 This application for Sundry approval for Kuparuk well 1G-01 is for the repair of conductor and inspection of surface casing. Subsequent diagnostics and visual found conductor is split. ConocoPhillips requests approval to repair the conductor and inspect surface casing and if damaged repair surface casing as well. le" With approval, inspection and repair of the conductor/surface casing will require the following general steps: 1. Secure the well as needed with mechanical plug in tubing 2. Remove the floor grate,well house, flow lines, and other equipment as necessary from around the wellhead. 3. Remove gravel around wellhead and excavate to 4. Install nitrogen purge equipment for the conductor and OA(if needed) so that hot work may be conducted in a safe manner. 5. Remove conductor casing and remove cement from the outside of the surface casing for inspection, Notify AOGCC Inspector for opportunity to inspect. 6. Repair of the conductor will be done with 16" 62 pd .375 wall pipe and if needed CPAI Mechanical Engineers will determine type of patch or repair needed to return the surface casing to operational integrity. 7. QA/QC will verify the repair for a final integrity check—if repairing surface casing. 8. Perform a MIT to confirm no fluid to surface—if repairing surface casing. 9. Install anti-corrosion coating as specified by CPAI Corrosion Engineer. k {`r CP 10. Replace the conductor and fill the void with cement and top off with sealant. - �- Swr 11. Backfill as needed with gravel around the wellhead. 12. Remove plug(s)and return the well to injection. 13. File 10-404 with the AOGCC post repair. KUP INJ 1G-01 • ClonocoPhillips g , Well Attributes Max Angle&MD TD Alaska 1riC P 04414111 Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) Corweominips KO 500292080500 KUPARUK RIVER UNIT INJ 45.18 4,700.00 7,970.0 .-. M1 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date ---10-01,717/2014 1.08,43 PM SSSV:TRDP Last WO: 8/2/1993 30.50 8/30/1982 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date __.__ ... ....,-... ._.___ '9 7- Last Tag:SLM 7,295.0 6/26/2014 Rev Reason:TAG,SETAVA BPI hipshkf 7/7/2014 HANGER;23.8 e Casing Strings It AMR 1 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WtlLen(I...Grade Top Thread " CONDUCTOR 16 15.062 29.0 80.0 80.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread � I-. 1 SURFACE 10 3/4 9.950 28.7 2,238.8 2,238.7 45.50 K-55 BTC ' ' ' ' '' '' '' , )! ° '441u6 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WtlLen(I...Grade Top Thread PRODUCTION 7 6.276 26.7 7,956.9 6,992.0 26.00 K-55 BTC Tubing Strings Tubing Description String Ma...ID En) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(lb/ft) Grade Top Connection TUBING 3.5x2 875 3 1/2 2.992 23.8 7,219.8 6 408.7 9.30 L-80 BTC-MOD .AAA CONDUCTOR.29.0-80.0' Completion Details - Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(3 Item Des Com (in) 23.8 23.8 0.05 HANGER MCEVOY GEN IV HANGER 3.500 SAFETY VLV;1,789.4 IT= 1,789.4 1,789.3 0.85 SAFETY VLV CAMCO TRDP-1AE SAFETY VALVE 2.812 11 6,867.0 6,125.5 35.49 PBR CAMCO PBR 2.937 6,880.4 6,136.4 35.50 PACKER CAMCO HRP-1-SP RETRIEVABLE PACKER 2.937 6,970.9 6,209.9 36.20 BLAST JTS STEEL BLAST JOINTS 2.992 7,062.2 6,283.1 37.02 BLAST JTS STEEL BLAST JOINTS 2.992 (( 1 [ 7,153.6 6,355.9 37.20 NIPPLE AVA PORTED NIPPLE(2.75"AVA BPI W/3-3/16" PORTS) 2.750 SURFACE;28.7-2,238.8-,, il I - 7,187.4 6,382.8 37.11 SEAL ASSY BAKER GBH-22 LOCATOR SEAL ASSEMBLY 2.405 GAS LIFT;2,959.0 7,188.6 6,383.8 37.10 PACKER BAKER D PERMANENT PACKER 3.250 7,207.4 6,398.8 37.08 NIPPLE CAMCO D NIPPLE NO GO 2.250 7,219.0 6,408.1 37.10 SOS BAKER SHEAR OUT SUB,ELMD TTL @ 7214 during 2.441 GAS LIFT;4.565.3 (PROF on 05/02/2006 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Inc! ta Top(ftKB) (ftKB) (°) Des Corn Run Date ID(in) GAS LIFT;6,816.6 7,153.6 6,355.9 37.20 SLEEVE-C 2.75"AVA BPI w/3,3/16"ports 7/4/2014 Perforations&Slots Shot Dens Top(ND) Btm(ND) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 6,970.0 7,019.0 6,209.1 6,248.6 C-4,C-3,1G- 8/30/1982 12.0 IPERF Geo Vann TCP;120 deg PBR;6,867.0 II ,I 01 Ph PACKER;6,860.3 :` 7,063.0 7,104.0 6,283.8 6,316.4 C-1,1G-01 8/30/1982 12.0 IPERF Geo Vann TCP;120 deg Ph 7,297.0 7,301.0 6,470.2 6,473.4 A-5,1G-01 8/30/1982 12.0 (PERF Geo Vann TCP;120 deg Ph 7,311.0 7,329.0 6,481.4 6,495.7 A-4,1G-01 8/30/1982 12.0 (PERF Geo Vann TCP;120 deg INJECTION;6,926.8 Ph III 7,346.0 7,362.0 6,509.3 6,522.1 A-3,1G-01 8/2/1993 4.0 APERF 28 deg CCW Mandrel Inserts St ati C _ o^ Top(ND) Valve Latch Port Size TRO Run 0 IPERF;6,970.0-7,019.0- No Top(ftKB) (ftKB) Make Model OD Sery (in) Type Type (in) (psi) Run Date In Notes:General&Safety • End Date Annotation 5/3/2006 NOTE:E-LINE(PROF IDENTIFIED C-SAND LEAK @ 7051' IPERF;7,063.0-7,104.0--T 8/26/2008 NOTE:WAIVERED WELL TxIA COMMUNICATION - 9/15/2010 NOTE:View Schematic w/Alaska Schematic9.0 1 NIPPLE;7,153.6 SLEEVE-C;7,153.61 , ■■! I SEAL ASSY;7,187.4 mos .A%r. PACKER;7,188.6 NIPPLE;7,207.4 b I SOS;7,219.0 IPERF;7,297.0-7,301.0- I PERF;7,311.0-7,329.0 APERF;7,346.0-7,362.0- PRODUCTION;26.7-7,956.9-4 • • • Schwartz, Guy L (DOA) From: Schwartz,Guy L(DOA) Sent: Monday,April 24,2017 3:00 PM To: NSK Well Integrity Field Supv Cc: NSK Well Integrity Supv CPF1 and 2; Loepp,Victoria T(DOA) Subject: RE: [EXTERNAL] 1G-01 PTD182-130 request for a verbal permission Roger, You have verbal approval to proceed with Conductor removal and surface casing repair as outlined in the submitted sundry. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From: NSK Well Integrity Field Supv[mailto:N1927@conocophillips.com] Sent: Monday,April 24,2017 2:57 PM To:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov> Cc: NSK Well Integrity Supv CPF1 and 2<n1617@conocophillips.com> Subject: RE: [EXTERNAL] 1G-01 PTD182-130 request for a verbal permission Mr.Schwartz, COP request a verbal for continued operations of conductor removal on 1G-01 as requested in the 10-403 sundry that was submitted previously. Respectfully, Roger Mouser/Roger Winter CPAI WI Field supervisor Office(907)659-7506 Cell (907)943-1055 N1927@ COP.com From:Schwartz,Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Monday,April 24,2017 2:49 PM To: NSK Well Integrity Field Supv<N1927@conocophillips.com> Subject: [EXTERNAL] email Guy Schwartz Sr. Petroleum Engineer AOGCC 1 • • Bettis, Patricia K (DOA) From: NSK Well Integrity Field Supv <N1927@conocophillips.com> Sent: Monday, April 17, 2017 4:44 PM To: Bettis, Patricia K(DOA) Subject: RE: KRU 1G-01 (PTD 182-130): Sundry Application Attachments: 1G-01 10-403 Conductor&SC repair 04-12-17.xls One more time total depth ND 7002',eff MD 7295, eff TVD 6468. Sorry had to merge across to get ND to pop up. From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent: Monday,April 17,2017 2:44 PM To: NSK Well Integrity Field Supv<N1927@conocophillips.com> Subject: [EXTERNAL]KRU 1G-01 (PTD 182-130):Sundry Application Good afternoon Roger, On Form 10-403, Box 11,total depth ND, and effective depth (both MD and ND)were not provided. Please provide this information as soon as possible. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Ave.,Ste 100 Anchorage,AK 99501 Tel: (907)793-1238 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Monday, April 17, 2017 2:44 PM To: N1927@conocophillips.com Subject: KRU 1G-01 (PTD 182-130): Sundry Application Good afternoon Roger, On Form 10-403, Box 11,total depth ND, and effective depth (both MD and ND)were not provided. Please provide this information as soon as possible. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Ste 100 Anchorage,AK 99501 Tel: (907)793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Friday, December 30, 2016 9:19 AM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler Subject: 1G-01 Report of split conductor (PTD 182-130, AIO 2B.035) 12-30-16 Attachments: 1G-01 schematic.pdf; MIT KRU 1G-01 Diagnostic MITOA 6-22-16.xls; 1G-01 90 day TIO 12-30-16.PNG Chris, Yesterday, while performing a preventative maintenance outer casing packoff test on 1G-01 (PTD 182-130,AIO 2B.035), a split in the burst seam of the sealed conductor was identified. There was a minor spill into the gravel cellar, estimated currently to be less than a gallon of hydraulic fluid. The lower seal in the packoff was compromised, allowing the hydraulic fluid used during the packoff test to migrate over to the OOA and out the split conductor. The test pressure only got to"50psi when the leak was identified, leading to the belief that the split was present prior to the testing yesterday. The burst seam is designed to release at"'650psi. It is unclear how the damage to the conductor occurred. After the incident,the OC-LDS's were discovered to be very loose and were retorqued. However because we did not want to potentially contribute to the size of the spill if the repair of the seal was unsuccessful, we decided to postpone a followup packoff test till the well can be secured and spill containment is laid down. The well was shut in and freeze protected yesterday. A downhole tbg plug will be set and investigation into the extent of the damage to the conductor will be pursued via excavation. DHD will be performing a followup outer casing packoff test and MITOA, as well as MITIA to confirm barriers. The OA was holding 440psi yesterday so communication across from the OA to the sealed conductor is not suspected at this time. There was a passing MITOA performed on 6-22-16 and a witnessed MITIA on 6-21-16. A path forward will be determined based on the diagnostics and proper paperwork submitted prior to returning the well to injection. The well is currently AA'd for TxIA communication. Please let me know if you disagree with path forward. Attached is the schematic, 90 day TIO trend plot and MIT data for the MITOA performed on 6-22-16. Kelly Lyons/Brent Rogers -r=l: :crn-�.�...... _ mow ,. Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Mobile Phone (907) 943-0170 SCANNED JAN 1 82017 1 w Ill14 ••• ¢ Zn 1.7 If Q V N W cr a 0 o ,n w VS CC x 0- —a. o u, `w E. crl - w CC a Ck I- u.l w 1- Q I J J w O G O O O 0 43e P �0 rt O h CV O O O O • to •-a r-. (n ,n r- r- 1 I I I I 1 c --' r kri i T CI o W o 6 4) 0 o ', V C , 0) co i0 i '3 oo a z ,G u C -o 3 !, '.7 z z m V r m O _ E �� 0 0 , U! .t C U Na.,Z w w ,O U0 : O O Q O L Q. a R; S0 IIIII Un CU III to• 0 ..0 0 0 0 0 o N L. :• :. t 1 Y ,. m t+ N " C.1 d y T Show Isd MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Tuesday,June 28,2016 Jim Regg '� P.I.Supervisor '' 7�'bf1j SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1G-01 FROM: Johnnie Hill KUPARUK RIV UNIT IG-01 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1G-01 API Well Number 50-029-20805-00-00 Inspector Name: Johnnie Hill Permit Number: 182-130-0 Inspection Date: 6/21/2016 Insp Num: mitJWH160627110542 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1G-01 , ;Type Inj W'TVD 6136 - Tubing 1243 1237 " 1240 . 1240 - PTD 1821300 " Type Test SPT Test psi 3000 ✓ IA 425 3300 , 3210 - 3190. Interval 'REQVAR P/F P OA 290 480 - 475 - 470 - Notes: MITIA per AIO 2B0.35 to max anticipated injection psi 4.3bbls diesel used SCANS NOV 2 2 2010 Tuesday,June 28,2016 Page 1 of 1 Ima~-~roject Well History File. C°verlge XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. / ~"C~__ - Z/c-~ _~) Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. ' [] Maps: [] Grayscale items: [] Other. No/Type [] Other items scannable by large scanner [] Poor Quality Originals: -.. OVERSIZED (Non-Scannable) [] Other: ~, NOTES: [3 Logs.of various kinds [] Other BY: BEVERLY BREN VINCENT(~ MARIA LOWELL DATEZ-~ ~SI Scanning Preparation '_ 'x 30 = . + _ = TOTAL PAGES ~ ISl ~ ~' . , ~ . Production Scanning ~ ~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~ YES ~ NO Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO ( ~NNING IS COMPLETE AT THI~ POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVlOUAL PAGE BASIS ReScanned(individualpage[spec/a/atten,ion]scanningcomp,e,ed) IIIIIIIIIIIIIIIIlll RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is/ General Notes or Comments about this file: Quality Checked (done) 10/25/02Rev3NOTScanned.wpd • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, January 23, 2013 TO: Jim Regg P.I. Supervisor i'2 " (j SUBJECT: Mechanical Integrity Tests 1 CONOCOPHILLIPS ALASKA INC 10-01 FROM: Chuck Scheve KUPARUK RIV UNIT 1G -01 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON - CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT IG -Ol API Well Number 50- 029 - 20805 -00 -00 Inspector Name: Chuck Scheve Permit Number: 182 -130 -0 Inspection Date: 1/17/2013 Insp Num: mitCS130121114605 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min ' Welly 10-01 T eIn � - -- � IA 2920 ; YP J 2920 182 1300 1 Type Tes SPT 2 9 0 0 120 0 ' — — - ' TVD I .� 160 160. ; �V " ; 260 2980 i PTD ,Tes si � 2900 OA 120 160 ' nter I val 1050 1050 loco loco REQVAR - P/F P / i Tubin Notes: 2 year MIT per AA2B.035 SCANNED APR 11 2013 Wednesday, January 23, 2013 Page 1 of 1 t3o • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. June 5, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Plug Setting Record: 1G-01 Run Date: 6/4/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1G-01 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 20805 -00 SCANNED APR 11 2013 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO I.I•IE; ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907-273-3535 klinton.wood@halliburton.com Date: `1 ti 2 Signed: ) 1 • 2G2. I6 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. March 5, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 SCANNED APR 11 2010 RE: Injection Profile: 1G-01 Run Date: 2/21/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1G-01 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50- 029 - 20805 -00 Injection Profile Log 1 Color Log 50- 029 - 20805 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com $ 4 .44 Date: 3 2 / 12, Signed: 1 5 d3zeeia- . • -v? 10. 1 G -01 — AA 2B.035 issued 7/30/2008. 9. 1 F -16A — Well name is 1 F -16A. IA DD failed 4/12/2007, but MITs are listed to have passed since. Well last injected 4/2007. AA 2B.018 was issued in October 2007, but no injection has occurred into the well. Looking at the pressure plot, it is shown that the IA pressure appears to have been bled off in October and November. Was there well work conducted, maybe plug setting? There is email traffic exchanged regarding "what if" for an OA pressure sensor. Such have been installed on other wells, is that possible here? What are the plans for the well? 8. 1D-40A—Well name is 1D-40A. MITIA failed - 10/1/2009. Well last injected 9/09. 7. 1D-119 — Single casing well. MITIA failed 7/16/2010. Well last injected 6/2010. 6. 1 D -106 — Single casing well. MITIA failed 7/16/2010. Well last injected 6/2010. Comments on the sheet indicate you have located the deep leak. 5. 1C-133 — Single casing well. MITIA failed 5/21/2010. Well last injected 5/2010. 4. 1C-10 — AA 2B.036 issued 8/25/2008. From: Maunder, Thomas E (DOA) Sent: Monday, January 03, 2011 11:13 AM SLANNED JAN 2 0 2011 To: 'NSK Problem Well Supv' Cc: NSK Well Integrity Proj Subject: RE: ConocoPhillips Monthly Injector Report - Dec 2010 Martin, et al, I am conducting a review of December's Monthly report. I have just gotten started and wanted to pass back the comments /questions I am developing. I also am doing some editing /formatting on the spreadsheet to facilitate printing it off when necessary. I have only edited the 1A -07, 1A -12 and 1B-02 in the attached spreadsheet. The edits are highlighted in yellow. Can these changes be accommodated without a lot of hassle ?? Thanks in advance for looking at this. Tom Maunder, PE AOGCC 3. 1 B -02 — TxIA communication reported 5/6/09. Well last operated 6/09. 2. 1A-12 — AA 2B.049 issued 6/9/2010. 1. 1A -07 — It is noted that an MITIA failed on 11/13/09, however I have not been able to find that information in our files. I have an email from July 28,2009 that reports failure of a diagnostic MITIA, that the well will be SI, added to the monthly report and diagnostic troubleshooting will begin as soon as feasibly possible. On December 15, 2009 it was reported that a surface casing leak was suspected and that the well is SI and on the monthly report. According to our injection records, the well has not operated since April, 2008. From: NSK Problem Well Supv [mailto:n1617 @conocophillips.com] Sent: Saturday, January 01, 2011 10:55 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: ConocoPhillips Monthly Injector Report - Dec 2010 • The following nformation is received monthly from CPAI. Reporting this information is a 9 Y P 9 requirement continued injection/operation of uirement of the administrative approval issued that authorizes co t q Pp 1 p the well where some integrity compromise is known. As of December, 2010 a total of 65 wells are on this report. Not all wells are actively injecting. From: NSK Problem Well Supv [mailto:n1617 @conocophillips.com] Sent: Saturday, January 01, 2011 10:55 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: ConocoPhillips Monthly Injector Report - Dec 2010 Jim/Tom /Guy, Attached for your records is the ConocoPhillips monthly injector report for December 2010. Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907 - 659 -7224 Cell 907 - 943 -1720 / 1999 Pager 907 - 659 -7000 #909 0 0 ConocoPhillips Well 1G-01 Injection Data • Water Injection 0 Gas Injection I 4000 3500 3000 2500 - a a: 2000 1500 1000 0 ii " • i A " all A 500 0 ♦ A• 0 2000 4000 6000 8000 10000 12000 Injection Rate, bwpd or mscfpd Date of Water Gas Injected Tubing IA Pressure OA Pressure Injection Injected (mscfpd) Pressure (psi) (psi) (bwpd) (psi) 31- Dec -10 4931 0 731 1200 150 30- Dec -10 4278 0 634 1200 150 29- Dec -10 4467 0 653 1200 150 28- Dec -10 4827 0 686 1200 150 27- Dec -10 4108 0 627 1200 150 26- Dec -10 4750 0 688 1200 150 25- Dec -10 4629 0 587 1200 150 24- Dec -10 4340 0 543 1350 250 23- Dec -10 4441 0 551 1350 250 22- Dec -10 5046 0 629 1350 250 21- Dec -10 4556 0 560 1400 300 20- Dec -10 5087 0 621 1250 200 I 19- Dec -10 7219 0 820 1250 200 18- Dec -10 7961 0 831 1250 200 17- Dec -10 4973 0 499 1150 200 16- Dec -10 3652 0 384 1150 200 15- Dec -10 5485 0 510 1350 300 14- Dec -10 3885 0 415 1150 100 13- Dec -10 5607 0 582 1150 100 12- Dec -10 1731 0 162 1150 100 11- Dec -10 2202 0 198 1150 100 10- Dec -10 3218 0 301 1150 100 9- Dec -10 3541 0 351 1150 100 8- Dec -10 3773 0 390 1200 100 7- Dec -10 3909 0 415 1150 100 6- Dec -10 3781 0 418 1200 150 5- Dec -10 3756 0 408 1200 150 0 • 4- Dec -10 3445 0 334 1250 200 3- Dec -10 3527 0 349 1250 200 2- Dec -10 3790 0 376 1250 200 1- Dec -10 3985 0 410 1250 200 30- Nov -10 3938 0 389 1200 150 29- Nov -10 4076 0 418 1200 150 28- Nov -10 3630 0 322 1000 200 27- Nov -10 3263 0 274 1300 200 26- Nov -10 3625 0 345 1300 200 25- Nov -10 3836 0 376 1300 200 24- Nov -10 4123 0 425 1300 200 23- Nov -10 4112 0 403 1300 200 22- Nov -10 4169 0 413 1300 200 21- Nov -10 4067 0 380 950 100 20- Nov -10 2365 0 82 950 100 19- Nov -10 2033 0 21 1000 60 18- Nov -10 7343 0 804 1700 250 17- Nov -10 7547 0 815 1700 250 16- Nov -10 7837 0 824 1700 250 15- Nov -10 7543 0 841 1700 250 14- Nov -10 7877 0 861 1700 250 13- Nov -10 7561 0 815 1600 300 12- Nov -10 6793 0 741 1600 300 11- Nov -10 6844 0 733 1600 300 10- Nov -10 6711 0 704 1600 300 9- Nov -10 6690 0 682 1800 300 8- Nov -10 10522 0 1034 1800 300 7- Nov -10 2843 0 504 400 50 6- Nov -10 0 0 325 400 50 5- Nov -10 0 0 263 400 50 4- Nov -10 0 0 195 400 50 3- Nov -10 0 0 146 400 50 2- Nov -10 0 0 112 400 50 1- Nov -10 0 0 80 400 50 31- Oct -10 0 0 59 400 50 30- Oct -10 0 0 176 400 10 29- Oct -10 0 0 304 400 10 28- Oct -10 0 0 267 400 50 27- Oct -10 0 0 242 400 20 26- Oct -10 0 0 252 400 20 25- Oct -10 0 0 245 400 20 24- Oct -10 0 0 220 400 20 23- Oct -10 0 0 207 400 20 22- Oct -10 0 0 199 400 20 21- Oct -10 0 0 197 400 20 20- Oct -10 0 0 189 400 20 19- Oct -10 0 0 182 400 20 18- Oct -10 0 0 174 400 20 17- Oct -10 0 0 162 400 20 16- Oct -10 0 0 153 400 20 15- Oct -10 0 0 142 400 20 14- Oct -10 0 0 128 400 20 • • 13- Oct -10 0 0 114 400 20 12- Oct -10 0 0 99 400 20 11- Oct -10 0 0 87 400 20 10- Oct -10 0 0 75 400 300 9- Oct -10 0 0 60 400 30 8- Oct -10 0 0 44 400 30 7- Oct -10 0 0 22 400 30 6- Oct -10 0 0 14 400 30 5- Oct -10 0 0 14 450 50 4- Oct -10 0 0 17 450 50 3- Oct -10 0 0 22 450 50 2- Oct -10 0 0 21 450 50 1 • ConocoPhillips Well 1G-01 Injection Data • Tbg Psi • IA Psi • OA Psi l 4000 - 3500 3000 - .°_) 2500 - 0. a 2000 1500 1� r 1000 • ,. • �».. • • 500 • _ • •.•. �• •"' '. • IM �• 09/10 10/10 11/10 12/10 01/11 Date PTD: 1821300 AIO2B.035 issued 7/30/2008 Reason: TxIA communication, IA failed DD test. MITIA Passed. Witnessed MITIA passed 06/25/10 MITOA passed on 06/25/10 AIO 2B.035 - Required Bleed events recorded No pressure bleeds occurred within the last month. • MEMORAND TO: Jim Regg P.I. Suaer~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 30, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1 G-O1 KUPARUK RIV iJNIT 1G-O1 FROM: Bob Noble Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Reviewed By: ~B P.I. Suprv Comm Well Name: KUPARUK RIV UNIT 1G-O1 API Well Number: 50-029-20805-00-00 Inspector Name: Bob Noble Insp Num: mitRCN100628075634 Permit Number: 182-130-0 Inspection Date: 6/25/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ~~ Well 1G-O1 Type In . I N TVD ~ 6136 .- IA 600 -' 2980 2880 2830 ~ 2830 P.T.D 1821300 TypeTBSt , SPT 'l'est pSl 2980 OA 40 10 l0 70 10 ---- --- Interval REQvAR p/F P .~ Tubing ~ loo ]oo loo loo_ Notes: Ian wanted to hold this an extra 1 S^fn becouse the second 15 min lost 50% of the first 15 min. ~~~ ~Q % ~ ~~ t S~~ i ~;. ~~~~~~ $.,~ : 1~ ~1 11 . ti .., . . .. .... ti Wednesday, June 30, 2010 Page 1 of 1 1 • 0F 1 A 1 t . (. 1 1 1 t ( l SARAH PALIN, GOVERNOR _: 1 1 t i \_ c_._ !'"t ALASKA OIL AND GAS 333 W. 7th AVENUE. SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 98501 -3539 PHONE (807) 278 -1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL AIO 2B.035 Ms. MJ Loveland Well Integrity Project Supervisor 9k/ANNED JAN 2 0 201i ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 -0360 RE: KRU 1G -01 (PTD 1821300) Request for Administrative Approval Kuparuk River Oil Pool Dear Ms. Loveland: In accordance with Rule 9 of Area Injection Order ( "AIO ") 02B.000, the Alaska Oil and Gas Conservation Commission ( "AOGCC" or "Commission ") hereby grants ConocoPhillips Alaska Inc. ( "CPAI ")'s request for administrative approval to continue water injection in the subject well. Kuparuk River Unit ( "KRU ") 1G-01 exhibits tubing by inner annulus communication. Despite passing all positive pressure diagnostic tests the well exhibits inner annulus re- pressurization following pressure bleeds. The Commission finds that CPAI does not intend to perform repairs at this time, deferring until the location of pressure communication can be determined. Reported results of CPAI's diagnostic procedures and wellhead pressure trend plots indicate that KRU 1G-01 exhibits at least two competent barriers to the release of well pressure. CPAI requested the Commission approve inner annulus pressure equal to injection pressure of 2500 psi, which is approximately 50 percent of the production casing's minimum internal yield pressure rating. Should the well develop communication to the outer annulus, the 2500 psi injection pressure would represent 70 percent of the surface casing's minimum internal yield pressure rating. Data provided by CPAI indicates infrequent excursions of inner annulus pressures above 2000 psi, and those have been successfully managed with pressure bleeds. Restricting inner annulus pressure to 2000 psi and outer annulus pressure to 1000 psi in conjunction with daily pressure monitoring provides CPAI with the opportunity to continue injecting in KRU 1G-01 without requiring automatic well shut -in equipment linked to the well's outer annulus pressure. With such in place, the Commission believes that the well's condition would not compromise overall well integrity so as to threaten human safety or the environment. AOGCC's administrative approval to continue water injection only in KRU 1G-01 is conditioned upon the following: 1. CPAI shall record wellhead pressures and injection rate daily; AIO 2B.035 • July 30, 2008 Page 2 of 2 2. CPAI shall submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli; 3. CPAI shall limit inner annulus pressure to 2000 psi and outer annulus pressure to 1000 psi; 4. CPAI shall perform an MIT -IA every 2 years to the maximum anticipated injection pressure; 5. CPAI shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; 6. After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; and 7. The MIT anniversary date is June 28, 2008. ' I DONE at Anchorage, Alaska and dated July 30, 2008. N 1 t ftJL 4 Daniel T. Seamount, Jr. . N • rm • Chairman m - toner RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration of the matter determined by it. lithe notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date an which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), " (t]he questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. • Regg, James B (DOA) From: Sent: To: Cc: NSK Problem Well Supv [n1617@conocophillips.com) Monday, July 21, 2008 6:37 PM Regg, James B (DOA) ra~c 1 Ul G • ` v ~ ~ /~~/ Maunder, Thomas E (DOA); NSK Well Integrity Proj; NSK Problem Well Supv; Downey, Allison; Allsup-Drake, Sharon K; Charyna, Alexander Z (GSI); McMains, Stephen E (DOA) Subject: RE: KRU 3N-12 and KRU 1 G-01 Admin Approval Requests Jim, The preliminary answers to your questions are provided below in red font. Please contact me at your convenience if you have questions or comments. Martin Martin Waiters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 t 1999 Pager 907-659-7000 #909 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Tuesday, July 15, 2008 5:09 PM To: NSK Problem Well Supv Cc: Maunder, Thomas E (DOA) Subject: KRU 3N-12 and KRU 1G-O1 Admin Approval Requests KRU 3N-12 - noticed the request included a provision for CPAI to install auto well shut in capability on OA; what is the reason for 90 day timeline for installation? (past approvals have required installation within 30 days) The 90 day timeline is to give us same flexibility around current activity level and parts availability. CPF3 started a plant turnaround on July 14th which is scheduled to end on August 30th. The parts have not been ordered yet and are considered long {cad items with at least a 30 day delivery time. The well is currently shut-in and will likely remain so after August 30th until the OA HPP and accessories can be installed unless more than a 30 day grace period is granted. KRU 1 G-01 - request is for T and IA pressures to equalize, but that has rarely occurred in the past 2 years; since December 2007 the IA has been significantly higher than tubing and the increase in IA pressure appears to be coincident to a sharp decrease in injection pressure; do you anticipate operating at the higher injection pressure (between 2000 and 2500 psi as done in 2007)? Why the significantly increased injection rate since beginning of 2008? The 1 G- 01 records indicate that the Weil was shut-in from March 14, 2007 anti( December 5th, 2007. As a result of being shut-in, pressure data during this time does not accurately reflect actual well performance due to the wellhead pressure transducer being isolated from the wellhead and in communication with the injection header. The significant increase in injection rate in December 2007 occurred when the well was returned to injection. In the course of investigating this well, I also discovered some SetCim inconsistencies between wells regarding the capturing and display of injection header and wellhead press~.~res. i am working with our Automation Group to understand the nature of the issue and a solution. At this time I believe this is the cause of the anomaly in reported injection pressures that occ€.~rred when we comrerted to a ne:nr method of generating the Monthly i=ailed MIT report. - we will need a 10-404 to cancel sundry 9-659. A thorough search of well records at Kuparui< and Anchorage revealed no sign of Sundry 9-659 for 1 G-01, Please forward a copy of the sundry to me so that (can adequately 7/22/2008 ra~c ~ ci ~ • • address your request. Assurning apprapriate; the 'I0-404 vviil ce fort;-iooming upon AA approve'. ~ . - attached is the injection volume comparison I mentioned by phone today -note highlighted discrepancies between your SetSim Data and what has been officially provided to the Commission in monthly injection report (Form 10-406). Gue to the 1 G-01 being shut-in for the entire months of April through November 2007, the data during this time should refilect no water injection. The CPAI Accounting Group reviewed the submitted 10-406 text files and !reviewed the submitted Monthly Failed MIT Reports and both appear to match the "RBDMS Water" column in the attached rile. This also includes the slight variation in March 2008. With the data I have access to, i cannot explain how you acquired the "CPAI Water" numbers. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 7/22/2008 • • I?" 4 ConocoP JUL 0 3 2008 Alaska A P.O. BOX 100360 l s,� cif ,ons. Commission ANCHORAGE, ALASKA 99510 -0360 Ar c June 30, 2008 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 SINNED JAN 20201 Dear Mr. Maunder: ConocoPhillips Alaska, Inc. presents the attached proposal as per AIO 2B, Rule 9, to apply for Administrative Approval to allow well 1G -01 (PTD 182 -130) to remain in water injection service with tubing by inner annulus communication. If you need additional information, please contact Perry Klein or me at 659 -7043 or Brent Rogers / Martin Walters at 659 -7224. Sincerely, G j, � zi'" MJ L veland Well Integrity Project Supervisor ConocoPhillips Alaska Inc. Attachments • • ConocoPhillips Alaska, Inc. Kuparuk Well 1G -01 (PTD 1821300) Technical Justification for Administrative Relief Request Purpose v this Administrative Relief that the AOGCC approve t ConocoPhillips Alaska, Inc. proposes pp ro request as per Area Injection Order 2B, Rule 9, to continue injection with known annular communication for Kuparuk injection well 1G -01. Well History and Status Kuparuk River Unit well 1G -01 (PTD 1821300) was drilled and completed in 1982 as a development well and converted to an injection well in 1993 1G -01 was reported to the Commission on 02/18/07 and most recently again on 06/29/08 as showing intermittent signs of T x IA communication. All positive pressure diagnostics continue to pass integrity testing, as well as 30 minute drawdown tests, however the IA pressures up above 2000 psi over several days after being bled (See attached TIO plot). There is no recordable leak rate so the exact location of the communication is not detectable. The well passed a diagnostic MITIA to 3000 psi and an MITOA to 1800 psi on 06/28/08 and 06/29/08 respectively. This well has been monitored internally by ConocoPhillips and the AOGCC since the initial report to the Commission in early 2007. In late 2007 the intermittent leak stopped and the well was returned to normal status by both ConocoPhillips and the AOGCC. Since that time the slow leak has resumed and now requires an AA to be in strict compliance with AIO 2B. ConocoPhillips intends to pursue repairs if the leak worsens enough to be detectable and located. However, until the leak is detectable, ConocoPhillips requests an AA which will allow the IA to equalize with the tubing in water only injection service at a pressure not to exceed header pressure which is approximately 2500 psi. Barrier and Hazard Evaluation Tubing: The 3 1/2" 9.3# J -55 tubing has integrity to the packer @ 6880' MD, based on passing MITIA to 3000 psi on 6/29/08. Production casing: The 7" 26# J -55 production casing has integrity to the packer @ 6880' MD based on the passing MITIA test outlined above. Surface casing: The well is completed with 10 3/4" 45.5# J -55 surface casing with an internal yield pressure rating of 3580 psi. The surface casing is set at 2238' MD (2238' TVD). A passing MITOA to 1800 psi was performed on 06/29/08. Primary barrier: The primary barrier to prevent a release from the well and provide zonal isolation is the tubing and packer as it passes all mechanical integrity testing. Second barrier: The production casing is the secondary barrier and also passes all mechanical integrity testing. Third barrier: The surface casing and cement shoe will act as a third barrier in the unlikely event that the first two barriers both fail. Monitoring: Each well is monitored daily for wellhead pressure changes. Should leaks develop in the tubing or production casing above the surface casing shoe it will be noted during the daily Well Integrity Supervisor 7/1/2008 1 • • monitoring process. Any deviations from approved MAOP annular pressures require investigation and corrective action, up to and including a shut -in of the well. T /IO plots are compiled, reviewed, and submitted to the AOGCC for review on a monthly basis. SVS: ConocoPhillips considers the tubing and production casing sound barriers and does not believe automatic well shut -in equipment on the well's outer annulus is warranted. However, n the unlikely event that the production casing fails, the surface casing would be subjected to less than 70% of the casing's minimum yield strength (as per AIO2B Rule 4). The normal injection header pressure for this well is —2500 psi and the surface casing burst pressure is 3580 psi. Proposed Operating and Monitoring Plan 1. Well will be used for water injection only (no gas or MI allowed), IA pressure may equalize with injection pressure; 2. Perform a passing MITIA every 2 -years as per AOGCC criteria (0.25 x TVD @ packer, 1500 psi minimum); 3. Perform a passing MITOA every 2 years to 1800 psi; 4. IA pressure not to exceed 2500 psi & OA pressure not to exceed 1000 psi. 5. Submit monthly reports of daily tubing & IA pressures and injection volumes; 6. Shut -in the well should MIT's or injection rates and pressures indicate further problems with appropriate notification to the AOGCC. Well Integrity Supervisor 7/1/2008 2 CHOKE FTP FTT IAP Tll/O Plot - 1G-01 OAP , 200 - I - 2000 = 1� 1 _ ,�1 150 f ry �r.� i �~ • �� ~' , - o. 1500 = 1, 1 I t II - 4) t = - 100 1000 50 500 - -,, V-/\[\-- ,-, 0 -- I I I t I t I I I I f 0 01- Apr -08 01- May -08 01- Jun -08 Date • • -e-‘ ConocoPhillips Alaska, Inc. KRU 1 G -01 1G-01 T - API: 500292080500 Well Type: INJ Angle @ TS: 36 deg 0 6969 ■ SSSV Type: TRDP Orig 8/30/1982 Angle @ TO: 38 deg @ 7970 sssv — - -� Annular Fluid: Completion: (1 179 Last W /O: 8/2/1993 Rev Reason: PULL WRP 0 Reference Log: Ref Log Date: Last Update: 6/16/2007 Last Tag_ 7316' RKB TD: 7970 ftKB _ Last Tap Date: 5/4/2007 Max Hole Angle 45 deg @ 4700 Calling String - ALL STRI _ �aS __ Description Size Top Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 80 80 62.50 H -40 SUR. CASING 10.750 0 2238 2238 45.50 K -55 PROD. CASING 7.000 0 7956 6991 26.00 K -55 Tubing String - TUBING - Size Top Bottom � TVD Wt - -T Grade Thread 3.500 0 6889 6143 9.30 J -55 BTC -MOD 3.500 6889 7197 6391 9.30 L -80 EUE -8RD 2.875 7197 7220 6409 6.50 L -80 librf orations Summary interval _ TVD Zone Status Ft SPF Date Type Comment 6970 - 7019 6209 - 6248 C -4,C -3 49 12 8/30/1982 IPERF Geo Vann TCP; 120 deg Ph 7063 - 7104 6284 - 6316 C -1 _ 41 _ 12 8/30/1982 IPERF Geo Vann TCP; 120 deg Ph PBR 7297 - 7301 _ 6470 - 6473 A -5 4 12 8/30/1982 IPERF Geo Vann TCP; 120 deg Ph (6867 - 6868, 7311 - 7329 6481 - 6496 _ A-4 18 12 8/30/1982 IPERF Geo Vann TCP; 120 deg Ph 00:5.625) 7346 - 7362 6509 - 6522 A-3 16 4 8/2/1993 APERF 28 deg CCW Ilbs Lift Mandrels/Valves St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run VIv PKR Cmnt (6880 1 2959 2957 Camco KBUG DMY 1.0 BK 0.000 0 11/20/1993 00:5.938) 2 4565 4360 Camco KBUG DMY 1.0 BK5 0.000 0 8/2/1993 3 6817 6085 Camco MMG -2 , DMY 1.5 RK 0.000 0 8/17/1993 Injection Mandrels/Valves St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run VIv Cmnt 4 6927 6174 CamcoTMMG r DMY 1.5 RK 0.000 0 8/2/1993 Closed Other (plugs, eg_ui . etcL . COMPLETION Depth TVD Type Description ID 1789 1789 SSSV Camc0TRDP -1AE 2.813 6867 6126 PBR Camco 2.938 6880 6136 PKR Camco HRP -1 -SP 2.938 7154 6356 NIP AVA PORTED NIPPLE 2.750 7154 6356 SLEEVE -C AVA 2.75" BPI run w /three 3/16" ports, set 7/18/2004 2.310 7187 6383 SBR _ Baker GBH -22 2.406 7189 6384 PKR Baker'D' 3.250 — 7207 _ 6398 NIP Camco' D' Nipple NO GO 2.250 7219 _6408 SOS Baker 2.441 SLEEVE - 7220 6409 TTL - - 2.441 (7154 ) z ' Other (plugs a ui , etc. SLEEVE Depth TVD Type Description ID - 7154 , 6356 SLEEVE -C AVA 2.75" BPI run w /three 3/16' ports, set 7/18/2004 1 2.310 General Notes SBR Date Note (7187 -7188, oD:3.500) 5/3/2006 NOTE: E -LINE IPROF IDENTIFIED C -SAND LEAK 0 7051' PKR (7189 -7190, OD:6.156) NIP (7207 -7208, OD:2.875) TUBING ■ (7197 -7220, OD:2.875, _ 10:2.441) Pert - (7297 -7301) --- Perf — (7311 -7329) Pert - (7346 -7362) i(h (G 2_-- 130 Well Name 1G-01 Notes: End Date 8/1/2008 Days 1000 Start Date 1115/2005 WHP Annular Communicaton Surveillance vii 111E 2500 1 - _ - - OAP _ - - - 150 Injecting in excess WHT of 2000 psi ` 2000 - ' V j 140 1500 I ■ �� i 114. 130 1114 w, o a Ilia . 1 1 0 0 0 I 120 riri ANI I 500 ( _ ��.� 110 ji , Ili 1 lir u_.._. 0 , 100 Jan -06 Jan -07 Jan -08 r } 10000 DGI III 9000 — E'.` MG' MI 8000 — •• E 7000 T. BLPD m s000 - -�--- Well Shut -in for k` _±. f►-* MPli S000 ��giri dzi11i dill i M 4000 > 8 months ME i" r1 ril M 3000 2000 r 1000 1 _ 0 - (( t Jan -06 Jan -07 Jan -08 Date I Data required for upcoming AA Page 1 of 1 i • Regg, James B (DOA) ~ ~ ~2- ~ ~~ From: NSK Problem Well Supv [n1617@conocophillips.com] ~ <j~~ f Sent: Sunday, June 29, 2008 5:42 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Fleckenstein, Robert J (DOA); DOA AOGCC Prudhoe Bay Cc: NSK Problem Well Supv Subject: Data required for upcoming AA Attachments: MIT KRU 1 G-01 06-28-08.x1s; MIT KRU 1 G-01 MITOA 06-29-08.x1s; 1 G-01.pdf; 1 G-01 1 MITIA.png Tom /Jim, Current diagnosti_ c work was performed on~1 G-01 (PTD 182-130 to keep well online in water injection service only. Attached is copy of the MITIA/MITOA, schematic, and 3 month TIO plot. Please let me know if you have any questions. Russ Colee PWS «MIT KRU 1 G-01 06-28-08.x1s» «MIT KRU 1 G-01 MITOA 06-29-08.x1s» «1 G-01.pdf» «1 G-01 MITIA.png» ~~ ~~ ScP 1 ~ 2D08 8/28/2008 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: FIELD /UNIT /PAD DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska, Inc. Kuparuk /KRU / 1G-01 t ~~ 06/28/08 Ives /Bates Packer Depth Pretest Initial 15 Min. 30 Min. Well 1G-01 Type Inj. W TVD 6,136' ubing 1,075 1,075 1,075 1,075 Interval P.T.D. 182-130 Type test P Test psi 1534 Casing 1,675 3,00 2,940 2,940 P/F P Notes: Pre AA MITIA OA 310 390 390 390 OOA 0 0 0 0 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water 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 T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11!27!07 2008-0628 MIT KRU 1G-01.x1s 1G-O1 PTD 182-130 Suspect TxIA Communication Regg, James B (DOA) From: NSK Welt Integrity Proj [N1878@conocophillips.com] Sent: Friday, June 27, 2008 10:55 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSK Problem Wel( Supv; NSK Well Integrity Proj Subject:. 1 G-01 PTD 182-130 Suspect TxIA Communication Attachments: 1G-01 TIO.jpg t/ Jim/Tom, Page 1 of 1 ~~~ A recent review of the 1G-01 (PTD 182-130) TIO trend reveals the return of a very slow but evident TxIA leak that requires approximately 1 bleed per month to maintain a 500 psi TxIA differentia . Current plans include leaving the well online in water injection service only. ~.i Completing a diagnostic MITIA and MITOA. And then applying for an AA for continued water injection service. --- Attached is a 3 month TIO plot. Let me know if you have any questions MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 «1 G-01 TIO.jpg» 8/29/2008 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska, Inc. ~~~ Kuparuk /KRU / 1G-01 06/29/08 Ives /Bates Packer Dep Pretest Initial 15 Min. 30 Min. Well 1G-01 Type Inj. W TVD 6 36' Tubing 1,400 1,400 1,400 1,400 Interval P.T.D. 182-130 Type test P Test psi 1534 Casing 900 950 950 950 P/F P Notes: Pre AA MITOA / OA 650 1800 1760 1750 / OOA 0 0 0 0 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P!F Notes: OA TYPEINJ Codes D =Drilling Waste G=Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test i INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT KRU 1G-01 MITOA 06-29-08.x1s KRU 1 G-01 PTD 182-130 2500 2000 1500 N a 1000 500 0 TlllO Plot -1G-01 ...........h ...................I............'FS.........~....................it5i..............................1....j ...T 01-Apr-08 01-May-08 Date 01-Jun-08 00 150 a E 41 100 m 0 50 0 • • Conocc~Ph~M1~s A[aska, tr~~. 1 G-01 API: 500292080500 Well T e: INJ SSSV Type: TRDP Orig 8/30/1982 sssv Com letion: (17as-nso, -- Annular Fluid: Last W/O: 8/2!1993 OD:3.500) Reference Lo : Ref Lo Date: Last Ta :7316' RKB TD: 7970 ftK6 Last Tag_Date: 5/4/2007 Max Hole Angle: 45 deq Ca) Casing String -ALL STRINGS Description I Size j Top I Bottom PBR (s8s7-s8s8, OD:5.625) PKR (6880-6881, OD:5.938) SLEEVE-C (71sa-71ss, OD:2.750) SBR (7187-7188, OD:3.500) PKR (7189-7190, OD:6.156) NIP (7207-7208, OD:2.875) TUBING (7197-7220, OD:2.875, ID:2.441) Perf (7297-7301) 2.875 7197 722(1 6409 6.50 L-80 Perforations S_umm__ a_ry i IntF>rval i TVII i 7nno i Rtatuc i Ft i RPF i r)ato i Tvno i Cnmmnnt i :grade H-40 K-55 K-55 ThrcaA 3.500 0 6889 6143 9.30 J-55 BTC-MOD 3.500 6889 7197 6391 9.30 L-80 EUE-8RD KRU 1 G-01 -- - --- An le TS: 36 de a) 6969 Angle @ TD: 38 deg @ 7970 I PROD. CASING ~ 7.000 ~ 0 ~ 7956 ~ 6991 ~ 26. Tubing String - TUBING Size To Bottom TVD tMt Grade 6970 - 7019 6209 - 6248 C-4,C-3 49 12 8/30/1982 IPERF Geo Vann TCP' 120 de Ph 7063 - 7104 6284 - 6316 C-1 41 12 8/30/1982 IPERF Geo Vann TCP; 120 de Ph 7297 - 7301 6470 - 6473 A-5 4 12 8/30/1982 IPERF Geo Vann TCP; 120 de Ph 7311 - 7329 6481 - 6496 A-4 18 12 8/30/1982 IPERF Geo Vann TCP; 120 de Ph i i.wo - / 1bZ ~ bbUy - 6bZZ I H-3 I l ti I 4 1 S/'L/l yy3 I H_h'tK_ F I Ltf qeq GGW I Gas Lift MandreisNalves _ St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch __ Port TRO Uate Run Vlv Cmnt 1 2959 2957 Camco KBUG DMY 1.0 BK 0.000 0 11/20!199 2 4565 4360 Camco KBUG DMY 1.0 BK5 0.000 0 8/2/1993 3 6817_ 6085 Camco MMG-2 DMY 1.5 RK 0.000 0 8/17/1993 Injection Mandr elslValv es _ _ St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 4 6927 6174 Camco _MMG _ _ DMY 1.5 RK Q00_0__ 0 8/2/1993 Clos ed Other (plugs, equip., etc .) -COMPLETION _ _ De th TVD T e Descri lion ID 1789 1789 SSSV Camco TRDP-1AE 2.813 6867 6126 PBR Camco 2.938 6880 6136 PKR Camco HRP-I-SP 2.938 7154 6356 NIP AVA PORTED NIPPLE 2.750 7154 6356 SLEEVE-C AVA 2.75" BPI run w/three 3/16" orts, set 7/18/2004 2.310 7187 6383 SBR Baker GBH-22 2.406 7189 6384 PKR Baker'D' 3.250 7207 6398 NIP Camco 'D' Ni le NO GO 2.250 7219 6408 SOS Baker 2.441 7220 -. 6409 _--~ TTL 2.441 Othe~Qlugs, equip., etc.) -SLEEVE De th ND T e Descri lion ID I. 71.54 6356 SLEEVE-C AVA 2.75" BPI run w/three 3/16" ports, set 7/18/2004 2.310 General Notes Date Note __ _. 5/3/2006 NOTE: E-LINE (PROF IDENTIFIED C-SAND LEAK Cal 7051' Perf (7311-7329) Perf (7346-7362) • • Regg, James B (DOA) From: Regg, James B (DOA) i Sent: Wednesday, December 19, 2007 3:24 PM ~~~~:~ \~~,i~4\ To: 'NSK Well Integrity Proj'; Maunder, Thomas E (DOA) Cc: NSK Problem Well Supv Subject: RE: 1G-01, PTD # 182-130, Produced Water Injector We concur that there is no admin approval necessary to continue injecting in this well. You must operate the well in accordance with AIO 2B and the appropriate regulations of 20 AAC 25. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 -----Original Message----- From: NSK Well Integrity Proj [mailto:N1878@conocophiliips.comj Sent: Wednesday, December 19, 2007 9:11 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA} Cc: NSK Problem Well Supv Subject: 1G-01, PTD ## 182-130, Produced Water Injector Jim, 1 ?.. 1G-Ol PTD # 182-130, produced water injector was returned to service x/5/07. The well is not showing signs of annular communication. Recent tubing pressure has averaged 2400 psi. The IA has recently maintained 600 psi without bleeds. At start up the IA was bled from 1500 to 800 psi on the 5th of Dec and again on the 11th of Dec from 2100 to 1700 to release pressure built from thermal expansion. The DHD crew bled the IA from 1600 to 490 psi on the 14 th of Dec while performing a passing draw down test. The ;.% IA pressure has remained stable at 600 psi since the test, see enclosed 90 day TIO plot. 1G-O1, IA-DD Test - passed Initial T/I/O/OOA= 1000/1600/240/0, Bleed down IA (all fluid). T/I/O/OOA= 1000/490/200/0, 15 min. T/I/0/OOA= ~'~ 1000/500/200/0, 30min. T/I/O/OOA= 1000/500/200/0, Final T/I/O/OOA= 1000/500/200/0 CPAI would like to leave the well online, operating the well in accordance with the Area Injection Order and our internal Well Operating Guidelines. We do not feel that it requires an AA to operate at this time but would be willing to carry it on the monthly L` report for a few months if you would like more time to monitor annular pressures. Please advise and let me know if you have any questions. Perry Klein Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7043 Cell Phone (907) 943-1244 • 1G-Ol PTD # 182-130, notice of~tion • Page 1 of 1 Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Wednesday, December 05, 2007 7:29 PM To: Regg, James B {DOA) Cc: NSK Problem Well Supv Subject: 1 G-01 PTD # 182-130, notice of injection Jim, 1 G-01 was placed on injection for a two week test today. T/I/O = 2350/1250/100 We will monitor the well closely and I'll update you in two weeks time or if the well shows any annular communication. Perry Klein Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7043 Cell Phone (907) 943-1244 12/19/2007 1G-O1 PTD # 182-130 ~ Page 1 oft • Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Thursday, November 22, 2007 1:59 PM `v~~C-~ To: Regg, James 8 (DOA); Maunder, Thomas E (DOA)';~~~~ Cc: NSK Well Integrity Proj ~\ Subject: RE: 1G-01 PTD # 182-130 Attachments: MIT KRU 1G-01 05-21-07.x1s Jim, Attached is the MIT form with the two MIT's done in May. Please let me know if there are any more questions. Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Cell Phone (907) 943-1999 Pager {307) 659-7004 pgr. 909 lyl~ 7~i~By~ ~~~ ~ ~ ~~V/ 1/Wr From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Wednesday, November 21, 2007 11:11 AM To: NSK Problem Well Supv; Maunder, Thomas E (DOA) Cc: NSK Well Integrity Proj Subject: RE: iG-Ol PTD # 182-130 You may resume injection in KRU 1G-01 fora 2 week test as outlined below regarding reporting, monitoring, and response to annular communication. We would like to have those MITs done in May 2007 for our files. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Friday, November 09, 2007 8:05 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSK Well Integrity Proj Subject: 1G-01 PTD # 182-130 Jim, 1 G-01 PTD # 182-130, produced water injector, was reported to your office after showing signs of annular communication on 2/18/07. The IA was found equalized with the tubing pressure at 2100 psi. The IA was bled to 1200 psi and found to be equalized with the tubing again in 24 hrs. Tubing pack offs and MITIA were performed and passed on 2!25/07. On 3112/07 the well failed an IA draw down test. A plug was set below the top of the packer at 6900' for further diagnostics. Subsequent MITT, MITIA, and IA draw downs passed on 5/21and 5/22 including a state witnessed MITIA on 7/14/07 CPAI would like permission to resume injection of produced water into 1G-01 for a test period of two weeks. After two 11/23/2007 1 G-0l PTD # 182-130 Page 2 of 2 weeks time CPAI would evaluate an~port results to your office. If the well sho~igns of annular communication during the test period CPAI will cease injection and notify you. At that point CPAI will decide on a path forward possibly, a renewed attempt to determine the original leak point, application for AA, or work over and communicate our plans to you. If the well shows no signs of annular communication during the test period CPAI would like to leave the well on injection indefinitely and will discuss options for that when the test results are reported. Let me know if you have any questions. Perry Klein Problem Well Supervisor office (907) 659-7224 Cell (907) 943-1244 Pager (907) 659-7000 x909 n1617@conocophillips.com 11/23/2007 :~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us; Tom_Maunder@admin.state.ak.us OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk/ KRU / 1 G-01 05/21 /07 Ives - AES ~~ i ~~ ~~~ Packer De th Pretest Initial .Min. 30 Min. Well 1G-01 T e Inj. W TVD 6,136' Tubing 0 2000 1925 1910 Interval p P.T.D. 1821300 T e test P Test si 1534 Casin 775 590 590 590 P/F P Notes: Diagnostic MITT -not state witnesed OA 170 170 170 170 Well 1 G-01 Ty e In'. W TVD 6,136' Tubing 50 360 390 390 Interval p P.T.D. 1821300 Type test P Test si 1534 Casing 355 2000 1945 1925 P/F P Notes: Diagnostic MITIA -not state witnessed done on 05/22/07 OA 170 190 185 185 Well T e Inj. TVD Tubin Interval P.T.D. T petest Test si Casing P/F Notes: OA Well T pe Inj. TVD Tubing Interval P.T.D. T pe test Test psi Casin P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. T e test Test si Casing P/F Notes: OA Well Type lnj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA D =Drilling Waste M =Annulus Monitoring G =Gas P =Standard Pressure Test I =Industrial Wastewater R =Internal Radioactive Tracer Survey N =Not Injecting A =Temperature Anomaly Survey W =Water D =Differential Temperature Test I =Initial Test 4 =Four Year Gycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 9!1!05 MIT KRU 1G-01 05-21-07.x1s MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: ~~S~~~iW' Rtfr 7/3i:{o7 DATE: Friday, July 20, 2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC FROM: Bob Noble Petroleum Inspector IG-OI KUPARUK RIV UNIT 1 G-OI \W00 Reviewed By: P.l. Suprx i7;?{"..:..- Comm Src: Inspector NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT !G-OI Insp Num: mitRCN070714191658 ReI Insp Num: API Well Number: 50-029-20805-00-00 Permit Number: 182-130-0 Inspector Name: Bob Noble Inspection Date: 7/14/2007 160 Initial 15 Min. 30 Min. 45 Min. ! -¡----- I __~ 1690 I 1690 I i 180 i 180 ! 180 I ! +- I 350 i 350 ! 350 I 60 Min. Packer Well IG-OI ¡Type Inj. I N ¡ TVD P.T.D! 1821300 iTypeTest i SPT! Test psi Interval 4YRTST P/F' P Depth ./ 6136 ./! IA : 1720 i OA I /' T b· i U mg¡ Pretest 430 -- 400 - Notes: I feel the tubing pressure dropped at the start becouse they had to pump open the SSSV, as the well was SI. 5CANNED AUG 0 6 Z007 Friday, July 20, 2007 Page I of I FW: 10-01 PTD # 182-130 Suspect T x 1A communication . . Jim, The Drill site operator went back through the paper copies of the field notes for the Jan 05 bleed events and confirmed there was an error in the entered data. The IA was bled from 2000 to 1100psi as is shown and the OA was bled ~ from 1100 to 400 psi. We will correct the bleed log to reflect the above numbers. Sorry for the confusion. Let me know if you have any other questions. Perry Klein Problem Well Supervisor office (907) 659-7224 Cell (907) 943-1244 Pager (907) 659-7000 x909 n16-] 11. corn SCANNED MAR 2 7 2007 -----Original Message----- From: NSK Problem Well Supv Sent: Thursday, March 08, 2007 4:48 PM To: I James Regg I Subject: RE: 18-01 PTD # 182-130 Suspect T x IA communicati'OI1 --'...... Jim, The OA starting pressure of 2000 psi appears to be a typo. The actual bleed date is Jan,05,2007 not May 13th 2006. The way the tabulated data is lined up in this e-mail makes it somewhat confusing. The operator bled both the IA and the OA on the 5th of Jan. They have entered that the starting pressure on the IA and OA were at 2000 psi and indicate that the annuli were both bled to 1100 psi. I suspect that the mistake was simply a double entry of the IA bleed, labeling it as an OA. Our historic Setcim data shows the OA pressure dropping from 1078 psi to 455 psi on that day. The highest OA pressure recorded is 1078 psi over the 6 months of data that I can access. I will talk with the operator and confirm the Setcim values against the paper copies of their well walk reports and get back to you. Perry Klein Problem Well Supervisor office (907) 659-7224 Cell (907) 943-1244 Pager (907) 659-7000 x909 n161 11. corn 10f4 3/16/20072:39 PM FW: 10-01 PTD # 182-130 Suspect T x IA communication . . -----Original Message----- From: James Regg [mailto:jim re;;a@adrni_rl.:_~ate__ak____lJ~] Sent: Wednesday, March 07, 2007 11:37 AM To: NSK Problem Well Supv Subject: Re: 1G-01 PTD # 182-130 Suspect T x IA communication is outer annulus pressure (2000psi) on May 13, 2006 a typo? Jim Regg AOGCC NSK Problem Well Supv wrote: Jim, In response to questions regarding bleeds and an update of diagnostic testing: Yes, the increasing pressure with thermally stable conditions is a symptom of pressure communication. The drill site operator bleed log for 1G-01 is as follows: 05-MAR-07 20:56 Well Annulus Test Report DS WL TIME DURATION STR-PRES END-PRES DIF-PRES CASING SERVICE MATERIAL COMMENTS 1G 01 25-FEB-07 20:00: +000:00 2290 1050 1240 INNER PWI diesel by DHD post MITIA 1G 01 16-FEB-07 17:25: +000:05 2100 1200 900 INNER PWI gas/liqu 1G 01 04-FEB-07 12:01: +000:06 1750 1450 300 INNER PWI Gas/Liq 1G 01 26-JAN-07 14:58: +000:10 2250 1550 700 INNER PWI gas/liqu 1G 01 05-JAN-07 04:53: +000:12 2000 1100 900 INNER PWI GAS 1G 01 05-JAN-07 04:53: +000:12 2000 1100 900 OUTER PWI GAS 1G 01 13-MAY-06 15:18: +000:10 1000 600 400 OUTER PWI gas 1G 01 13-MAY-06 14:32: +000:10 1800 1300 500 INNER PWI diesel 500# rule w Cfirr ~S"~ ¿ ~~¡ , '. 5\:'-, ttlCOf $, '1 ~ 4o<f:>; 3e~$' ~11~Þ7 The two bleeds subsequent to Jan 15 were about 10 days apart before the IA repressured within 24 hrs of being bled on 2/16 and reported to AOGCC. Most bleeds are via a hose into an adjacent flowline to avoid venting gas to the atmosphere, so it is difficult to determine the exact volume and material bled. The bleed log notes the estimated bleed material and the volume is inferred by the duration of the bleed. Most of the bleeds listed in the table are 5 to 10 mins, suggesting a low volume. Preliminary diagnostics were completed on 2/25/07. The tbg packoffs failed a positive pressure test. The tbg lockdown screws were loose and torqued to 450 ft-lbs. The tbg packoff passed a subsequent positive pressure test. An MITIA passed. Pre test pressures were T/I/0=1900/2290/240. The IA was pressure up with 1 bbl of diesel to 3000 psi for initial T/I/0=1900/3000/240. 15 min T/I/0=1900/2960/240, 30 min T/I/0=1900/2960/240, for a total loss of 40 psi during test. Bled IA down to 1050 psi. Monitored WHP's for 15 min. Final T/I/0=1900/1370/160. On 2/28/07 the IA had repressured to 2250 psi. 20f4 3/16/20072:39 PM FW: 10-01 PTD # 182-130 Suspect T x IA communication . . It appears the well has a slow one-way leak typical of a tbg collar thread leak, packer leak, DV leak, or PBR leak. Additional IA bleed diagnostics are planned to determine if the leak is large enough to be logged with the sonic leak detect tool. A sundry to repair the well or an administrative relief request will be submitted after diagnostics have been completed. please let me know if there are any questions. Marie McConnell Problem Well Supervisor (907) 659-7224 n161 11. com -----Original Message----- From: James Regg ilto: ..L.L .Dtate.ak.us Sent: Thursday, 01, 2007 3:27 PM To: NSK Problem Well Supv Cc: Thomas Maunder Subject: Re: 1G-01 PTD # 182-130 Suspect T x IA communication What is the pressure anomaly in mid january (jan 8-15)? It appears the IA pressure was bled to roughly 750 psi after an increase to approximately 2000 psi from a stable 1500 psi, and built back to 1500 psi within 1 week. Well appears to be thermally stable (varying less than 5 degrees if I read your chart correctly). Isn't the increasing pressure with thermally stable conditions an indication of TxIA pressure communication? Absent other info, I'd interpret pressure data subsequent to jan 15 as bleeding pressures at least 1 per week, something not evident from the data prior to that date. When bleeding pressure from the annulus, are they also bleeding liquids or just gas? Any idea about the volume of liquid bled? Jim Regg AOGCC NSK Problem Well Supv wrote: Tom & Jim, 1G-01 PTD # 182-130, produced water injector, is showing signs of T x IA pressure communication. Prior to the bleed event T/I/O = 2100/2100/300. The IA was bled to 1200 psi and found equalized with the tubing in 24 hrs. DHD will promptly troubleshoot the problem testing will including an MITIA. I'll follow up with results of the pressure test. I've enclosed a well bore schematic and a 3 month pressure plot. Let me know if you have any questions. Sincerely, 30f4 3/16/20072:39 PM FW: 10-01 PTD # 182-130 Suspect T x IA communication . Perry Klein Problem Well Supervisor office (907) 659-7224 Cell (907) 943-1244 Pager (907) 659-7000 x909 01617@co~~~ophillips.com «lG-01 pressure plot.jpg» «lG-01 Schematic.pdf» . 4 of 4 3/16/20072:39 PM O-O! pressure 127Jx778 l.state.ak.us/lnbox"Ìnumber=6 20-NOV-06 08:47 WEEK SCRATCH 41 FLOW TUBING PRESSURE ??????? SCRATCH_41 OUTER ANNULUS PRES ??????? ¡ of! ~/ _'f I SSSV I (1789·1790, OD:3.500) Gas Lift ,ndrel/Dummy Valve 1 (2959.2960, OD:5.391) Gas Lift 'ndrel/Dummy Valve 2 (4565-4566, OD:5.391 ) Gas Lift 'ndrellDummy Valve 3 (6817-6818, OD:5.797) PBR (6867-6868, OD:5625) PKR (6880-6881, OD:5.938) I Injection .. 3ndrellOummy Valve 4 (6927-6928, OD:5.797) -.- --- -- = --. _. ,-.--. .- SLEEVE-C (7154-7155, OD:2.750) SBR (7187-7188, OD:3.500) PKR (7189-7190, OD:6.156) NIP (7207-7208, OD:2875) TUBING (7197·7220, OD:2.875, ID:2.441) Perf -. (7297-7301) ~ Perf == (7311-7329) _. .. Perf =:::: (7346·7362) ~ ~ ~. - 1== . API: 500292080500 SSSV Tvoe: TRDP Annular Fluid: Reference Lon: Last Tan: 7294' ELMD Last Taa Date: 4/15/2006 Ca$inn Strlnn:;. ALL STRINGS Descriotion CONDUCTOR SUR CASING PROD. CASING Tubiím Strina - TUBI~G,' ',' Size Ton 3.500 0 3.500 6889 2.875 7197 Interval TVD 6970 - 7019 6209·6248 7063·7104 6284 - 6316 7297 - 7301 6470 - 6473 7311 - 7329 6481 - 6496 7346 . 7362 6509 - 6522 GàsLm:,Màì'ií:liíl_ÆiIV'ês St MD TVD Man Mfr Well Type: Oria Comoletian: Last W/O: Ref Loa Date: TD: Max Hole Anale: Size 16.000 10.750 7.000 Bottom 6889 7197 7220 Zone C-4,C-3 C·1 A-5 A-4 A-3 Man Type Y Mfr Date Tvne Comment 8/30/1982 IPERF Geo Vann TCP; 120 den Ph 8/30/1982 IPERF Geo Vann TCP; 120 den Ph 8/30/1982 IPERF Geo Vann TCP' 120 deQ Ph ~8/30/1982 IP~ERF Gea Vann TCP; 120 deo Ph 28 ¡¡;;Or cw - Y OD Latch Port TRO Date Ylv Run Cmnt 11/20/1993 8/2/1993 8/1711993 INJ 8/30/1982 8/2/1993 Too o o o 7970 ftKB 45::=4700 I Bottom I 80 I 2238 I 7956 TVD 6143 6391 6409 Status Ft 49 41 4 18 16 Y Type 1 2959 2957 Cameo KBUG 2 4565 4360 Cameo KBUG 3 6817 6085 Camea MMG-2 Irìi~Qn MandrelsNalves . St MD TVD Man Mfr Man Type DMY DMY DMY .\ . Y Mfr Y Type 4 6927 6174 Cameo MMG Qttì'¡b'iJfå; S'';F duin., etcJ * JEWELRY Deoth TVD Tvne 1789 1789 SSSV 6867 6126 PBR 6880 6136 PKR 7154 6356 NIP 7187 6383 SBR 7189 6384 PKR 7207 6398 NIP 7219 6408 SOS 7220 6409 TTL Other {I luas etluló,' étc::;)1~SLEEVE . . Deoth TVD fVDe I Descrintion 7154 6356 SLEEVE-C IAVA2.75"BPlrunw/three3/16"ports,set7/18/2004 I· -. I ---- -- I -~-- f-- I···...· ~ I.... I· . I··· .. -::::- ... .- Cameo TRDp·1 AE Cameo Cameo HRp·1·SP AVA PORTED NIPPLE Baker GBH-22 Baker'D' Cameo 'D' Niaole NO GO Baker DMY . SPF 12 12 12 12 4 YOD . . Description Wt 9.30 9.30 6.50 1.0 1.0 1.5 1.5 KRU 1 G-01 Annle® TS: 36 den (â) 6969 Anale (â) TD: 38 den (â) 7970 Rev Reason: TAG Last Uncfate: 5/3/2006 TVD 80 2238 6991 Wt 62.50 45.50 26.00 Grade I H·40 I K-55 I K·55 Thread I I I 'I I Grade J-55 L·80 I L-80 Thread BTC-MOD EUE·8RD BK BK5 RK 0.000 0.000 0.000 o o o Latch TRO Date Ylv Run Cmnt 8/2/1993 Closed Port RK 0.000 o _._~-_.- ID 2.813 2.938 2.938 2.750 2.406 3.250 2.250 2.441 2.441 I ID I 2.31Ò- 1G-01 PTD # 182-130 T X IA communication . . Jim, 1 G-01, PTO # 182-130, produced water injector, continues to exhibit T x IA communication. .7he well passes an MITIA, see enclosed data, yet fails an IA draw down test, repressurizing in ./ approximately one hour. We believe that the IA is charging through a one way leak in the packer. Immediate action will be to shut in the well and promptly submit a request for an AA to continue water injection. Let me know if there are any questions. Perry Klein Problem Well Supervisor office (907) 659-7224 Cell (907) 943-1244 Pager (907) 659-7000 x909 n1617@conocophillips.com «KRU 1 G-01 02-25-07.xls» 5G.~NED MAR 2 7 2007 KRU IG-Ol 02-25-07.xls Content-Description: KRU IG-Ol 02-25-07.xls Content-Type: applicationlvnd.ms-excel Content-Encoding: base64 1 of 1 3/16/20072:35 PM . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk / KRU /1G-01 02/25/07 Brent Rogers/ Shane Ferriera/Ian Ives <\<q1 3h:~{o 7 Packer Depth Pretest Initial 15 Min. 30 Min. Well!1G-01 I Type Inj. I W TVD I 6,136' Tubing 1900 190 1900 1900 Interval 0 P .TD. h 821300 I Tvpe test I P Test psi! 1534 Casing 2290 3000 2960 2960 P/F P Notes: troubleshooting T X IA communication OA 240 240 240 240 D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test 2007 -0225_MIT _KRU_1 G-01.xls ../ I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) RECEiVED 05/18/06 Scblumbel'gel' MAY 2 4 2006 !1___~ (':.J ~ ~ '..t1I ¡;¡ Gas Gens. COfTnr."B ~~-m;~ NO. 3808 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 30 Kuparuk \ ~")..: \ ,) ~) Field: Well Color CD Job # Log Description Date BL 1 G-01 (REDO) 11213744 INJECTION PROFILE i1fé:J-13ö 05/03/06 1 1 Q-26 11258706 PRODUCTION LOG WIDEFT ¡c1 :'\-/"'3') 05/06/06 1 1 A-03 11258708 PRODUCTION LOG W/DEFT I 1) ( - 0 ~11" 05/07/06 1 1Y-15A 11216294 PRODUCTION LOG WIDEFT IC, ¿r _ I~(,. 05/08/06 1 1A-02 11258709 SBHP SURVEY I.' '! e I ~ t - 0-=1- \ 05/09/06 1 1 R-13 11258711 INJECTION PROFILE (" "1 (' \ 'X', - 1..--(' 05/10/06 1 2M-34 11216296 INJECTION PROFILE \.ft(> \ q (~- (y~ 05/11/06 1 2F-03 11216298 SBHP SURVEY ; \ ~ (\ \..:.-~ - i,,-<'1- 05/14/06 1 2F-14 11216299 SBHP SURVEY UTi. I~~'- ~ 05/14/06 1 1 A-06 11258712 INJECTION PROFILE ~) '1: Q.. ¡ "'" í - II c:... 05/14/06 1 3Q-11 11216301 LDL i 'S'~ -/¿¡';r 05/16/06 1 1J-184 11216297 USIT r)""t(' ;;:j"'(. ()¿¡<-/ 05/12/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. [1~~ $"/8S-(oe, C} e e 05/09/06 Scblumbel'gep NO. 3792 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 ~:::::9.'A~ , ,.,'('>--"->',\ ;""¡(: j,'iil>\'''~:t''''I: ~\);i~~" \)..- Æ C' " ~ ,.'. >¡;." Field: Well Log Description Date CD BL Color Job # J.. .. 1Y-29 11213739 PRODUCTION PROFILE W/DEFT ~ '7ri(' - f"" I 04/28/06 1 3M-25A N/A SHUT IN BHP 1 &\"/ - rro(" 04/23/06 1 2N-303 N/A LDL ,:) <'0 - I/~n. 04/21/06 1 1 R-21 11213737 PRODUCTION PROFILE W/DEFT l q I - t \ 3 04/25/06 1 3F-07 N/A INJECTION PROFILE I 'Í(",,- - >~4f...- 04/23/06 1 18-16 11235353 PRODUCTION PROFILE W/DEFT IC¡ I.../-('<"~ 04/04/06 1 38-15 11213741 INJECTION PROFILE ¡~K - (~;)~- 04/30/06 1 1 G-07 N/A PRODUCTION LOG W/DEFT ¿r; ~ - ;;4,.... l 04/19/06 1 1A-20 11235356 PRODUCTION LOG W/DEFT Ir,O-II~';) 04/26/06 1 1 H-18 N/A INJECTION PROFILE ¡C;.~ - (';:).0 04/24/06 1 1R-12 11213738 PRODUCTION LOG W/DEFT i~5 -OC,-x 04/27/06 1 1 Y -13 11213740 INJECTION PROFILE I~~ - c.... ,¡;;;;'- . 04/29/06 1 2N-318 11213742 LDL dDO -loa 05/01/06 1 1 Q-08A 11213743 INJECTION PROFILE £.).-¡ -,",c, ':2, 05/02/06 1 1 G-G1 11213744 INJECTION PROFILE .......~- t~D 05/03/06 1 3J-17 11258704 PRODUCTION LOG W/DEFT 1C,(" _(L{-r 05/04/06 1 1 R-26 11258705 INJECTION PROFILE '¡ ~ I - ("it:. ':l- 05/05/06 1 2A-04 11249902 INJECTION PROFILE I ~L..I - i'<=< 05/06/06 1 1 G-06 11249903 INJECTION PROFILE 1)? - ~;4(,-, 05/07/06 1 1 E-18 11216193 MEMORY PRODUCTION PROFILE 1"":f2.-~,[- 05/07/06 1 1 G-14 11249904 INJECTION PROFILE /.<'..< -:z. ,- ':'11 05/08/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. e e 10-01 (PTD 1821300) MITIA data ') ) Subject: 1G-01 (PTD 1821300) MITIA data From: NSK Problem Well Supv <n1617@conocophillips.com> Date: Sun, 26 lun 2005 20: 12:52 -0800 To: tom _ maunder@admin.state.akus, bob _ fleckenstein@admin.state.akus, jim _regg@admin.state.akus L€cl- (3D Tom, Bob, & Jim Attached is a passing MITIA for 1 G-01. This test was a diagnostic test and no problems were identified. Please let me know if you have any questions. Marie McConnell Problem Well Supervisor 659-7224 «MIT KRU 1 G-01 06-23-05.xls» ii Content-Description: MIT KRU 1G-01 06-23-05.xls MIT KRU 1 G-Ol 06-23-05.xls! ¡ Content-Type: application/vnd.ms-excel Ii Content-Encoding: base64 t,"'·tt'·,"" IiN, 16. ¡EO. f"11 J P N 9, t",' '1'2 () Of ':.~'\.1ð"" f"! """~~" ., 1.) (" ð - J 1 of 1 6/27/2005 10:35 AM ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test ') ! Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;andJim_Regg@admin.state.ak.us OPERA TOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk 1 KRU 11 G 06/23/05 Rodgers 1 Sauvageau - AES Packer Depth Pretest Initial 15 Min. 30 Min. Well 1G-01 Type Inj S T.V.D. 6136 Tubing 2470 2470 2470 2470 Interval 0 P.T.D. 1821300 Type Test P T est psi 1534 Casing 1960 3000 2950 2950 P/F P Notes: Diagnostic test. OA: 560/560/560/560 Well Type Inj T.V.D. Tubing Interval P.T.D. Type Test T est psi 1500 Casing P/F Notes: Well Type Inj T.V.D. Tubing Interval P.T.D. Type Test T est psi 1500 Casing P/F Notes: Well Type Inj T.V.D. Tubing Interval P.T.D. Type Test T est psi 1500 Casing P/F Notes: Well Type Inj T.V.D. Tubing Interval P.T.D. Type Test T est psi 1500 Casing P/F Notes: Test Details: TYPE INJ codes F = Fresh Water Inj G = Gas I nj S = Salt Water Inj N = Not Injecting MIT Report Form Revi~ed: 05/19/02 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test MIT KRU 1G-01 06-23-05.xls INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover o = Other (describe in notes) 6/27/2005 ) ) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ~, etif¡ bl1 (04' P.I. Supervisor <¡ i l DATE: Wednesday, June 02,2004 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC ]G-O] KUPARUK RIV UNIT !G-Ol 1~--'13Ó FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: ,.-.-' .., f:""" P.I. Suprv ~,Jl? Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT IG-01 API Well Numbe 50-029-20805-00-00 Inspector Name: Permit Number 1821300 Inspection Date: Chuck Scheve 5/30/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. - Well: !G-O] Type Inj. P TVD 7002 IA ]450 2480 2440 2400 2400 P.T. 1821300 TypeTest SPT Test psi ]534 OA 550 550 550 550 550 - Interval 4YRTST P/F P Tubing 2]00 2]00 2]00 2]00 2100 Notes: The pretest pressures were observed for 30+ minutes and found stable. Well demonstrated good mechanical integrity. Wednesday, June 02,2004 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille O. Taylor DATE: October 19, 2001 Chair ~ O~~--~'V~'SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder Phillips Alaska Inc. P.I. Supervisor IE;~ ~,__~r,~ ,..,~:¢~ \,._ 1D/1G Pads 1 D-07, 1 G-01, 1 G-06 FROM: Jeff Jones KRU Petroleum Inspector KRF NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. ~ WellI 1D-07 ITypelnj. I S IT-V-D- I 6033 ITubingl 2110 I 2110 I 2110 I 2110 llntervall 4 P.T.D.! 1791120 ITypetestl P ITestpsii 1508 I Casingl 290 I 1600 I 1580 ! 1575 ! P/FIE' Notes: Pre-test pressures monitored 30 min. & stable. WellI 1G-01 I Type,nj.I s I T.V.D. I~ I~,~',~i~0 I 2180 I2180 I2180 l lntervali 4' B.:%e;:,1:,:.i821300 ITypetest[ p ITestpsil 1534 [Casin~l 1280 I 1870 I 1860 I 1860 I P/F I P Notes: Pre-test pressures monitored 30 min. & stable. Welll 1G-06 I T,pe,.j.i N I T.V.D. 1590~ I Tubm11500 115OO !1500 ILS00 I'nter~a'l '4 P'T'D'! 1822200 ITypetestl P ITestpsil 1477 I Casingl 400 I 2200 I 2200 I 22001 P/F I _P Notes: Pre-test pressures monitored 30 min. & stable. Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. 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 October 19, 2001: I traveled to Phillips Alaska Inc.'s injection wells 1D-07, 1G-01 and 1G-06 in the Kuparuk River Field to witness 4-year MIT's. Pete Nezaticky was the PAI representative in charge of the tests, which were performed in a safe and proficient manner. The pre-test pressures were monitored for 30 minutes and observed to be stable. The standard annulus pressure test was then performed, with all three wells passing the MIT's. These wells are suitable for continued injection. Each well house was inspected with no exceptions noted. Summary: I witnessed successful MIT's on Phillips Alaska Inc.'s injection wells 1D-07, IG-01 and IG-06 in the Kuparuk River Field and inspected each well house. M.I.T.'s performed: 3_ Attachments: Number of Failures: 0 Total Time during tests: 6.5 hrs. cc: MIT report form 5/12/00 L.G. MIT KRU 1D, 1G Pads 10-19-01 JJ.xls 10/22/01 STATE OF ALASKA N_,-,oKA OIL/IJXlD ~ CONSERVA~ COMMIb,.,, ~ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown ~ Stimulate Plugging Pull tubing Alter casing Repair well Perforate Other 2. Name of Operator ARCO Alaska. Inc. 3.. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 5. Type of Well: Development Exploratory Stratigraphic 895' FSL, 313' FWL, Sec. 29, T12N, R10E, UM At top of productive interval 1313' FNL, 276' FEL, Sec. 31, T12N, At effective depth 1803' FNL, 500' FEL, Sec. 31, T12N, At total depth 1833' FNL~ 520' FEL~ Sec. 31~ T12N~ 12. Present well condition summary Total Depth: measured 7 true vertical 7 R10E, UM R10E, UM R10Ep UM 970 feet 002 feet 6. Datum elevation (DF or KB) RKB 91 7. Unit or Properly name Kuparuk River Unit 8. Well number 1G-01 feet 9. Permit number/approval number ~/93-215 ~,=,5.-- C~I~O 10. APl number 5o-029-20805 11. Field/Pool Kuparuk River Oil Field/Pool Plugs (measured) Norle Effective depth: measured 7858 feet true vertical 6914 feet Junk (measured) Norle Casing Length Size Cemented Structural Conductor 80' I 6" 324 SX AS II Surface 221 4' 10 3/4" 1000 Sx AS III & Measured depth 80' 2238' True vertical depth 80' 2235' Intermediate 250 Sx AS I Production 7925' 7" 595 Sx Class G & Liner 250 Sx AS I Perforation depth: measured 6970'-7019', 7063'-7104', 7297'-7301' true vertical 6209'-6248', 6284'-6316', 6470'-6473' 7956' 7311'-7329' 6481'-6496' Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 @ 7216' Packers and SSSV (type and measured depth) PKR's: Baker HB-1 @ 6824', Baker 2-B @ 7181'; SSSV: Camco TRDP-1AE @ 1718' 13. Stimulation or cement squeeze summary Converted well from oil producer to IWAG injector on 11/23/93. Intervals treated (measured) A Sand only injected Treatment description including volumes used and final pressure N/A 14. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 7000' RECEIVED DEC ] 7 199 ] ~l~ska Oil & Gas Cons. C0mm Anchorage Tubing Pressure Prior to well operation 1 8 3 157 206 1034 188 Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 0 0 2400 950 2350 J16. Status of well classification as: Oil Gas Suspended Service IWAG Iniector r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~'~~~ ~'~-"- Title Sr. En§ineer --orm 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE ,sion MDC=S I"IOR~"!N=,-.~ ' P WEt_L. REPOR]-.. FOR 1'~' : ..... ;.:...o/93 ORtLLSITE 10 PAOE 1 PRODUCTION WELL STATUS OAS LIFT STATUS IO~OR = 10000 SI DA". W Z S rdAS rdAS E O T CFIOI&E '?'" 10" II'q,J OPl" OPT I-I M t._ N A OP, WC 1"I;-2S (SSrd CSrd METER'. VC]L. IRATE rdl_ P, I L kS 'F % FTP FTT % PPM PSI PSi READINg- MSCF MSCFD ROOTS S N PR 0 OM OM .52 1.60 1000 200 .</ 0 1.2 590 ;-2. 1. 1645 " 7 P,,"' '" 600 70 O~ C'. .::, i (') %, Id .... ""' s,,l cA 'l OC, (') 0 0 0 2400 " S ....'r~ p ,P. 1 '7. tS i .:';: .'.5 154 S 0 ,':-':' ...... 0 ¢'.'"~_ ...:."-, ,--:....., r'-,~. ,".4-..50. K O b S O. 0 526 3. 4 0000 i r; r' c I 0 OM C,f"'I 8'7 80 t 20{..3 500 ~o ¥ (} 0 6."4:'3 2. 0 "';'400 '~1.~B PR 1'76, 142 1 :-?.¢'~,... ..... ~:I'~ 80 i. 3!=,¢;.., ~9.50 ¢~"%¢~;4 C,,. 729 538 ,.:.'::' ..50000 2. 0 ~400 ': 12 A SI 0 01':1 OM 29 200 ~.450 350 / See 0 0 160 1.3 B F'R 176 i77 12/.:, 70 80 i200 600 /cd~ot~4,~'A5 0 0 0 O. 0 0000 _ / !,5 I3 ~l 0 OM OM 90 220 1400 50/ 0 0 / 'T'QTALS: / '7/4-1 244'/ TN,_,IECT,OI"...I WELl__ STATUS / ~!q,JEC'T' IrON VOLUM£S SI DATA /-- L_ N ¢-', OR iN,.) (.'-SO (.'.SO I METER bC}L_ R~'-','T'E VOl_ R I D I i._ E T .'.4 PST FTT .PSi F-~S,~' '-------- -'-' ~ 77: ':{ da, D .,"[. N (=~ [' ~, '_.* "WPD MM.'T,C F ............ .S N 2 B Gi 30 382..-*.7 97 1350 1150-~ 0 O 0 5. 819 0000 13 A ~I~ ¢_~,0~ 3861 96 750 ,_o00 0 0 0 ,3. '7613 0000 4 13 rdI 12 3833 96 200 50 0 0 (} 10. 579 0000 5 ;3 ~~'I 0 OM OM 150* 0 0 0 0'~' O. 000 ~.400 . ~ _.. '~ F5 Z~'-') c:' A .. _ 6 B S W 50 =: i 99 7 ~ ~,: 1. (] 0 ~'+ ._ 0 0 ................ 7 :[ 57.~. O. fi 00 0000 .,c¢ 84 i '~{'3 n ,:~ 7E, 5 418._~. (} 0('),.'.7;, 0000 .14 B SW 20 19;I. 4 o-~ ;250 C' n 3 ~ ..............,~: .... uc, 3955:~ 0 000, 0000 ~' ~ '5 ...... , o 3548-~' 000 0000 16 D SW oD ..... ~.,4 8'~ ~ 000 0 0 1 0 ~.~% ~ _ ,~ ~ ~) . . TOTALS' SWI' 1'7640 + PW!' 0 = 1'7640 18843 P_O. 161 '" - '" ..... . ..... ~,...._,,,.., .... ,,.,Om!ER i ,~EC.; T[]N RAT)7 'rf'-4D.~.(?.A"i"FS THAT 'I'HE A hi .;.r..- e-', ~' ] z. R 'T' H E R l C iq,t¢'i"4 u-t-~ r, ~: n ' ' ""- N.. T. .... "- WELL. SHOULD BE WiDE DPEN REOARDLESS Of:" '}-HE !..iSTEE, RECOMMENDED RA'FE. RECEIVED DEC 1 7 1993 Alaska O~l & Gas Cons. Commission Anchorage ~-'-"' STATE OF ALASKA -'-'~ O.~ ~~, OIL AND GAS ~VATION COMMib,.,. -JN · REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate X Plugging Perforate k.,P~~ Pull tubing Alter casing Repair well Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) feet ARCO Ala.~ka. Inc. Exploratory 3. Address Stratigraphic P. O. Box 100360, Anchorage, AK 99510 Service 4. Location of well at surface 895' FSL, 313' FWL, Sec 29, T12N, R10E, UM At top of productive interval 1313' FNL, 276' FEL, Sec 31, T12N, R10E, UM At effective deplh 1805' FNL, 500' FEL, Sec 31, T12N, R10E, UM At total depth 1833' FNLr 520' FELt Sec 31~ T12N~ R10E~ UM 12. Present well condition summary Total Depth: measured 7970 feet true vertical 7002 feet Effective depth: measured 7 8 5 8 true vertical 691 4 Development ~ RKB 91 7. Unit or Property name Kuparuk River Unit 8. Well number 1G-01 9. Permit nu_mber/approv_al number I10. APl number so-029-20805 I11. Field/Pool Kuparuk River Oil Field/Pool Plugs(measured) NOlle RECEIVED Casing Length Size Structural Conductor 8 0' 1 6" Surface 2214' I 0-3/4" Intermediate Production 79 25' 7" Liner Perforation depth: measured 6970'-7019', true vertical 6209'-6248', Tubing (size, grade, and measured depth) DEC 1 7 1995 feet Junk (measured) None feet Alaska Oil & Gas Cons. Commission Anchorage Cemented Measured depth True vertical depth 324 SX AS II 8 0' 8 0' 1000 SX AS III & 2238' 2235' 250 SX AS I 595 SX Class G & 7 9 5 6' 7 0 0 0' 25O SX AS I 7063'-7104', 7297'-7301', 6284'-6316', 6470'-6473', 7311 '- 73 29', 6481 '-6496', 7346'-7362' 6509'-6522' 3.5", 9.3#, J-55 @ 7189' & 2.875", 6.5#, L-80 @ 7189'-7220' Packers and SSSV (type and measured depth) PKR: Camco 'HRP-1-SP' @ 6880', Baker 'D'@ 7189'; SSSV: Camco TRDP-1 @ 1789' 13. stimulation or cement squeeze summary Refractured "A" Sand on 9/16/93. Intervals treated (measured) 7297'-7301', 7311'-7329', 7346'-7362' Treatment description including volumes used and final pressure Pumped 166 Mlbs of 16/20 & 12/18 ceramic proppant into formation~ fp was 6300 psi. 14. Reoresentative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 20 ~ 4 1939 625 143 265 114 311 1417 204 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. Si~lned '~~J~~' ~~ Title Senior Engineer Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ARCO Alaska, Subsidiary of Atlantic Richfield Company WELL ~ ~3-~[ IPBDT''']'j:k,..~ I FIELD-DISTRICT-[~ STATE CONTRACTOR IOPERATI~ AT REPORT TIME REMARK~ p. ~ C C' WELL SERVICE REPORT KUPARUK PETROLEUM ENGINEERING 0~oo - IL. 18,o _5030 4 - ['-I CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather Temp. Chill Factor J Visibility J Wind Vel. Report ~F "F]~ miles knots /~.laska Oil & Bas Cons. Comrnis~ion STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown __ Stimulate __ Plugging Perforate Pull tubing X Alter casing Repair well Ot he r __ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 895' FSL, 313' FWL, Sec. 29, T12N, R10E, UM At top of productive interval 1313' FNL, 274' FEL, Sec. 31, T12N, R10E, UM At effective depth 1803' FNL, 500' FEL, Sec. 31, T12N, R10E, UM At total depth 1863' FNL, 534' FEL, Sec. 31, T12N, R10E, UM 12. Present well condition summary Total Depth: measured true vertical 7970' feet Plugs (measured) 7002' feet Effective depth: measured 7858' feet Junk (measured) true vertical 691 4' feet Casing Length Size Cemented Structural 80' 16" 324 Sx AS II Conductor Surface 2239' I 0-3/4" 1250 SX AS III & II Intermediate Production 7957' 7" 845 SX Class G & ASI Liner Perforation depth: measured 6970'-7329'. 7346'-7362' MD X , 6. Datum elevation (DF or KB) 91' RKB, 60.5' PAD GL 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1G-01(Conserv Order # 261) 9. Permit number/approval number 82-130 10. APl number 50-029-20805 11. Field/Pool Kuparuk River Oil Pool RECEIVED SEP 0 1993 Alaska 0ii & Gas Cons. t;0mmiss~, Anchorage Measured depth True vertica depth 79' MD 80' TVD 2239' MD 2235 TVD 7957' MD 7000' TVD true vertical 6200'-6500', 6509'-6522' TVD Tubing (size, grade, and measured depth) 31/2", 9.3#, J-55 @ 7220' MD Packers and SSSV (type and measured depth) Baker "D" Perm Pkr @ 7189, Camco "HRP-I-SP" Ret Pkr @ 6880' MD, Camco "TRDP-1AE" SSSV @ 1789' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 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. Form 10-404 R~v 05/17/89 Title Area Drilling Engineer Date ~~ SUB(VIIT Ih DUPLICATE ARCO ALASKA INC. DAILY OPERATIONS PAGE: i WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: 1G-01 NORTH SLOPE KUPARUK RIVER KUPARUK RIVER 50-029-20805 82-130 ACCEPT: 07/23/93 11:30 SPUD: RELEASE: 08/03/93 04:30 OPERATION: DRLG RIG: WO/C RIG: NORDIC 1 07/24/93 ( 1) TD: 7970 PB: 7858 07/25/93 (2) TD: 7970 PB: 7858 07/26/93 (3) TD: 7970 PB: 7858 07/27/93 ( 4) TD: 7970 PB: 7858 MONITOR WELL PRESS MW: 0.0 MOVING F/2M PAD TO 1G PAD. ACCEPT RIG @ 2330 HORS ON 07/23/93. LEVEL RIG. RU HARD LINE FOR KILL OPERATION. MU LUB & PULL BPV. TEST HARD LINE TO 2500 PSI. OPEN FLOW LINE VALVE. OPEN WELL. BLEED OFF GAS. CIRC DN TBG W/SW @ 3 BPM. SHUT IN WELL & MONITOR PRESS. MONITOR WELL PRESS MW: 0.0 FILL PITS W/10.8 PPG BRINE & WATER BACK TO 10.2 PPG. PMP 300 BBLS, ONLY 176 BBLS RETURNED. TBG PRESS DROPPED TO 0 PSI. WELL WENT ON A VACUUM. CUT BRINE WT BACK TO 9.9 PPG. PMP 170 BBLS OF 9.9 PPG. RETURNS STOPPED. CHANGE WELL BACK TO SW TO DETERMINE KILL WT. ORDER A THICK-SAL PILL. PMP 48 BBLS OF THICK-SAL & CHASE W/50-BBLS OF 10 PPG BRINE TO PLACE PILL. PRESS PILL INTO PLACE. DISPLACE ANN W/10.0 PPG BRINE @ 2 BPM. DID NOT HAVE FULL RETURNS, REDUCE RATE TO 1 BPM WITH ONLY ABOUT 40% RETURNS. PILL EVIDENTLY DISSOLVED. ORDER ANOTHER 100 BBL PILL W/LARGER SIZE SALT. POH W/3-1/2" TBG MW:10.0 NaCl/Br WT UP BRINE TO 10 PPG. MONITOR WELL. WAIT ON THICK-SAL PILL. PILL ARRIVED. PMP 110 BBLS OF THICK-SAL & CHASE W/58 BBLS OF 10 PPG BRINE @ 3 BPM W/1800 PSI. CIRC AROUND, HAD FULL RETURNS. MONITOR WELL-STABLE. RD CIRC LINES. SET BPV. ND TREE. NU DOUBLE STUDDED ADAPTER. NU 11" BOP STACK. PERFORM FULL BOP TEST. WITNESS BY AOGCC REP. PULL 2-WAY CV. MU LANDING JT. BOLDS. RU GBR EQUIP. PULL TBG HGR TO FLOOR. RU FLOOR TO POH. POH W/3-1/2" TBG. LOAD DP IN PIPE SHED MW:10.0 NaCl/Br SERV RIG. POH W/3-1/2" TBG. CHANGE OUT COUPLINGS TO BTC MOD. DRIFT & STRAP. RECOVERED ALL SS CONTROL LINE BANDS. LD COMPLETION JEWELRY. LD 23 JTS. RD GBR. CLEAR FLOOR. RU TO RUN DP. LOAD DP & DC IN PIPE SHED. STRAP & TALLY. RECEIVED S E P 0 199, Alaska 0il & Gas (Jons. uummiss~u' Anchorage WELL: 1G-01 API: 50-029-20805 ~ERMIT: 82-130 PAGE: 2 07/28/93 (5) TD: 7970 PB: 7858 07/29/93 (6) TD: 7970 PB: 7858 07/30/93 (7) TD: 7970 PB: 7858 07/31/93 ( 8) TD: 7970 PB: 7858 PREP TO POH MW:10.0 NaCl/Br MU SBR RETRIEVE TOOL ON FISHING BHA & RIH, PU 3-1/2" DP. TAG SBR @ 6799'. LATCH SBR & WORK FISH, UNSUCCESSFUL. SLACK OFF & RELEASE PKRW/RIGHT HAND ROTATION. ATTEMPT TO CIRC. ATTEMPT TO RE-SET PKR, RESULTING IN LOST RETURNS. POH, RECIP PKR. CBU @ 1 BPM, 100 PSI. POH. RECOVERD SBR HOUSING, PKR, 1 JT TBG, GLM #1, 2 JTS TBG, GLM #2, 1/2 JT CUT TBG. BREAK, LD & SEND OUT FISH. CLEAR FLOOR. MU NEW FISHING BHA & RIH ON 3-1/2" DP. PU & SERV KELLY. TAG FISH @ 6946'. DRESS OFF TBG STUB. LATCH & WORK FISH. WOULD NOT PULL FREE. RELEASE FROM FISH. TEST UPPER & LOWER KELLY VALVES. PREP TO POH. TIE IN SWS TBG CUTTER MW:10.0 NaCl/Br POH. FORM TAKING 60 BPH. RIH & MONITOR. FLUID LOSS STABILIZED @ 3 BPH. MIX & PMP VISC PILL. POH W/FISHING BHA. RIH W/OVERSHOT ON 3-1/2" TBG. MU TWO 10' PUPS, LATCH FISH, PULL 100M# & LAND IN SLIPS. RU SWS WL. RIH W/2.75" JET CUTTER & CCL. JET CUTTER WOULD NOT ENTER CUT-OFF TBG STUB. CUTTER STUCK COMING UP THROUGH O/S. PMP ON IT & IT CAME FREE & WENT INTO TOF. CUTTER WOULD NOT FALL THROUGH FISH & HAD TO BE PMP DOWN. STOPPED @ 7148'. AT REPORT TIME, LOGGING CUTTER ONTO CORRECT DEPTH TO CUT TBG @ 7132'. RIH W/FISHING ASSY MW:10.0 NaCl/Br TIE IN TBG CUTTER & SHOOT @ 7132'. POH W/WL & RD SWS. POH W/FISH ON 3-1/2" TBG. RECOVERED PARTIAL JT CUT TBG, 3 JTS TBG W/BLAST RINGS, 3 TBG PUPS, 2 JTS TBG W/BLAST RINGS, 4' SECTION CUT TBG. REMOVE BLAST RINGS F/TBG. BREAK & LD FISH. MU NEW FISHING BHA & RIH W/SAME ON 3-1/2" DP. TAG FISH @ 7119'. SPEAR, WORK & JAR ON FISH. POH NO RECOVERY. C/O FISHING BHA TO O/S ASSY & RIH O~ DP. POH W/PKR-MILLING ASSY MW:10.0 NaCl/Br CONT RIH W/FISHING ASSY. TAG FISH. MILL OVER & WORK FISH LOOSE. CBU. S/B KELLY & POH W/FISH. RECOVERED PARTIAL JT OF CUT TBG, GLM, 1 JT TBG, & SEAL ASSY. BREAK & LD FISH & FISHING ASSY. MU PKR-MILLING ASSY & RIH W/SAME. SLIP & CUT 50' OF DRILLING WIRE. PU & SERVICE KELLY. TAG PKR @ 7173'. MILL ON PKR. CUT FREE & PUSH TO 7217'. CIRC GAS OUT THROUGH CHOKE. MONITOR WELL-OK. B/D & S/B KELLY. POH W/PKR-MILLING ASSY. RECEIVE£ S EP 5 0 Anchorage WELL: 1G-01 API: 50-029-20805 ~ERMIT: 82-130 PAGE: 3 08/01/93 (9) TD: 7970 PB: 7858 PULLING UP TO SET STORM PKR MW:10.0 NaCl/Br CONT POH W/PKR-MILLING ASSY & LD. MU PKR SPEAR ASSY. RIH ON 3-1/2" DP. TAG FISH @ 7272'. WORK FISH. FISH OR FISHING TOOLS PACKED OFF-UNABLE TO CLEAR. RU TO PULL WET STRING. POH W/WET STRING. FISH PACKED W/SAND & PKR PIECES. BREAK, LD & MOVE OUT FISH & FISHING TOOLS. MU CLEAN OUT BHA. RIH W/CLEAN OUT BHA. TAG FILL @ 7304'. MU KELLY, WASH & REAM TO 7405'. TAGGED UP HARD. CIRC SAND F/HOLE. PMP AROUND 45 BBL VISC PILL. HOLE CLEAN. S/B KELLY & PULL DP TO ABOVE PERFS PRIOR TO SETTING STORM PKR. 08/02/93 (10) TD: 7970 PB: 7858 POH W/SWS PERF GUNS MW:10.0 NaCl/Br MU STORM PKR TO DP. SET @ 24' RKB & TEST TO 3000 PSI. ND & MOVE OUT 11" BOP STACK. BLEED OFF GAS F/7" X 9-5/8" ANN. CHANGE OUT TBG SPOOL TO MCEVOY GEN IV 11" 3M X 7-1/16" 5M. INSTALL RETROFIT PACKOFF. TEST PO TO 3000 PSI. MOVE IN & NU 7-1/16" BOP STACK. PERFORM TEST ON BOPE. TEST WITNESS WAIVED BY JOHN SPAULDING OF AOGCC. LATCH, RELEASE, & LD STORM PKR. POH, LD DP. RIH 10 STDS DP F/DERRICK & POH, LD SAME. RIH 15 STDS TBG F/DERRICK & POH, LD SAME. ND FLOW RISER. NU SWS LUB & TEST TO 1000 PSI. RIH W/SWS 4" GUNS. PERF 7346'-7362' @ 4 SPF. POH W/WL. 08/03/93 (11) TD: 7970 PB: 7858 RIG RELEASED MW:10.0 NaCl/Br LD GUN. MU GAUGE RING/JUNK BASKET. RIH 7320'. WENT SLICK. POH W/GAUGE RING/JB. LD GAUGE RING/JB MU PKR/TAILPIPE ASSY. RIH. SET PKR @ 7180' POH & RD SWS. INSTALL FLOW RISER. RU & RIH SS COMPLETI6N. TAG UP, SPACE OUT. MU HGR. MU CONTROL LINE TO TBG HGR & P-TEST TO 5000 PSI. LAND HGR, RILDS. TEST PKR TO 2500 PSI FOR 30 MIN. BOLDS. PUT 1000 PSI ON TBG & SHEAR PBR W/82M#. RE-LAND, RILDS. TEST SSSV W/500 PSI. TEST TBG & ANN W/2500 PSI. TEST TBG W/3000 PSI. PRESS TBG TO 3700 PSI TO SHEAR BALL. BLEED OFF, CLOSE SSSV, SET BPV. ND BOPS, NU TREE. TEST PACKOFF TO 5000 PSI, PULL BPV, SET TEST PLUG, TEST TREE TO 5000 PSI, PULL TEST PLUG, OPEN SSSV. FREEZE PROTECT ANN W/12 BBLS DIESEL. BULLHEAD 4 BBLS DIESEL DN TBB. SECURE WELL. RIG RELEASED @ 0430 HRS 08/03/93. SIGNATURE: dri~er~nte~nt DATE: RECEIVED S E P 0 199; ~aska Oil & Gas Cons. (;ommiss~u,, Anchorage MEMORANDUM TO:David Johnston, Chairmari State of Alaska Alaska Oil and Gas Conservation Commission DATE: August 3, 1993 THRU: Blair Wondzell, J~Z~u~ FILE NO: P. I. Supervisor ~'[~ FROM: Jp~rt7 iHer~i?_g, J ~°~' SUBJECT: o au nspec[or AAUKGXAA.doc ,.. B.O.P.E. Test- Nordic 1 ARCO, KRU, 1G- lA Kuparuk River Field Saturday. July 24, 1993: ! completed a rig inspection and witnessed the initial B.O.P.E. test on Nordic 1 completing a workover on ARCO's Kuparuk 1G-lA. The 7" casing was installed to 7957 feet. The Rig Inspection and B.O.P.E. Test Reports are attached for reference. Nordic 1 had just moved on pad to 1G-lA. I found the rig to be in good shape with all equipment in place and in good operating condition. There was one failure, the packing leaked on valve number 5 on the choke manifold. The packing was replaced and the valve retested satisfactorily. The area surrounding the rig and camp was clean and orderly providing for good access. Summary: The B.O.P. test on Nordic 1 started at 10:00 PM and lasted for 5 hours. No failures were encountered. Attachment STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: 7" Test: Initial Workover: X Nordic Drilling Rig No. ARCO Alaska, Inc. KRU fG-1A Set @ 7,957 X Weekly Other 1 PTD # Rep.: Rig Rep.: Location: Sec. DATE: 7/24/93 82-130 Rig Ph.# 659-7115 Karla Lenz Shane McGuhan/Dave Richie 29 T. 12N R. IOE Meridian UM MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) Reserve Pit N/A Well Sign OK Drl. Rig OK BOP STACK: Annular Preventer Pipe Rams Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Pressure P/F 300/3000 P 300/3000 P NIA NIA 300/3000 P 300/3000 P 300/3000 P 300/3000 N/A P N/A MUD SYSTEM: Visual Alarm Trip Tank OK None Pit Level Indicators OK None Flow Indicator OK None Gas Detectors OK OK FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F 0 N/A N/A 0 NIA NIA I 300/3000 P I 300/3000 P CHOKE MANIFOLD: No. Valves 12 No. Flanges 26 Manual Chokes 1 Hydraulic Chokes I Test Pressure 300/3000 300/3000 Functioned Functioned P/F ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure O System Pressure Attained 0 Blind Switch Covers: Master: Nitgn. Btl's: 2 Bottles 2,200 Ave. 3, 050 2,450 minutes 17 sec. minutes 53 sec. OK Remote: OK Psig. Number Of'FailUres: ........ ~' ""' ,TestTime:: 4.0 Hours.'' N'urnber°f valves teSted 18 Repair or Replacement of Failed' Equipment will be made within n/a days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: The number 5 valve on the choke manifold leaked and was repaired. Anchors to be installed on BOP stack. Distribution: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File c -Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: JerryP. Herring ~ FI-021L (Rev. 7/93) AAUKGXAA.XLS OPERATION: Drig Contr: Operator: Location: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RIG ! BPS INSPECTION REPORT Drilling Workover Nordic ARCO Alaska, Inc. Section 29 T. 12N X Cmpl. Well Name: Rig No. Rep. R. 10E M. UIC 1 Rep. Karla Lenz UM KRU 1G-1 DATE: 7/24/93- PTD# 82-130 Shane McGuhan Rig Ph.# 659-7115 (A.) B.O.P. STACK fig wkg press Stack wkg press Annular preventer Pipe rams Blind rams Stack anchored line size tums targeted ( chke & kill Ln.) HCR valves (chke & kill Ln.) Manual valves (chke & kill Ln.) Connections (Flgd, Whd, Clamped Drilling spool Flow Nipple monitor Control lines fire protected (B.) CLOSING UNIT pressure level Operating pressure Pressure gauges Sufficient valves Regulator bypass 4-way valves (actuators) Blind rams handle cover Driller control panel Remote control panel Firewall Nitrogen power source (backup) Condition (leaks, hoses, ect.) REMARKS: (C.) MUD SYSTEM Pit level floats installed Flow rate sensor Mud gas separator Degasser Separator bypass sensors Choke line connections Trip tank (D.) RIG FLOOR Kelly cocks (upper, lower, IBOP) Floor valves (dart, ball, ect.) Kelly & floor valve wrenches console (flow monitor, flow rate indicator, pit level indicators, gauges) Kill sheet up-to-date Gas detection monitors H2S & methane) Hydraulic choke panel Choke manifold (E.) MISC. EQUIPMENT Flare/vent line targeted downstream choke lines) {eserve pit tankage Personnel protective equip, avail. Drillsite Supervisors Trained For Procedures H2S probes Rig housekeeping This is a workover rig. All equipment is in good operating condition. RECORDS: Date of Last Rig / BPS Inspection 6/7/93- Resulting Non-Compliance Items: Non-Compliance not corrected & Reason: Date Corrections Will Be Completed: BOP Test & Results Properly Entered On Daily Record? Distribution: orig - Well File c - Oper./Rig ~ - Database c - Trip Rpt File c - Inspector Date of Last BOP Test 7/24/93- None AOGCC REP: OPERATOR REP: Yes Kill Sheet Current? No Jerry P. Herring F1-022 (Rev. 3/93) QAUKGXAA.XLS STATE OF ALASKA Au ,,¢KA OIL AND GAS CONSERVATION COMMb~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, In(;. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 895' FSL, 313' FWL, Sec. 29, T12N, R10E, UM At top of productive interval 1313' FNL, 276' FEL, Sec. 31, T12N, At effective depth 1803' FNL, 500' FEL, Sec. 31, T12N, At total depth 1833' FNL, 520' FEL, Sec. 31, T12N, R10E, UM R10E, UM R10E, UM 12. Present well condition summary Total Depth: measured 7 95 6' feet true vertical 7000' feet Plugs (measured) 6. Datum elevation (DF or KB) 91' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 1G-1 Producer 9, Permit number/approval number 82-30/7-541 10. APl number 50-029-20805 11, Field/Pool Kuparuk River Oil Pool Effective depth: measured 7858' feet true vertical 6890' feet Junk (measured) Casing Length Size Structural 8 0' I 6" Conductor 2238' 10 Surface Intermediate Production 7956' 7" Liner Perforation depth: measured 6970'-7329' true vertical 6200'-6500' Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 @ 7216' 3/4" Cemented 324 Sx 1250 Sx Measured depth 80' 2238' True vertical depth 80' 2235' 865 Sx 7956' 7O00' RECEIVED 0 7 ISgO Alaska 0il & Gas Cons. Commission Packers and SSSV (type and measured depth) Anchorage Camco TRDP-1AE @ 1730'; BOT HB-1 @ 6824', BOT 2-B @ 7181' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 3000 gal, 12~ % HCL 14. Prior to well operation (producing) Subsequent to operation (injecting) 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X Reoresentative Daily Averaoe Production or Iniection Data - OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 433 341 1677 821 817 402 1334 889 Tubing Pressure 190 200 16. Status of well classification as'. Water Injector__ Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed .//~ ~,~._~ Form 1~0-404 F~v Title Sr. Operations Engineer 05/17/89 STATE OF ALASKA ALASKA OILAND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Abandon _ Suspend _ Operation Shutdown Alter casing _ Repair well _ Plugging _ Change approved program_ Pull tubing _ 2. Name of Operator I 5. Type of Well' I Development X ARCO Alaska. Inc. Exploratory _ 3. Address I Stratigraphic _ P. O. Box 100360, Anchorage, AK 99510I Service _ 4. Location of well at surface 1929' FSL, 661' FEL, Sec. 11, T11N, R9E, UM At top of productive interval 1374' FNL, 1426' FEL, Sec. 11, T11N, R9E, UM At effective depth 1120' FNL, 1454' FEL, Sec.11, T11N, R9E, UM At total depth 1090' FNL, 1465' FEL, Sec. 11, T11N, R9E, UM 12. Present well condition summary Total Depth: measured true ve'rtical 7450' feet Plugs (measured) 6 81 2' feet None' _ Re-enter suspended well_ Time extension Stimulate Variance _ Perforate _ Other 6. Datum elevation (DF or KB) RKB 109 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2Z-04 9. Permit n~mber 83-86 / ~,' ~-_,t ~,~- /_ S./-,,/~/ 10. APl number 50-029-20965 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured true vertical 7348' feet Junk (measured) 6 71 4' feet None Casing Length Structural Conductor 7 4' Surface 3 2 2 3' Intermediate Production 7 3 9 1 ' Liner Perforation depth: measured 6479'-6538' true vertical 5885'-5941' Tubing (size, grade, and measured depth 3 1/2," J-55, tbj w/tail @ 6602' MD Packers and SSSV (type and measured depth) Size Cemented Measured depth True vertical depth 1 6" 286 Sx AS II 1 13' 1 13' 1 0 3/4" 1300 Sx Fondu & 3 2 6 2' 31 51 ' 300 Sx Permafrost C 7" 435 Sx Class G & 7 4 3 0' 6 7 9 3' 250 Sx Permafrost C R EC E IV E D 6668'-6736' 6064'-6129' ;JUN o 7 'i9 9 Alaska 0il & Gas Cons. Commission Anchorage Otis RH pkr@6295',Otis RH pkr @ 6574' and Camco TRDP-1A SSSVC 1799'(Locked Open), MACCO PB-2.50 WRDP @ 1799' 13. Stimulation or cement squeeze summary Intervals treated (measured) No Treatment 14. Treatment description includin~l volumes used and final pressure Re0resentative Daily Average Production or Iniection Data /V OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation Subsequent to operation Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si!~ned ,./-'~)~ ,.'~ /(-~5 .../~t..¢~.U.~...c.c.~'~L/ Title Sr. Operations Engineering Form 10-404 ~lev 06/15/88 SUBMIT IN DUPLICATE f · 'ARCO Alaska, Inc. Subsidiary of Atlantic Richheld Company WELL SERVICE REPORT WELL 'NTRACTOR REMARKS PBDT iFIELD- DISTRICT- STATE OPERATION AT REPORT TIME IDAYS DATE J~ ~' ¥.~_~,? ,5E'7" ~ ,,'7 6 (-/' : pub/ O~ - z. s~"' ,~A.Ceo [] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather ITemp' I Chill Fact°r I Visibility iWlndVel'Report OF OF miles knots WELL ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company 3NTRACTOR REMARKS jPBDT FIELD - DISTRICT - STATE IOPERATION AT REPORT TIME WELL SERVICE REPORT JDAYS ~ DATE [] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK knots ARCO Alaska, Subsidiary of Atlantic Richfield ComDany WELL CONTRACTOR REMAR[<S ,PBDT /_C.-" - WELL SERVICE REPOF I iEIELD- OISTRICT - STATE OPERATION A~' REPOR~ TIME /o ~Z:v_.., I--] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK WeatherReport Ivamp' I Chill Factor I Visibility iw, n~ vel ARCO Alaska, Inc. WELL Subsidiary of Atlantic Richfield Company iPBDT 2oo~' ONTRACTOR REMARKS / FIELD - DISTRICT - STATE IOPERATION AT REPORT TIME WELL SERVICE REPOR1 'DATE 15oo 5'00 I ~o ! [--] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ~W_e_a_th..,er I'°-. __ 1 Chill Factor,_ I Visibility _,.__ l Wlnd Vel. ~.--.. J Signed/C.../Z ARCO Alaska, Inc. Date: December 8, 1988 Transmittal #: 7365 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. 1 G- 01 Kuparuk Fluid Level Report 1 2 - 0 5 - 8 8 Casing 3Q-02 Kupaurk Fluid Level Report 1 1-29-88 Casing 3 K- 0 6 Kuparuk Fluid Level Report 1 1 - 2 7 - 8 8 Casing 2 V- 0 4 Kuparuk Well Pressure Report 1 1 - 1 6 - 8 8 Sand 'A' 2V-04 Kuparuk Well Pressure Report 11-19-88 Sand'A' Receipt Acknowledged: DISTRIBUTION: D&M State of Alaska Chevron Mobil Unocal SAPC ARCO Alaska, lnc; Post Office _.,.. 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: September 2, 1987 Transmittal # 6049 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 1Y-3 Pressure Report 'Al Sand 8-20-87 100596H IY-14 Static Gradient Survey 8-20-87 100556Y14 1Y-5 Static Survey 8-20-87 1005551Y5 1G-1 Kuparuk Well Pressure Report(Camco} 8-24-87 1G-7 Kuparuk Well Pressure Report 8-24-87 2D-3 Kuparuk Well Pressure Report(Otis)'C' Sand 8-2-87 .Alaska Oil & Gas Co~s. Anchorage Receipt Acknowledged: DISTRIBUTION: Date: BPAE Chevron Mobil SAPC Unocal D&M ARCO Alaska, Inc. Is a Subsidiary of AtlanlicRIchfleldCompany STATE OF ALASKA -'--~ ALAc._t~ OIL AND GAS CONSERVATION COlt ~,SSION 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 [] 2. Name of Operator ARCO Alaska, Inc 3. Address PO Box 100360, Anchorage, AK 99510 4. Location of well at surface 895' FSL, 313' FWL, Sec.29 T12N RIOE UM At top of productive interval ~ ~ ' 1313' FNL, 276' FEL, Sec.31, T12N, RIOE, UM At effective depth 1803' FNL, 500' FEL, Sec.31, T12N, RIOE, UM At total depth 1833' FNL~ 520' FEL, Sec.31, T12N, RIOE? UM 11. Present well condition summary Total depth: measured 7956' MD feet true vertical 7000' MD feet 5. Datum elevation (DF or KB) RKB 91 6. Unit or Property name Ku~aruk RivPr Unit 7. Well number 1G-1 8. Permit number Permit #82-130 9. APl number 50-- 029 -20805 10. Pool Kunar~k Rivor Oil Ponl ! Plugs (measured) None Effective depth: measured 7858' MD feet true vertical 6890' MD feet Length Size 80' 16" 2238' 10.75" Casing Structural Conductor Surface Production xx~-~xeXxxxx x Perforation depth: measured Junk (measured) None Cemented 324 SX 1250 SX Measured depth ~ue Vertical depth 80' MD 80' TVD 2238' MD 2235' TVD 7956' 7" 865 SX 7956' MD 6970'-7329' MD 7000' TVD RECEIVED true vertical 6200'-6500' TVD Tubing (size, grade and measured depth) 3.5", 9.3#, ,]-55 @ 7216' MD Packers and SSSV (type and measured depth) Camco TRDP-1AE @ 1730'; BOT HR-1 (a 6F~24; RflT ?-B @ 718!' 12.Attachments Description summary of proposal J~ Detailed operations program [] Treat w/3000 gals 12% HC1 to clean up scale 13. Estimated date for commencing operation August 20, 1987 AUG 1 ? 1987 Alaska 0il & Gas Cons. Corem[ss Anchorage BOP sketch [] 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed .,~ Title Sr. Operations Engineer Commission Use Only Conditions of approval Notify commission so representative may witness I Approval [] Plug integrity [] BOP Test [] Location clearance I NO. Date 8/17/87 Approved by , . Commissioner by order of the commission Date Form 10-403 Rev 12-1-85 Submit in triplicatey" ARCO Alaska, I~' ~, WELL SERVICE REPORT - Subsidiary of Atlantic Richfield Compa,., WELL IPBDT / I FIELD - DISTRICT - STATE IDAS IDA?/ -~/'-A cc i r~,zv-o~ - REMAI~KS }OPERAT/~ON AT REPORT TIME [--I CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather Report Temp. Chill Factor I Visibility iWind Vel. °F °F miles knots Signed'~- A~ ATTACHMENT I I Drill Site lA Wel 1 No. lA-4 lA-5 lA-7 1A-9 1A-11 1A-12 1A-14 1A-15 1A-16A KUPARUK RIVER UNIT Production LoBs FEBRUARY 19, 1986 Lo9 Date Drill Site Well No. Lo9 Date 7/6/83 10/29/83 2/8/82 5/7/82 1/25/82 3/23/83 1/19/83 3/21/83 3/8/82 4/1/82 6/5/82 5/11/82 6/8/82 lB lB-1 12/26/81 lB-2 6/25/81 lB-3 11/16-18/81 3/12/82 1B-6 11/18/81 9/10/82 1B-7 11/23/81 1B-8 12/28/81 8/4/82 1B-9 6/24/82 8/3/84 Drill Site 1C Well No. 1C-1 lC-2 1C-3 1C-4 1C-5 1C-6 1C-7 1C-8 ' L,o9 Date 5/9/81 5/8/81 7/13/81 11/8/81 3/9/81 2/26/81 11/30/81 5/19/81 5/21/81 Drill Site 1D Well No. Log Date 1D-1 · 1/80 5/23/83 1D-3 8/5/80 1D-4 7/30/80 8/13/80 1D-5 6/11/81 1D-6 6/9/81 1D-7 6/8/81 8 (ws-~) 511o178 Attachment Page 2 Dri 11 Si te 1H Drill Site lQ Well No. Log Date IH-3 8/16/82 1H-4 8/13/82 1H-6 6/21/82 1H-7 7/20/82 1H-8 7/22/82 Well No. Log Date ~1Q,~12/1785~ Drill Site Well No. Lo9 Date 1E 1E-lA 1E-2 1E-3 1E-4 1E-5 1E-6 1E-7 1E-8 1E-12 1E-15 1E-16 1E-17 1E-20 1E-24 1E-25 1E-26 1E-27 1E-28 1E-29 1E-30 8/19/81 8/17/81 1/17/84 10/18/81 11/7/81 8/4/80 9/2/81 11/5/81 10/27/81 10/21/81 11/12/82 10/28/81 8/28/81 11/1/81 11/28/84 8/26/82 8/29/82 9/1/82 5/7/83 2/17/83 1/17/83 1/13/83 10/31/82 10/27/82 6/13/83 10/18/82 7/18/83 10/16/82 Drill Site 1G Well No. Lo9 Date 1G-1 1G-2 1G-3 1G-4 1G-5 1G-7 1G-8 9/7/82 9/25/82 9/28/82 12/8/84 10/13/82 11/12/82 Drill Site 1F 3/12/83 Alaska Oil & Gas Cons. At--ore, ge Well No. 1F-1 1F-2 1F-3 1F-4 1F-5 1F-6 1F-7 Log Date 2/19/83 2/3/83 1/31/83 5/29/83 10/25/82 10/28/82 11/19/82 5/7/83 Attachment I I ~--_., Page 3' Drill Site 1Y Well No. Lo9 Date 1Y-1 6/6/83 10/21/83 1Y-2 6/10/83 3/4/84 1Y-4 7/2/83 1Y-5 6/29/83 1Y-6 6/27/83 1Y-8 6/22/83 1Y-9 6/20/83 !~-'Cl~ 5/10/83 ~_ 11/21/83 1Y-12 5/25/83 1Y-13 5/27/83 IY-14 5/13/83 5/18/83 1Y-15 5/29/83 1Y-16 5/30/83 10/23/83 Drill Site Well No. Log Date 2C 2C-4 2/19/85 2/28/85 2C-7 10/15/84 Drill Site 2Z' Well No. Lo9 Date /10/83 · __ 12 8s; 2Z-2 ': 6/24/83 7/19/83 2Z-3 8/5/83 2Z-4 7/12/83 2Z-6 7/27/83 2Z-7 7/28/83 2Z-8 8/3/83 VLF:pg:O052 Alaska Oil & Gas Cons. Anchor~]~. 2 : ..... Drill Site -- 1H _ II Well No. 1H-3 ~1H-4 XlH-7 ~1H-8 Log Date 8/16/82 8/13/82 6/21/82 7/20/82 7/22/82 I · .1. Drill Site 1E Well No. Lo~ Date 1E-lA '~/19/81 1E-2 ~8/17/81") _'~1/17/84/ 1E-3 "-10/18/8I~. ~11/7/81/ ~8/4/80'~ 1E"-4~,~el ~/,,.:~ I~,5 ~I0/27/81 i~-6 ~i0/21/81"% '-~11/12/82// '~'1E-7 ~/28/81~ ~E-8 '~ ~I2~/8~) ~ "~11/1/8 1E-12 '"11/28/84 1E-15 "-8/26/82 1E-16 "'8/29/82 1E-17 "-9/1/82 1E-20 "~5/7/83 1E-24 "-2/17/83 · 1E-25 '~1/17/83 1E-26 ~1/13/83 1E-27 '",S10/31/82 1E-28 ~10/27/82) ~'~6/13/83 1E-29 -~0/18/82B ~7/18/83 1E-30 ~'-10/16/82 Drill Site 1G Well No. "X. lG_1 "~1G-3 ~1G-4 %1G-8 Lo9 Date 9/7/82 I 9/25/82~ 9/28/82 12/8/84 10/13/82 11/12/82 3/12/83 1/22/83 Drill Site Well No. Log Date 1F '~1F-1 2/19/83 ~1F-2 2/3/83 'XIF-3 1/31/83 "1F-4 5/29/83 %1F-S 10/25/82 '~1F-6 10/28/82 ~ 1F-7 11/19/82~,, ~ 5/7/837 RECEIV F E B 2 1 1986 Alaska 011 & Gas Cons. Commission Anchomge ARCO Alaska, Inc. -*'--~ Post Office B~. 0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 17, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached in- following wells at Well 1B-2 1B-4 1E-lA 1E-lA 1E-27 1E-30 1F-6 1Q-5 1Q-6 1Q-7 1Q-11 1Q-13 1Q-14 1Q-15 1Q-16 1Y-2 1Y-8 1Y-12 2A-2 2C-8 2C-14 2H-15 2V-2 duplicate are subsequent notices the Kuparuk River Field' Action Fracture Fracture Cancellation (Reperf) Cancellation (Frac) Cancellation (Frac) Polymer Project Cancellation (Frac) Cancellation (Frac) Cancellation (Stressfrac) Acidize Acidize Fracture Cancellation (Frac) Fracture Fracture Fracture Fracture Conversion Conversion Conversion Conversion Cancellation (Perf) Acidize Stimulation Conversion Date Performed 6/14/85 6/14/85 1/5/85 6/23~85 6/24~85 6/25/85 7/2/85 7/1/85 7/2/85 7/2/85 3/30/85 3/30/85 3/30/85 3/31/85 7/2/85 6/30/85 5/16/85 on the If you have any questions, please call · T. M. Drumm Kuparuk Operations Coordinator TMD/kmc Attachment (Duplicate) me at 263-4212. ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany STATE OF ALASKA ALASKA O~L AND GAS CONSERVATION CO~MISSION SU_N_DRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO ALASKA, INC. 3. Address P. O. BOX 100360, ANCHORAGE, ALASKA 99510 4. Location of Well SURFACE LOCATION' 895'FSL, 313' FWL, Sec. 29 T12N, R109E, UM 5. Elevation in feet (indicate KB, DF, etc.) 91' 12. 7. Permit No. 82-130 8. APl Number 50- 029-20805 9. Unit or Lease Name KUPARtJK RIVER UN I T 10. Well Number 1G-1 I 6. Lease Designation and Serial No. (RKB) ADL25640 ALK 2571 POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other I-IX Pull Tubing [] Other [] Pulling Tubing [] 11. Field and Pool KUPARIJK RIVER FI ELD KUPARtJK RIVER OIL (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Kuparuk well 1G-1 will not originally proposed. be stressfrac'ed in the "A" sand as 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~,,/~.-'~-~ (~¢.~-.~~ Title KIJPAR! IK The space below for Commission use OPERAT IONS COORD ! NATOR Date 7 / ! 6 / 85 - Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date ~ Submit "Intentions" in Triplicate Form 10-403 and "Subsequent Reports" in Duplicate D~,, ~ I 0('~ ARCO Alaska. Inc. Post Office ~,_^ 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 June 24, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK .99501 Dear Mr. Chatterton- Attached in duplicate are subsequent notices following wells at the Kuparuk River Field. Well Action Date Performed 1A-3 Fracture 5 / 30 / 85 1A-4 Fracture 6/1 /85 1C-5 Perforate 4/27/85 1E-3 Perforate 3/28/85 1E-3 Fracture 4/3/85 1E-4 Perforate 4 / 20/85 1E-4 Fracture 5/7/85 1E-1 6 Fracture 4 / 1 4/85 1E-1 7 Fracture 3 / 26 / 85 1 E-29 Fractu're 4/1 2/85 1F-1 6 Perforate 4/11/85 1F-'I 6 Fracture 4/1 5/85 1G-1 Fracture 4/1 / 85 1 L-15 Fracture 3/31/85 1L-1 6 Fracture 3/31/85 1Q-1 Fracture 5/31/85 1Q-4 Ac id ize 5/17/85 1Q-4 Fracture 5 / 31./85 1Q-5 Fracture 5/1/85 1Q-6 Fracture 4/19 / 85 1Q-7 Fracture 4/27/85 1Q-7 Ac id i ze 5/26 ! 85 2C-1 0 Perforate 4/21/85 2D-3 Ac idi ze 5/11/85 2W-1 3 Ac idi ze 5/20/85' 2X-12 Acidize 5/12/85 on the If you have any questions, please call T. M. Drurnm Kuparuk Operations Coordinator TMD / kmc Attachment (Duplicate) me a t 263-4212. RECEIVED Alaska Oil & gas ~o[~$. Cornmissiort Anchorage ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA O~L AND GAS CONSERVATION CO,v~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 82-130 3. Address 8. APl Number P. O. BOX 100360, ANCHORAGE, ALASKA 99510 50- 029-20805 4. Location of Well SURFACE LOCATION: 895'FSL, T12N, R109E, UM 313' FWL, Sec. 29 5. Elevation in feet (indicate KB, DF, etc.) 91 ' (RKB) 6. Lease Designation and Serial No. ADL25640 ALK 2571 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 1G-1 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL POOL 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On April 1, 1985, the "A" sands of Kuparuk well 1G-1 were hydraulically fractured and propped to improve production. The treatment consisted of 288 BBLS of gelled water as pad and carrying fluid and 17,674 LBS of 100 mesh and 12/20 sand as proppant. 12 BBLS of gelled diesel was used as a flush. Prior to pumping, equipment and lines were tested to 5000 psi. I ECEIVED JUN 2 6 1985 Alaska 0il & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. KUPARUK Signed ~-~'~ ~"¢"~¢"~'~ Title OPERATIONS COORDINATOR The space below for Commission use 6/18/85 Conditions of Approval, if any: By Order of Approved by. COMMISSIONER the Commission Date Form 10403 Rev. 7-1-80 Submit "Intentions" in Triplicate and ."Subsequent Reports" in Duplicate ARCO Alaska, Inc Post Off.; '~''~ 100360 Anchoras . ,,,aska 99510-0360 Telephone 907 276 1215 DATE' AF'RII_ --.:_ i98~ 'rr-;;AN..~HITTAL_ N0' !..'-.:t 4g -A (., ~'-, LE.D(;E ...... ~,,,...:.:,.~ ....... TH ARr.--- TI--Ir-- F'O~...., ....... REE:ETF'T AL!D K.'ETL~RN ONli:-. ,.--'7..~Gt'~'E~.'.' COF'Y Ol:- THIS TRAN?HITTAL, .?CE / ! N l'l:-_ R M I TTF:N T :'_70..F../F'ROD I._O[.; & ' A' P' .... U NJ:- ' .'7 .... ::/I-'B ( T. I Iai._ ,?OE/F'BU 5'OE/F'.E-:U ,?OE/F'BU ~PF/' ' ' .~ .,._ C SAND F'P,U SOE/SBI"IF' '- 'A' STATIC BHF' DATA ~TATiC BHF' DATA ~TATIC BHF' DATA STATIC BI"!F' DATA YTATIC BI"IF' DATA :?TATIC BHF' DATA ,'?TATIC BHF' DATA Y'¥ATIC BHF' DATA YTATIC BHp DATA ~ .- ~" II-, , ~ ~ ~TAT.,./~ ~, r'~ r- ~T,.-~TIC r.,,-IF- T;~ATA ,~TAT~C BHP 9ATA ~TATZC BHP DATA ~,~..,T~.C BHF' DATA ~TAT]C BHF' DATA 5'TAT~C BI-IP DATA 3TATZC BHF' DATA ~f'?:TIC BI-IF' DATA ~TATZC BHP D~TA I_ I F'T F F'.,:.;,..~ URE 5'URVEY · '.AND F'BU F'RES'5.'LJRE ) 'C' SANDZ -': F'A E i':, C!.!F'.:,R I ER , !", :" VRON DI,.?. TRI BU'I' i ON: DRILLING W.,. F'A,S'HER L,. .JOHNS'TON EXXON MOBI',_ PHIl_LIPS' OIL N~:K CI._ERI< J, RATHHE~LL ARCO Alaska, Inc. is a Subsidiary of AllanticRichfJeldCompany 416-7/85 3,-" t t/85 '-.. '~/') 6/o5 .- ..-., / ,_, -z/"~ / .-,.~ 5/t 8/o'~ i/24/85 t/24/8% ,..S/~/85 3;/'""/85.- ,5/2/85. ~/~/'-~ 5/t 9/85 3/I 9/85 f/2'" :..,: a'. S / ~ 4 / o ,~- -z/~6 ,L.., ~,. / C; ~ i/.,24 /,q 5 f/25/85 i / ''~ z / 'R · ,,2..'...'/ "" 5 t/2~/8~ 'i/?,1 /~ ._.. / ,_.: ._/ ,( .// (..' _;' ~/i i/8'3 ' 'i /'.)4 'l/."')1~' /(-, / ,,,'- -.;' / / ,-'.. ~// k_, ~/ RECEIVED APR 2 5 1985 alaska Oil & G~s~ ~__Cons. Commission U i'-./I 0 i'-,~ K. TI~LIN/VAL;LT ., ARCO Alaska, Inc.:-"'~. Post Offic 360 Anchorage, ~.,aska 99510 Telephone 907 277 5637 Date: 1/30/85 Transmittal No: 5013 RETLrRN TO: ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B An.O. Box 100360 chorage, AK 99510 ' mitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. _ BHP REPORTS & .SEQUENCE QF EVENTS 1G-4 9/30/84 9/04/84 "BHP" IO-f':, 11/24/8_4 11/24/84 "SB~" iL-8 10/05/85 1L-7 10/19/8'4 1L-6 10/18/84 1L-5 10/18/84 1L-4 10/19/84 2w-7'- 1/07/85 · 2w-6 1/07/85 2W-5. 1/07/85 2w-8~- 1/08/85 1E-5" 11/~5/84 . . .1/07/84 1/07/84 1/07/84 1/o8/84 11/26/84 "SBHP" "Initial" "SBHP" "Initial" "SBHP" "Initial" "SBP~" "Initial" "SBHP" /cat Receipt Acknowledged: B. Currier BPAE Chevron D &M Date Drilling Geology Mobil NSK Ops. DISTRIBUTION W. Pasher G. Phillips Phillips Oil J. Rathmell State of AK Sohio Union Well Files ARCO Alaska, Im~-~-. Post Offi~ :x 100360 Anchorage,. -.-.,aska 99510-0360 Telephone 907 276 1215 RETLIRN TFJ' ARCO ALA,?I<¢;, INC. ¢; T T N ' ,-R El C 0 R I) .? F_; [_ E R I< ATO-i i t , F:'.O. ,90X i00~6'3 A,WCHNF.'AGE,_ . ;il-.'. ':?°5,- i 0 EtdlTI--! ARF'_- THE FOLL_C)!,JING URN ONE .S'-IGNED COPY OF DAI'E' AF'RIL t9, i985 TRAN,?IfllTTAL NO'_..~I4'7. F:'AG F" OF' I I'EHS'. F'!._,:~A..?E- AC, I< NOI..JL.EDGT:. THZ~' 'TRAN£HI'FTAL. EVEHTZ · 'A' SAND FRAC-GELLED ~TATIC F'BU F'E;U ~, T',I I ",--" L; F'BU F' B U GELLED WATER FRAC HYDRAULIC FRAC F'O~T FRAC TEMF' LOC;~ F'BU F'BU ~TATIC Blip F'BU F'BU GEl_LED wATER BATCH F'O,~T FRAC TEMF' LOG ~TATiC BHF' .FI .~TATIC BHF' INJECTIVITY TE~T STATIC BHF' BHF' B H F' BHP F'BU F'O;~T FRAC TE~F' LOG BHF' F'O~T FR~C TEHF' LO~ I--IYD. FRACTURE F'~U F'BU I$IF' WATE~ FRAC 413185 4/3/85 4/2/85 4/f-2/85 ~/¥t,/85 3/31185 4/t/85 4/t/85. 4/2/85 4/9-f0/85 4/7-8/85 ~ /o/o~ 4/tt-t3/85 4/t t -t.-'"185 4/t o ,'o~ 41t2/85 ,1/i 3/85 41t 3/85 41t 3/,_,-.' 4/I t/85 41f ~/o~ .~. ,,' ,,.., ...~ 41t ":' / 8':'- .. 4/t ~/o,~' 4/t 0--t t 4/t 4--t 5/85 4/t 4/.q'= 4/1 4/t 4/t ~-t 4,/8E 4/t 4-tS/8_'5 RECEIPT ACKi'!OHLEDCED ' BF'AE CURRIER CFIEVRON H DIJTRIBUTION.: DRILLING W, F'ASFIER L. ,.JOHNSTON EXXON F, OB IL F'14ILL IF'£ OIL i'-.'~K CLERK d. RAI'HHELL ARCO Alaska, Inc. II a Subsidiary of AtlanticRIchlleldCompany APR 2 5 Alaska 0ii & Gas IC: A'F E: --AT.;7~;]or: ..... " . ~TE C:F AL. AS.'~I'.: ,-':.;~-~ _ . . 3'Ol.iIO UNION K ,Q'U[. I N/VALII_.T ARCO Alaska, h Post Office 8ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 6, 1984 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' Attached is our notice of intention to stimulate Kuparuk Field well 1G-1. If you have any questions, please call me at 263-4253. ~iike L. Laue Kuparuk Operations Coordinator MLL/kmc Attachment (In Triplicate) £C£1V£D o 7 · Ct~o,.age Com/~i.~ion ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASK/, O~L AND GAS CONSERVATION ~,~MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL 2. Name of Operator ARCO ALASKA, ! NC. 3. Address P. O. BOX 100360, ANCHORAGE, ALASKA 99510 OTHER [] 4. Location of Well SURFACE LOCAT ! ON- 895 ' FSL, T12N, R109E, UM 313' FWL, Sec. 29 5. Elevation in feet (indicate KB, DF, etc.) 91' (RKB) 12. 7. Permit No. 82-130 8. APl Number 50- 029-20805 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 1C;-1 11. Field and Pool KUPARUK RIVER FI ELD 6. Lease Designation and Serial No. KUPARUK RIVER O ! L ADL25640 ALK 2571 POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate ~[] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is proposed that a Stressfrac treatment be performed on Kuparuk well 1G-1. The process utilizes a downhole gas generator to stimulate the formation through the perforations. The tool is run on wireline under a lubricator and is handled similar to a perforating gun. Prior to start, all equipment will ANTICIPATED START DATE' November be pressure 12, 1984 tested. ~b-~.-aqu~at W ~o~'k Rq~t~l RECEIVED NOV 0 ? Alaska 0il & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. /~~.~~~ KUPARUK Signed Title OPERAT IONS COORD I NATOR The space below for Commission use Date 11/6/84 Conditions of Approval, if any: Approved by. COMMISSIONER the Commission ~pproved C'.. ~: ~eturned Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, ! Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 October 31, 1984 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 1G-1 Dear Mr. Chatterton' Enclosed is a Subsequent Sundry Report for the subject well. you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU2/L53 Enclosures If RECEIVED NOV 0 5 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc, is s Subsidiary of AtlanticRichfieldCompany STATEOF ALASKA ALASKA OIL AND GAS CONSERVATION L;OMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELLx~ OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well Surface: 895' FSL, 313' FWL, Sec.29, T12N, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) RKB 91 ' 6. Lease Designation and Serial No. ADI ?~R/~0 Al 14 _257! 7. Permit No. 82-130 8. APl Number 50- 029-2080S 9. Unit or Lease Name Ku~ruk e,.'ver Unit 10. Well Number ! r;,-! 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stim u late [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Accepted rig ~ 1230 hfs, 09/03/84. Killed well. ND tree. NU BOPE & tstd to 3000 psi - ok. Pulled tubing & recovered pkr. Set R-3 pkr ~ 7400'; tstd DP & csg to 3000 psi - ok. Set R-3 pkr ~ 7200'; pumped 25 bbls brine to perfs - brk down ~ 2100 psi - no returns to surface. Set R-3 pkr @ 6900'; tstd ann to 3000 psi - ok. Tstd lubricator to 500 psi - ok. Ran gauge ring/JB to PBTD - no recovery. Set 2-B W/L pkr ~ 7181'(WLM). Ran 3-1/2" completion assy w/tail ~ 7225', HB-1 pkr ~ 6835', 2-B pkr @ 7192' & SSSV ~ 1741'. ND BOPE. NU tree & tstd to 5000 psi - ok. Tstd tbg to 2000 psi - ok. Disp well w/30 bbls diesel followed by Kuparuk crude. Set BPV. Secured well & released rig @ 0600 hfs, 09/07/84. RECEIVED NOV 0 5 Alaska Oil & Gas Cons. C0mmissi0n Anchorage 14. I hereby ce,~y that the foregoing is true and correct to the best of my knowledge. The space w ission use Conditions of Appr~ if any: Approved by By Order of COMMISSIONER the Commission Date Form 10~,03 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Ir"'"" Post Offic~ =Ox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 October 23, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 1G-1 Dear Mr. Chatterton' Enclosed is a Well Completion Report for the subject well. you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU2/L34 Enclosures If RECEIVED -.;.; ,.~ (~?s Clans. Commission ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~-- ~-~ STATE OF ALASKA ALASt ~._ AND GAS CONSERVATION , .¢IISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL I~(X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-130 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20805 4. Location of well at surface 9. Unit or Lease Name 895' FSL, 313' FWL, Sec.29, T12N, R10E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1313' FNL, 274' FEL, See.31, T12N, R10E, UM 1G-1 At Total Depth 11. Field and I;°ol 1863' FNL, 534' FEL, See.31, T12N, R10E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 91' RKBI ADL 256b, 0, ALK 2571 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 08/13/82 08/24/82 08/29/82J N/A feet MS LJ 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 7970'ND,7002'TVD 7858'MD,6914'TVD YES [] NO [] 1741 feet MD 1500' (approx) 22. Type Electric or Other Logs Run DIL/GR, DIL/GR/SP, FDC/CNL, GR/BHCS, RFT, Cal, CBL/VDL/GR, DIL/GR, CBL, CCL/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 79' 24" 324 sx AS II ._10-3/4" 45.5# K-55 Surf 2239' 13-1/2" 1000 sx AS Ill & 250 s: AS I 7" 26.0# K-55 Surf 7957' 8-3/4" 595 sx Class G & 250 s: AS I 2~. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 6970' - 7019' 3-1/2" 7225' 6835' & 7192' 7063' - 7104' 7297' - 7301 ' w/12 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7311 ' - 7329' 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.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr') Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE I Form 10-407 GRU1/WC22 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. GEOLOGIC MARKERS NAME Top Upper Sand Base Upper Sand Top Lower Sand Base Lower Sand MEAS. DEPTH 6970' 7103' 7287' 7400' 30. FORMATION TESTS TRUE VERT. DEPTH 6209' 6~16' 6462' 6552' Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS . Wnrkov~.r W~_] 1 Hi 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Title INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-4~7 Oil.nd Gee Compeny O: Well History - Initial Report- Dally ~ Pr~pe~l and ~ubmR the "lnitlli RIIx~l" on Delly won~ prior to SPudding should District Field Kuparuk Field liter a well Is spuddad or wor'kover operltlona am mm'ted. ~-~ gl:ring inclusive dates only. ~, ~ or borough IState North Slope Borough J Alaska Lea~e or Unit Well no. ADL #25640 iC-1 W/O Auth. or W.O. no. Title AFE 103926/294561 Recompletion Nabors i-ES API 50-029-20805 Operator IARCO W I. ARCO Alaska, Inc. J 56.24% Spudded or W.O. begun IDate I,o"~ IPrior eta,us ,f a W.O. Workover 9/03/84 1230 Hrs. Date and depth as of 8:00 a.m. 9/06/84 9/04/84 9/05/84 Complete record for each day reported 7" @ 7951' 7858' PBTD, Top of Vann Fsh @ 7420' WLM, Tst'g BOPE 9.0 ppg NaC1 Accept ri~ @ 1230 hrs, 9/3/84. Pull BPV. Kill well by pmp'g 40 bbls 9.4 ppg CaCo3 pill, followed by 37.5 bbls brine, monitor well, well dead. ND tree, ~ & tst BOPE. 7" @ 7956' 7858' PBTD, Top of Vann Fsh @ 7420' WLM, Circ gas 9.0 ppg NaC1 RU & pull tbg, observe well, no fluid loss, POOH &std back tbg. RIH w/retrv'g tl & BHA, tag SBR slick stick @ 6840' DPM, wsh dn to pkr, engage & unseat pkr; well started losing fluid. SI well, circ, observe well. Prep to spot pill. (Accum fluid loss = 91 bbls). 7" @ 7956' 7858' PBTD, Top of Vann Fsh @ 7420' WLM, Rn'g 3½" CA 9.0 ppg NaC1 POH, retrv pkr. PU R-3 pkr, RIH, set @ 7200'. Pmp 25 bbl brine to perfs @ 7 BPM/2850 psi, POH. RIH w/JB & 6.125" gage ring to PBTD, POH. PU BOT 2-B W-L pkr w/tailpipe assy, TIH, set pkr @ 7181'. Prep to rn CA. ITitle 10/02/84 Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report tnslruclions: Preeare an(] submit, "-he "Final Report" on Ihs first Wednesoay alter allowable -as been ass~gr, ed 3r ..,ell ,s P~ugged. Abandoned. or Sold "Final Report" Snou~O be subm,.'led also when operations are suspended for an indelinde or 3oorec~able :engm. bt ':me On .,,orkovers when an official !est ~s not required uoon c-ornc,et~on, reoort comc.~etion and representatl~ lest date m blocks Drowdea T'~e "Final Report" 'orm may De use(] for reOorung the enhre ooerahon ,f space ~s avamlaele. J Accounl~ng COSl :enler code O~s,.:,c,. jcoun:y or Par!sh ] Stets Alaska Alaska Kuparuk Field Auth or W 0 L .... North Slope Borough or Unit J .',el; no J ADL #25640 [G-[ W/O T;?e Recompletion AFE 103926/294561 Nabors 1-ES AP1 50-029-20805 ARCO Alaska, Inc. i 56.24% ~013! '~urnger Of .we;:s i-SCflVe or ,qac[¢/e) ol~ Th~Sj [COS' Sen'er or'or t.D Dlugg,ng and [aDaecocmen[ of :n,s .well J Wo~kove~ J 9/03/84 J [230 H~s. gate an,3 as 0l 8 00 a m 9/07/84 Comc.,ete record 'or each c8¥ reOor.:ed 7" @ 7956' 7858' PBTD, Top of Vann Fsh @ 7420' WLM, RR Kuparuk crude in ann & tbg w/~20 bbl diesel cap on tbg RU & rn 218 jts, 9.6#, BTC & 5 jts, 9.6# EUE + 6 pups, 3~" tbg, space out & ind. Set BPV, ND BOPE, NU & ts[ tree to 250/5000 psi. Displ well w/30 bbls diesel, followed by Kuparuk crude. RR @ 0600 hrs, 9/7/84. SSSV ~ 1741' - SBR @ 6812' - He-1Pkr ~ 6835' - 2B Pkr ~ 7192' D Nipple @ 7213' - Shear Out Sub ~ 7225' GLM's: 7154', 6942', 6873', 6773', 6190', 5332', ~593', 3922', 3336', 2810', 2279', 1811' Old TD J New TD i =9 lb:tn 7970' i 7858' ~e~ease~ - ~ Date j<m.~ o' ' g 0600 His. 9/07/84 j Ro~a[v gas e:c Oil TyF. e -_*.m=~e:,On ~smg~e :_]'. el: Single Produc-og --'etP-od Official ~eser',,o~r ~a,~e,,s~ Flowing Kuparuk Sands gofer, ha; :est ~ata Well no JDa,e iq ..... -c,r P ....... g ........ Jc,i or iJ . JO, :~ :est Gas :et ~ay t · Pump s~ze. 3PM X ;englh I ~h ~e s~ze T P C ?. Water % ~ o iA,.c¢.as'e Effect .e The above ,s c,.~rec.' ~ ...... Ioa,e ,,,,e ?L.4__~,-- ~, C. ~~.~ 10/02/84 Drilling Superintendent ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 10, 1984 Mr. C. V. Chatterton Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton- Attached are notices of intention to fracture Kuparuk wells 1G-1, -2, -3, -4, -5, -6, -7 and -8. If you have any questions, please call me at 263-4253. Mike L. Laue Kuparuk Operations Coordinator MLL/kmc Attachment (In Triplicate) RECEIVED JUL ! 2 ].984 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ;': ALASKA OIL AND GAS CONSERVATION CO~v~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO ALASKA, INC. 3. Address P. O. BOX 100360, ANCHORAGE, ALASKA 99510 313' FWL, Sec. 29 4. Location of Well SURFACE LOCAT I ON' 895 ' FSL, T12N, R109E, UM 5. Elevation in feet (indicate KB, DF, etc.) 91' (RKR) 12. 7. Permit No. 82-130 8. APl Number 50- 029-20805 9. Unit or Lease Name KUPARUK RIVER UN I T 10. Well Number 1G-1 11. Field and Pool KUPARUK RIVER FIELD 6. Lease Designation and Serial No. KUPARUK RI VER O I L ADL25640 ALK 2571 POOL' Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [~ Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). it is proposed that the "A" sand in Kuparuk well 1G-1 be hydraulically fractured and propped to improve production. The treatment'uses gelled water as the pad and carrying fluid and 12/20 sand as the proppant. Lines and equipment will be pressure tested to 5000 psi prior to starting job. Radioactive tagging of the proppant an~ pre-post frac logs are included in the treatment program. Fluid. Proppant- Gelled Water 12/20 sand ANT ICI PATED START DATE: BBLS 167 LBS 7500 July 23, 1984 Form No. -------- p~t~ ~/--/-- RECEIVED J U L I 21984 Alaska Oi~ & Gas Cons. Oommission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. /////j~~/~Z,CA_9~ KU PARUK Signed Title OPERATI ONS COORD ! NATOR Date The space below for Commission use 7/10/84 Conditions of Approval, if any: LOH IE C. St ITIt Approved by COMMISSIONER Approved Copy Returned By Order of the Commission Date Form 10-403 Rev. 7-1 ~80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. ' Post Office B~... 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 28, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT: 1G-1 Dear Mr. Chatterton: Enclosed is a Sundry Notice for the subject well. We propose to convert 1G-1 to a selective single completion. Since we expect to start this work on July 18, 1984, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, J. B. Kew in Area Drilling Engineer JBK/JG/tw GRU8/L20 Enclosures RE£EIV£D jULo2t, Alaska 0ii & Sas Cons. Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA ~..- AND GAS CONSERVATION C~ ,vllSSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I~x 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 82-130 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20805 4. Location of Well 9. Unit or Lease Name Surface: 895' FSL, 313' FWL, Sec.29, T12N, RIOE, UN Kuparuk River Unit OTHER [] TD: 1863' FNL, 534' FEL, Sec. 31, T12N, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) RKB 91 ' 6. Lease Designation and Serial No. ADL 25640 ALK 2571 10. Well Number 1G-1 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing ~, Other ~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a subhitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonmentsee20 AAC 25.105-170). ARCO Alaska, Inc., proposes to convert well 1G-1 to a selective single completion. The procedure will be as follows: 1. The well will be killed with brine. Weight to be determined after running pressure bomb. 2. The current completion assembly will be pulled. 3. The well will then be completed as a selective single. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. BOP equipment will be tested weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. The subsurface safety valve will be installed and tested upon conclusion of the job. Estimated Start: July 18, 1984 o~ Term ~°I RECEIVED JULO .Alaska Oil & Gas Cons. Comml~lofl Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Area Drilling Engineer COMMISSIONER JAPproved Copy Returned . _ By Order of the Commission Date Form 10-403 GRU8/SN10 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate he STRESSFRAC system represents an advanced well stimulation technique designed to complement and enhance current completion methods. Through the use of powerful downhole gas generators, the process permits the initiation of multiple horizontal fractures at most well depths and conditions. Multiple or large zones may be treated without having to isolate previ- ously treated intervals. Furthermore, the risks of forma- tion damage due to swelling or emulsions are greatly reduced since non-reacting gases are the primary fracing media. Today's STRESSFRAC process is the result of twenty- five years of development history, backed by active on- going research and quality control programs. The technique has been successfully applied in over 4,000 well completions, covering a wide range of cased and open hole applications, and at treatment depths from as little as 400 feet to over 14,000 feet. Minictture STRESSFRAC test in unsupported perfora, ted pipe. Perforations were plu~ed with. plastic, a~zd pipe was filled with .s'itnulated well fluid. No packoff was provided at h,p. High ,speed film fratne, 2 milliseco~ds after ignition, shows incande.%e~t gc~.se.s' (~t~.d well fluid escaping unifor~l_y £rom c~ll perforatio,s. le e e e e e 7~ 8~ 9~ Characteristics Extensive observations indicate that STRESSFRAC creates horizontal and multiple fractures radiating in all directions from the well bore, greatly enhancing communication with the reservoir. STRESSFRAC does not depend on acids to achieve formation breakdown and consequently, the creation of damaging emulsions is prevented. The High Gas Transfer velocity, coupled with fracture propagation rates of approximately 300 feet per second, erode the fracture, preventing healing and largely eliminate the need for proppants. Although the STRESSFRAC pressure-time profile is measured in milliseconds, the event is sufficiently slow to insure partial pressure equalization behind the casing. The chance of excess pressure on the cemented casing is therefore minimized. Due to the inherent efficiency and simplicity of the system, it is extremely cost effective when compared with other methods. STRESSFRAC can pinpoint fracture initiation in a precise interval, thus optimizing subsequent hydraulic treatments. The STRESSFRAC process effectively breaks down and cleans casing perforations. In the controlled, elevated gas pressure regime associated with STRESSFRAC, the mechanism of formation fracture initiation has different characteristics and does not take the path of least resistance as invariably occurs with hydraulic applications. Therefore, treatments close to oil and water contact are more likely to stay in zone. APPLICATIONS" 'FOR STRESSFRAC Primary stimulation is Possible in certain· permeable reservoirs, which respond to' STRESSFRAC directly without need for addi' tionalffeatment. ' -:.. . perforation breakdown and perforation extension, by microfracturing, can be achieved in lieu of hydraulic methods. Skin damage, due t° mUd Or cement inva;.-i sion, can often be overcome. '. · , . :: - Tight formations, exhibiting high breakdown-' pressure, can be preconditioned with STRESSFRAC.. · .:. Fractured reservoirs have been successfully. treated, preced!ng large hydraulic or gas treatments.: .. Open' h°le completions have been achieved . selectively, w_!thout the use of packers. Through tubing, STRESSFRAC operations'i.- are carried on routinely to depths in excess of 14,000 feet. ' ' Swelling. clays are not affected by the gase- ous proddCts. · Carbonates · and sands ~ have responded favorably to this treatment as an intermediate .- - step prior to'high volume fracs~ ' .";~ ~ ' ~ ,~' .~' . ¥. , ,,.- , ,:. Additional aPpliCations for STRESSFRAC in: : "" -.-:' dude pre-fracing, zone teSting, pre-drill stem-:: - ¥: -testing;-' mUltiPle; Completions, injeCtion' and.? -.:~'-. dispoSal"~/ells;.'~:.~: :~.~:~' ~: '''.'::i-~!'r: ;: :' Fluid heads of several thousand feet are advantageous in the application of STRESSFRAC, although special well conditions sometimes compel the use of less than 1,000 feet. The type of fluid in the well bore should be compatible with the formations to be stimulated and may consist of produced fluids, KCL water, or other more exotic combinations. Repeat STRESSFRAC test~-~'-~, Ignition Dynamic process using controlled high pressure gas to initiate dpropaga e multiple fractures 15 milliseconds later Combustion gases and well fluid are escaping from all perforations at over 600 ft./sec. 30 milliseconds Uniform energy transfer is maintained. 45 milliseconds Residual gas pressure is maintained by short fluid column at top. The Process The STRESSFRAC system centers around a unique proprietary propellant and associated ignition system, which are both highly controllable. Pressure rise and peak pressure characteristics of the system are set to maximize the rate of energy transfer to the formation resulting in fractures, while remaining regulated enough to permit its use in properly perforated, cemented casing. In a typical application, a cylindrical STRESSFRAC tool is lowered into the zone on a standard wireline under a substantial fluid head. Upon ignition, the propellant through its combustion converts into a large quantity of gases, such as CO~, raising the pressure in the well bore to the point that within several milliseconds the first fractures have been initiated. The gas generation process, however, is sufficiently sustained so that the first fractgres cannot absorb all the gases. This causes the pressure in the well bore to rise further, creating additional fractures, until an equilibrium is reached. The exact point of maximum pressure reached depends on the proper match between the specific well characteristics and the STRESSFRAC tool dimensions. Fracture propagation rates of over 300 feet per second are possible with this system, which makes available a driving force of over 100,000 horsepower directly at the producing zone. The formative portion of the event, including fracture extension, is measured in terms of lO0 milliseconds. The terminal phase, which is characterized by a rise in the fluid column and backflush of the gases from the fractures, is measured in terms of several seconds. Copyright 1984 Multi-Zone Capability Utilizing the latest state-of-the-art impulse method, STRESSFRAC provides an effective means for breaking down perforations, initiating fractures, and overcoming skin damage in oil, gas, injection, and disposal wells. While STRESSFRAC does not replace hydraulic or other high-volume, Iow-rate treatments, it does offer significant advantages as a prefrac stimulation tool. In numerous reservoirs, this process provides the additional advantage of a primary stimulation service. STRESSFRAC is ~ proven method uniquely applicable in a large number of situations where customary stimulation methods are not advisable. Multi-Frac Application For well servicing and technical information contact: EXCLUSIVE MANUFACTURER OF STRESSFRAC TOOLS Rt. 1, Box 132E, Rodd Field, Corpus Christi, Texas 78415 (512) 993-2475 Colorado (303) 762-1608 Kansas (913) 625-4894 In Canada contact: #200, 215 10th Ave. S.W., Calgary, Alberta, Canada T2P 0A4 (403) 290-1700 #25, 7875 48th Ave., Red Deer, Alberta, Canada T4P 2K1 (403) 347-8255 SERVING OHIO end WEST VIRGINIA INCORPORATED Rt. 1, Box 17, Marietta, Ohio 45750 (614) 374-2655 SERVING · EASTERN UNITED STATES Rt. 1, Box 17, Marietta, Ohio 45750 (614) 374-5161 ~ ~ SERVING OCKY MOUNTAIN AREA P.O. Box 2258, Billings, Montana 59103 (406) 259-5065 730 W. Hampden, Suite 306, Englewood, Colorado 80110 (303) 762-1608 STRESSFRAC~ is a trademark of SERVO-DYNAMICS, INC. Printed in U.S.A. KUPARUK E~GINEERING :, z__.~ TRAHSHiTTAL ,~ ,,~~'~ FROM- D. Fay Allison TO: DATE' / ~P. ~ ~', bO..~ WELL NAME' see Transmitted herewith are the following' PLEASE NOTE' BL- BLUELINE, S-SEPiA, F-FILM, T- TAPE,~~- PHOTOCOPY Well /~-/ Des~ript ion Date Run ?~/~-? ~ ~/. RECEIPT ACKNOWLEDGED' ~~PLEAsE RETURN RECEIPT TO' ARCO ALASKA, INC. ATTN' D. FAY ALLISON - ATO/lll5-B P. O. BOX 100360 ANCHORAGE, AK. 9951.0 KUPAF...2]K EI"E; 1NEERI TRA~L~,I 11-FAL Transmitted herewith are the fol l(wvin9' PLF_ASE NOTE: BL - BLUELINE, S - SEPIA, F - FI~A, T - TAPE~ ,~'~FT AC_J4~O,;,fl ~ED: PLEASE RETURN RECEIPT TO: ARO3 ALASI(A, II,C. ATI'N: SHEIJ3Y J. MAI-II-IB:;/S - Al-O/111 5-B P. O. EOX 100360 AI',E]-tOP¢,GE, ,A](. 99510 Transmitted herewith are the following: D. W. Bose/Lorie L. Johnson . _ PT.FASE NOTE: BL- BIATEIff/~E, S - SEPIA, F - FIT~I, T- TAPE, ATIN: LORIE L. JOHNSON - AFA/311 P. O. BOX 360 · ANCHORAGE, AK. 99510 TO: William V~en D. W. Bose/Lorie L. Johnson Transmitted herewith are the following: PI,FASE NOTE:~~ F. -~ FIL~I, ~PC_.-PHOTOCOPY RECEIVED NOV 2 ~ ]982 Alaska 0il & Gas Cons. Cc~nmis~,ion · -Anchorage . ~/I/:~T A~, ~ DATE: P. O. BOX 360 ANCHORAGE, AK. 99510 KUPARUK ENGINRRRING D. W. Bose/Lorie L. Johnson Transmitted herewith are the following: PT.FASE NOTE: ~L- BLUEL~~ F- FILM, ~ PC - PH~PY RECEIPT ACKNfTWr.kn~SED: PLEASE RETURN RECEIPT TO: ARCO ALASKA, INC. ATIN: LORIE L. JOHNSON - AFA/311 P. O. BOX 360 ANCHORAGE, AK. 99510 RECEIVED NOV j. ~s I982 Alaska Oil & Gas Cor~s. Commission /~nchorage ARCQAI~ska, inc. ...----- Post Office.Box Anchorage, Alas~,a 99510 Telephone 907 277 5637 October 14, 1982 Mr. C. V. Chatterton Commissioner State of Alaska' Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton' Enclosed are monthly reports for September on these drill sites' 1-19 18-6 1-20 18-7 6-21 1E-28 6-22 1E-29 13-16 1E-30 13,34 1F-6 1G-2 1G-3 WSW-3 WSW-4 A1 so enclosed are well completion reports for' 2-26 1G-1 6-20 14-15 (completion report & subsequent sundry report) 1E-17 1F-5 The survey for 2-22 needs to be reran; a completion report for this well will be submitted when an approved survey is received. Sincerely, . P. A. VanDusen District Dril ling Engineer PAV/JG-11m Enclosures GRU2/L15 ARCO Alaska, Inc. is a subsidiary of AllanlicRichfieldCompany ~-*~ ~:' STATE OF ALASKA -.- ALAS, ~_ AND GAS CONSERVATION vllSSION WELL COMPLETION OR RECOMPLETION-REPORT AND LOG 1. Status of Well Classification of Service Well OIL I~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] - 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-130 3. Address 8. APl Number P.O. Box 360, Anchorage, Alaska 99510 5o- 029-20805 4. Location of well at surface 9. Unit or Lease Name 895'FSL, 313'FWL, Sec. 29, T12N, RIOE, UM ~~ Kuparuk River Unit At Top Producing Interval ! VERiFiED ! 10. Well Number 1313'FNL, 274'FEL, Sec. 31, T12N, RIOE, UM tsurf._____~ 1G-1 At Total Depth lB. H, [~:: 1 1. Field and Pool 1863'FNL, 534'FEL, Sec, 31, T12N, RIOE, UN' ~ Kuparuk R~ver Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 91'RKB ADL 25640, ALK 2571 Kuparuk River Oil Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 8/13/82 8/24/82 8/29/82 N/A feet MSL 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set I 21. Thickness of Permafrost 7970'MD, 7002'TVD 7858'MD, 6914'T~D~Es[~ NO[] 1919' feetMD 1500' (approx) 22, Type Electric or Other Logs Run DIL/GR, DIL/GR/SP, FDC/CNL, GR/BHCS, RFT, Cal, CBL/VDL/GR, DIL/GR, CBL, CCL/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 79' 24" 324sx AS II 10-3/4" 45.5# K-55 Surf 2239' 13-1/2" lO00sx AS III & 250sx AS I 7" 26.0# K-55 Surf 7957' 8-3/4" 595sx Class G & 250sx AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 6970' - 7019' 3-1/2'" 6892' 6857' 7063' - 7104' 7297' - 7301' w/12 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7311 ' - 7329' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A ~/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR iCI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED.~, OIL-BBL GAs-McF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None . ..... i ii.,' ': '~' C,: :-,.'4^ '~ Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. NAME Top Upper Sand Base Upper San( Top Lower Sand Base Lower Sand GEOLOGIC MARKERS MEAS. DEPTH 6970' 7103' 7287' 7400' TRUE VERT. DEPTH 6209' 6316' 6462' 6552' FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS Drilling History, Gyroscopic Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge S'gned__ ~. Title Sr. Dril 1 i nq Enqr~ate z/ ,,/ INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24' If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form !0-407 1G-1 DRILLING HISTORY NU Hydril & diverter. Spudded well @ 2000 hrs, 08/13/82. Drld 13-1/2" hole to 2255'. Ran GR/DIL f/2255'-80'. Ran 53 jts 10-3/4" 45.5#/ft, K-55, BTC csg w/shoe @ 2239'. Cmtd 10-3/4" csg w/1800 sx AS III & 250 sx AS I. ND Hydril & diverter. NU BOPE & tstd to 3000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new hole. Tstd form to 12.5 ppg EMW. Drld 8-3/4" hole to 7470'. Ran DIL/GR/SP, FDC/CNL, GR/BHCS; could not get past 4360'. Reamed f/4350'-4410'. Ran DIL/GR/SP/FDC/CNL/BHCS. Ran RFT - unable to get sample due to tool failure. Ran Cal& DIL/GR. Shot sidewall cores. Reamed f/4330'-4460', 4590'-5200', 5400'-6000', & 6766'-7470'. Cont drlg 8-3/4" hole to 7970'TD (08/24/82). CBU. Circ hole - mix and pump 30 bbls Hi-Vis sweep pill. Mix & spot 40 bbl Soltex pill at TD. Ream f/6543'-6968'. CBU @ 6948', RIH; hit tight spot @ 6998' & stuck pipe. Worked pipe free. Reamed f/6905'-7700'. Ran 175 jts 7", 26#/ft, K-55, BTC, ERW csg w/shoe @ 7957'. Cmtd 7" csg w/595 sx Class G cmt. Instld 7" packoff & tstd to 3000 psi - ok. Ran gyro f/7800' to surf. Ran CBL/VDL/GR. Arctic packed 7" x 10-3/4" annulus w/300 bbls H20, 250 sx AS I, & 97 bbls Arctic Pack. Ran CBL to 2000'. Ran 3-1/2" completion assy w/tail @ 6892' & pkr @ 6857'. Ran CCL/GR. Tstd tbg hanger and packoff to 3000 psi - ok. ND BOPE. NU tree & tstd to 3000 psi - ok. Displaced well w/diesel. Dropped bar & fired guns. Flowed well. Dropped ball to release guns ( estimated top of Vann Gun fish 7420'). Closed SSSV @ 1919'. Set BPV. Secured well & released rig @ 1800 hrs, 08/29/82. TRUE,,:.,. lEAS, DR'! FT ':'¥ER'T-,]:CAL ,EPTH .fIG,LEi" D I'1 :0 ~0 3:0:0. O. '16 4',00 ,0 14 540 O, 20 6;00 :0 !4 ?,;0~0 ':. :0 . ,24 8:0.:O ,9'0.0 1'00.0 1 2,0.0 1'3,0.0 14.1:):0 16:0,0 1 180'0 2..0-0.0 2'1 O0 23:00 0 17 0 10 :0 '20 0 22 :0 ,0 28 '0 ! 2 1 6 1 2 0 50 0 54 0 59 'I 'I 4 1 I:0 1 4 I 20 'i,.699,99 - 799,99 /' 899.99 999,99 1:099.99 1 ! 99.99 ! 108.99 1299 ,'99 12. 08'~ 99 1399,98 1:-308,98 1499.97 '1408.97 1599.95 1508,95 1699.93 1608.93 1 799.92 1708,92 1899.91 1808,91 1999,89 1:908.89 2:099,87 2008 ~ 8?' 2199,85 2108.85 2299 . 83 2208,83 2399.81 2308.81 N -6,83E S43.. 17W S26, .02W <337,47111 S35.40U S42 ~ 38W S44.43U $75;37U $77,35W H36,68W N40. 57W N35.97W N37,.ISW 91 ,',!0,!0 ,,/:,~ A: ' : ':~! ?," ', "'-'"'i~ :~ .... · · ' .::',i"'~, ,, .' ..... c ~ - ~;' .: ' '.' ,',:,,; . 'c'?, · DOG LEG ~:.~. ' ' C':~'';"G ,E '~::~ SEVER I TY '~:' pi $~ ~NC ,: ANG~:"",: DEG/1 0 OFT ' :.. D M S 19 'E :57 E E ..S r ific .58 E .i'. 45 E ,18 E .16 W ,78 W 1,62 W · 2,73 W 3.9.0 W . ,o2 U ."'6,3.1W 9,53 S ' .. 7,91 W ' ,. 8.89 $ :i..".<..9,62 W 7,26 $ ....... :10;93 W ,'5,73 $ !":.'-:;.12,13 W 4,05 $..-:"'- "13,.38 W ... ,.. ,. .~. 54' S 20 43 7 ,73 S 52 5 32 ,?:0' $ 85 33 58 ,44 H 53 47 5'0 ,04 t, 02 1 '1 .71 2,25 2.17 2.01' 3,0'1 4.56 6.38 8.20, 9.78 11 ,11 12,38 '13.10 13.12 13.42 13.98 N 54 6 5'0 $ 9-14 34 $ 32 48 59 $30 15 6 S 19 56 39 S 11 2.6 49 .S 4 49 18 S 4 30 29 S'15 4 38 S 20 50 18 S 25 20 25 S 28 23 22 $ 30 51 49 S 34 36 26 $ 39 40 38 8 47 14 48 8 56 24 24 S 64 43' 37 S 73 .1 O 24 E E E W E E E E E E W W W W W W W W W W W W · 000 ,233. .033 ,067 · 033: ,100 ,100 . '167 ,117 ,.I 17 ,167 .033 ,267 ,367 ,2:3:3 · 067 · 067 .200 · 067 ,08:3 ,252 · 067 .100 $ECTIn~ DISTA~ , '00 ,20 ,42 . ,26 -.15 -,35 -,01 ,45 ,65 1 ,37 1 ,98 2,nl 1. :3.01 4,55 6,31 8,04 9,50 10.59 I1 .43 11 ,33 10,15 9,04 7,80 0 RCO .KUPRRUK, : I ' m "TRUE tEAS, :'DRIFT . YERTICRL iEPTH tINGLE DEPTH D H 25':0:0 I 44" ... 2499 2.6:0.0 2'2;0" 2599.,71 2~,00 2 2 '....L 2699, 28~'..0 '4 29:.0'8 ;' 8 29 300:0 '12 43' 31 '00 32;0.:0 33:0.0 3509 37-&0 3.8:08 39:0:0 · 4 0:013 4'I 1013 43:00 44:0-0 45;0:0 4600 4700 48013 490.0 5000 51'00 52:0:0 16 3 1.7 46 1.9 32 2'I. ~0 23 3 25 7 .26 37 28.29 3'0 23 32 21 .34 8 35 59 38 ~0 39 38 41 49 43 58 45 11 44 59 44 42 44 32 43 "55 43 41 43 .7 2.799,5'0 .2898,88 '2997.15" 3094, ,00 ' 31,89',67 :,3284 ..42 '~i 337.8, 347'0,92 '3562,2'1 · 3652, '19 3740,85 . 382.7,9.4 3913,32 3996 ,'95 4.078.81 : 4.158.. 67 -4236,59 431.2,37 4385.63 - 4456.86 4527;47 4598,37 - 4669,55 4241 4813,39 4886 .'.05 GYROS ,,0 coPxC' ,SURVE:y,..: ,, . JOB NO 1,40'1 ~'SER ,~ r D,R l FT' TES "DIREC 3649 3736 3822 3905 3987 4067 41.45 4221 ' 4294 4365 '2906,15:':.:;",S 6 3 0:03 ~,00 ''~;' 3.098.67 3193,42.. 3287', 23 33?9 ,' 92 3471,2! .3561, t9 ,85' · 94 ,32 · 95 ,81 ,67 S 9,SOW ,59 S 9,77U ,37 S .63 S I I, 05~ ,86 S 4436,42 S 4507.32 S 65~8,55' S1 4650,21 811 .97~ 4722.39 4795.05 S12~978 ,~iy:'i 4'.'91 U ?':28 ;:82 W", .86 ~' 8 .7,,52~ S 8~ 55~ s S 9,08.W '' S 9;'3714'.':~: S 9.,35~'~' 263,9 S 9,15N"?. 309 57',:.~ .~:.., '..'~:'76 ~ 05 s e.'==U'?.,, ~s:.Oe,, S~":'.~,:',' ~'"" ,",83.;'~4 u 641 , 39. S >".[~,,; 1:3 O, 69 ~ .':" . 841,31 $ ,¥' .-168 . 58 ~ t 84,57. S "': "23~, 5~ u ,' ,:;: 1251,58 .. S..{~::,. ~: 254 ,'? ' ,, , ,: - '..~., . , ,,", ,. ,: '.~ ...'~.. ::.,. ,:... ~:..:, '.. .. ' , , ... ., DZSTRNCE RNGLE D H 15,~02 S 82 16,92 N. 86 19,79.H 78 24.24 N 81 29,49:$ 77 40,77. S 53. 6'0,52. S 36 87,,'09~$ 26 1 I?,-80,:'8 21 151,74 $ 18' 188..79::'S 16 72:7'0'.9.14 3t.8,78 S 13' ..367,.78 $ 13 4'19.73 .S 12 4~4.46 $ 12 531,82 S I1 591,93 S 11 654,57 S 11 719.79! S 11 Z87,85 $ I1 '858,03 $ 11 928,84 S '11 999.36 S 11 1'069,59 S,'!1 1139'34 8 11 12.08,55 S !1 '1277,24 S 11 0 1'0 SEPT 82 DOG LEG SE,VERITY DEG/IOOFT 17 39 ~ 26 49 ~ 4'6 48 U 47 38 U 41 28U 14 57 W 54 38 W 52 2O bJ · 53 32 b/ 55 54 W 33 51-W. 34 24 Gl 48 7 W 11 32W 42 5'0 Gl 19 11 Id 59 5 W 42 58 Al 31 0 (~ 23 21 W 20 2 kl 19 50~J 2,0 57 W ;21 29 W 21 41 kl 23 1W 25 58 U. .4'00 .600 .300 2. 025 4. 496 4.273 3. 333 I .718 1". 770 I , 467 2,050 2,067 1 ,500 1 ,867 1 ,900 1 .967 1 ,784 I ,850 2. 020 I ,637 2.204 2,169 1 ,241 ,204 ,316 .182 ,659 .351 ,604 SECTION DISTANCE 6, 3.91 ! ,9o 3,;73 . 14,4~ 32.73 57.1~ 85,81 117.39 151,66 188.79 A29,21 272.44 318,26 366,94 418.51 472, '529,?'2 589.34 651,49 716,25 783.89 853.72 924.21 994,38 1064,28 1133.72 1202,69 ~271.2o ~R:CO KUPI-'qRUK G-:I r . ~rr~GYROSC · IEI~S; ~EPTH 1 'RNGLE .54~0 '42 52 550~0' 42 !4 ( TRUE "DR!FT VER DEP:T,H 5'6~.,0 4'I .3.8 57~0!0.' 4 0 .44 58~00 39 5:0 '59,.04 38 17 6.0..00 36 47 6'I'~0~ 35 37 62:0~) 34; 38 63.0:0 34 31 64'00 35 2 65~:'0:34 29 ..6600 34 50 67~:0~ . 34 58 68!00 35' 26 69,'00 35 31 7099 36 29 ?'1'~0 3.? 21 72~0 37 4 73O..,0 37 14 74~-0~ 36 48 .75~)~ 37.32 7600 37 47 77~0 38 13 7800 38 12 · .§032 ,' 86" 4'941",',' ..:.5 o7 . :50!6..,25 -81 5258~80 5167,80 :·'.'::, $1:~,;53U 5336,45 5496,44' 5578,2.3 56 60,5.7. 5742 ,'71 524'5,45 .5324',.74 · 5405,44'. 5487:; 23 5569,5.7" 5651 , 71', 5824., 86, 59.0.7,12 5989,13 607,0,85 6.152.28 6233 ,'18 6313, '13 6392,78 6472.48 6552,33 6632',~02 6711;18 6789,99 6868,56 5733;86 ..... 'S23,~188 19 5816,12 5898,13 5979 .. 85 6061 , 28 6142,18 6222,13 6301,78 6381 ~ 48 . 6461,33 6541 , 02 662.0,18 6698,99' 6777,56 JOB NO 1.401 S22 63[~1 233~ 21 8. '" , , , · 822.7.7~1- 239'0,92 ..;~::':.,. 664,44 $23 40~ 2446 3.0~..~ · , .... :~. '"-, ~ S2.3;67~ . 250'1,69".8 825,35~ 2557,28 $ .~. , S27.37~ ~ 26t2,44 S S30.:03~ · 2666,69 , .., , rHE FOLLOWING IS EXTRRPOLRTED TO. TD 797I) 38 12 ,7002,16 6911,16 830,03~ 'R,,' P" i".'~, H .. :., .. 1.. 34" 3;3 Id- 1'.(38'"57, bt 1 44 2 ~ 1 .50, 18 'W 1 ..'!672;·.95 S'::,.12 8 .30 ~ 1.848~8].:':.8, 12 55 4 W '1904~;88 $:'!3~tl 3 ~ 17,.51_S'.13 42:34 a 14 14 42 U 14 30 23 ~ 14 44 53 a 14 57 48 W ~5 9 49 ~ 242],62 S ~5 21 8 ~ 2481 ,53 S 15 3l 50 ~ 254l~22,.~$ t5 '42 33 ~ 2601,09.~ 15 53 25 ~ 266],50 S ~6 5 14 ~ 2722,10 S 16 !9 6 W 2782.54 S 16 35 29 W 2884,'90 8 17 4 36 W SEPT,: 82 .DOG LEG' SEVERiTy DEG/I'OOFT .657 ,632 ,973 ,975 ,747 .650 .382 '.'987 .292 ,517 .621 .412 .169. .467 ,256 ,994 ,867 ,294 .1,74 ,489 .740 ,680 .885 ,020 ,0'00 SECTION· DISTANCE 14 06.6:7 1539,13 1603,75 1666.75 1 727,65 1786'. 59 1843 1900,49 1957 ;29 2014.02 2'0'7 O. 53 2127,33 2184,52 2242, ..zoo. 236 0.35 2420,52 2480,62 2540,50 2600,53 2661.1' 1 2721 .86 2782,. 4.4 . 2884,9'0 ,: IRCQ KUP~RUK G-! .., · IEtqSuRED DEPTH AND":OTHEE DATA FOR HEIASURED.,: : ,~, ~0 191 '391 491 "' 591 ~ 791 ': '::' 89 !' :?.. 1091 <_.~ 1191 ?:'.. :1391 7t491 : ' .1591 '1691 1791 2091 2191 2291 2391 2491 2591 2691 2791 2892 2994 3097 3201 3307 3414 3~22 ~TRUE..: ;¥ERT !'CAi _ . ; "' 'O', /" 4 0'0 oo .1,491.,... -1400' .;:~'...,... 1,59!. ' 169.1, 179!, 1'69 ! 1:991, '., '2091 2191, 2291. 2391, 2491, 2591., 2691. 2791 . 2891. 2991 . 3091. 3191, 3291, 3391, 3491 GYROSCOP] · 1600 'I 70'0 1800 1900. 2000 ' 2100 2200 2300 2400 2500 260'0 2700 2800 2900 3000 3100 3200 3300 .3400 0 0 0 0 0 0 1 2 5 I0 15 22 30 8,30 ,', 9,1 0 'S 9,5.05 7.4O S 5..86 S · 4,21 $ 2,07 S~' ,81 N .3.7~ N 3.,82 N ~.'17 s. 22.79 S ,. 47,96 S ?e.'os s I!1,65 S '148,44 S ::189,13 S 4,92 6,18 7,76 .9;50 10.81 12,04 13;26 '14,77 16.69 19,16 23,59 28,41 32,67 35,68 39.47 44,24 49',89 56.; 35 W W W W W W W W W W W W W W W 0 10 SEpT 82' :iRCO KUpIqRUK G-! .. GYROSCOF,!C, SUg ~Ei.~SrURED DEPTH AND/OTHER 'DATA FOe EYERY:'EVi DEPTH .. 363'2 3744 3.857 3974 '" 4'093 ,., 42!5 '.' 4341 4471 4,607 ' .4748 4890 5030 51'69 5,3O? ,,5443 · 5578 -571 I 5842 6093 6216 63:37 6580 6702 6948 7',072 7198 7323 7448 7575 7701 7829 ,,, VERTICAL ,SUIB HD'TVD ..... DEPTH SEA,:,i:D IFFERENC! .?.,, '~,~.~ 3~9't,,", 3991 .;' 36 ,~4091. : 400'0 4191, 41 00 4291 -, .42 0 4391 449'1'~ 4400,, 459 l ~4691 :. 4891., /!:480 499i ,- 5091:; 5191 ~291 5391 ,, 5491 5691 .. 5791, 5~91. 5~91. 60~ 1 6191. 6291, 6491 6591. 6691 ~791 6891. 69~I 5qO0 ":.'.~i 48? 51 O0 ;. ;'/'~',520":'"' ,.,.;:,'.,~: 53.o0 ' 578 .- -::i~: ":::"28 5400 . ,, 5500 5600 5700 . . 5800 5900 6000 ~1 O0 ~200 6300 ~400 6500 ~00 ':.. ',, ~700 . '. ,, 6~00 6900 602 624 645 667 '689 711 733 756 -701 8O6 832 '857 083 · .910 937 964 . I JOB,NO i,401: SEA DEPTH; 337 ;:05 687,T:02S 67,4,,88 ia~6;o9 s 2.065,63 2130.10 2195,65 .2263,94 _ 25 ' ', .2333,96 $ , ., 26 ' r . ''~ · .. 24.03,83 25 ':: *': :'" 2473,.01 8 ,.. ~:,,,.::,.%~. ~,.,, ,. ~ 27..~-.,,,.~,~::~,~.~ :.: :... · 2613., 1.5 S fi ,' , ,. ,>, , ..,,,' ..,, . 2,~.,r-:,....:....,..,.,., - 368'1 98 $ ~ ~.:~;/':?:'~"' :%' .:"?'... ' . 2,750 '.! 0 S t," - --?/' ':'~?'"" ?'"¢ """;' ':':"' . ' ' DZHATES , ; 8:0 $ ':":'.'"~:'::'297 ', 52 W 77 $ ?~.. "318,93 W 341',20 365.14 390.67 416.54 · 442,45 469,02 .... · 496.33 · '-524,65 -553.63 582..32 6!1,23 640,62 669.88 699.64 730,88 '' 765,21 eo3.36 · 842;77 1.608,67 1675,65 1744., 88 181.'0.. 22 !8.74.1! !'.938., 53 2 00'1; 94. W W W W W W W W W W W W W W W' W W .. 0 1 O SEPT 82 .I'RCO, KU, P~RUK . G'I (~YRO$CO~!C ~IER'SURED DEPTH RHD'?.OTHER DR.T.R:'EOR EVERY,' E¥.Et DEPTH '~'' ' ,'i ".:..".JOB '. H0. ! 41!01 · ER DEP.TH., 0 SEPT 82 2 ~0 0,0 2997, . . GYROSC 'p T z © ::t'RC:O KUPIqRUK G-'I ~YROSCOPiC [NTERPOLnTED TRUE MER'T'Xcn,F,DEPTHS,,:COORD : TRUE ::ODE .... HEASUR'ED ~AHE. DEPTH TP'/.'UP.' SlqHD '. '"' 69.70 9'S'/UP S. RND ,:..'.. ?'t.,03 ,, rP/Lbi SaND .aS/LI~ ,S~ND ~,, ,74'0,0 ~BT . 7858 _. '.. ~;."~ ~.,.... 62'09 dOB NO 14:0'! :L,OSURES FOR GIVEN DEPTHS CLOSURE ,"D'! STRNCE RHGLE -'p ~ s 1.0 SEPT 82 SUB SEA :ScientifiC".'..'_ ,.'Drilling 'International 0 . o · . . ' - . ~ '-' ' . . - : : I . ; ' ~ ~ . 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' : i I-- ;~_: ' ~ : | : i 'i ! ] : ; ~ :] : ~ ; ~ ; : ;.j i : : ; : : ,j ; i ~t ' ! : - ! ; ' - .:'~ - ' ~' - - Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. Reports and Materials to be received by: ?--~ ~' Date Required Date Received Remarks . ., Completion Report Yes,, / .Well History Yes - -_ _Samples ~- .... ¢ ' ' k~ '! Core Chips Core Description _ Registered Survey Plat ~ , Inclination S~ey /~'~ I' . ~.' ..Drill. St~ Test RemUs z~'ff~/, ~s R~. Yes TO: william VanAlen FROM: D. W. Bose/Lorie L. Johnson Transmitted her~,ith are the following: P~.VASE ~KJrE~B~~ F - F77~I, T - TAPE, PC- PH~PY · o. Alaska Oil & Gas Cons. Ccmmission Anchorage ARCO ALASKA, INC. ATTN: LORIE L. JOHNSON - AFA/311 P. Oe BOX 360 : ANCHORAGE, AK. 99510 Z? Sz ARCO Alaska. Inc. ,- ,~ c. ar u ~. P' C..leC I , drawn by' ,.,C,~, k~3PARUK ENG~G William VanAlen D. W. Bose/Lorie L. Johnson Transmitted herewith are the follc~ing: PI.~ASE NOTE: BL - BI/IELINE, S - SEPIA, F - FTTbI, _ PC - PHCYI~PY tl. noh~r3n~~ Co~."rli",,.?,'?:7 .. _ .. IPT ACKNC~. ,~q'X::;ED: DATE: ATIlW: LORIE L. JOHNSC~ - ALFA/311 P. 0.. ~OX. 360 ANCHORAGE, AK. 99510 TO: William VanAlen FRC~: D. W. Bose/Lorie L. Johnson Transmitted herewith are the following: P~.WASE NOTE:. ~~, F- FIIM, T- TAPE, PC-PHOTOCOPY RECEIVED SEP 2 ~ 1.982 : Naska 0ti & Gas Cons, Commission A~chorage P. O..'BOX 360 ANCHORAGE, AK. 99510 ARCO Aiaska, Inc. '~-", Post Office B, $0 Anchorage, Alaska 99510 Telephone 907 277 5637 September 10, 1982 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- State Reports Dear Mr. Chatterton' Enclosed are monthly reports for August on these drill sites' 1-19 13-32 1E-30 2-23 13-34 1G-1 2-26 14-21 1G-2 6-19 18-3 1F-5 6-20 18-6 WSW-2 6-21 1E-17 Also enclosed is a well completion report for Kuparuk 1E-16. Surveys for 2-22 and 6-18 are being reran; completion reports for these wells will be submitted when approved surveys are received. Sincerely, P. A. VanDusen District Drill ing Engineer PAV/JG:ilm Enclosures GRU1/L93 S£P .I. a, .i.t-.~,::,~.. Oil & Gas cons. Co~r~rn!ssion ". '!(:~i;.'_ ?',r', ~-~ ARCO Alaska. Inc. is a subsidiary of AllanlicRichfieldCompany ~ ? , ~ .~. STATE OF ALASKA ..... , ALASKAL _AND GAS CONSERVATION CC VllSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling wellx[~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 82-130 3. Address 8. APl Number P. O. Box 360, Anchorage, AK 99510 50- 029-20805 9. Unit or Lease Name FSL, 314' FWL, Sec. 29, T12N, RIOE, UM (Approx) Kuparuk River Unit 4. Location of Well 895' at surface 5. Elevation in feet (indicate KB, DF, etc.) 91' RKB (est,) I6. Lease Designation and Serial No. ADL 25640 ALK 2571 10. Well No. 1G-1 11. Field and Pool Kuparuk River Field. Kuparuk River 0il Pool For the Month of August ,19.82 2. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 2000 hfs, 08/13/82. Drld 13-1/2" hole to 2255'; ran DIL/GR; ran, cmtd tstd 10-3/4" csg. Drld 8-3/4" hole to 7470'-ran logs & shot sidewall cores. Cont. drlg 8-3/4" hole to 7970' TD. Stuck pipe & worked free. Ran, cmtd & tstd 7" csg. Ran gyro & logs.. Perf'd well. Secured well & released rig ~ 1800 hrs, 08/29/82. SEE DRILLING HISTORY 13. Casing or liner run and quantities of cement, results of pressure tests 10-3/4" 45 5#/ft, K-55, BTC csg w/shoe @ 2239' Cmtd w/1800 sx AS III & 250 sx AS I 7" 26 O#/ft, K-55 ERW, BTC csg w/shoe ~ 7957' Cmtd w/595 sx Class G SEE DRILLING HISTORY 14. Coring resume and brief description None 15. Logs run and depth where run GR/DIL f/2255'-80' Cal DIL/GR/SP DIL/GR FDC/CNL CBL/VDL/GR GR/BHCS CBL to 2000' RFT CCL/GR ~16. DST data, perforating data, shows of H2S, miscellaneous data N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 'SIGNED- -- ~.~~.~r~¢~ ,~~__ _ .....-- ~',~,...~'.,~_._.. ~ TITLE Kr . Drl 11 ~ nn Fnn~ n~r DATE NOTE--Rep/to/f/this f~rm is required for each calendar month, regardless of the status of operations, and must be'file'~ in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10404 GRU1/MR35 Submit in duplicate 1G-1 DRILLING HISTORY NU Hydril & diverter. Spudded well @ 2000 hrs, 08/13/82. Drld 13-1/2" hole to 2255'. Ran GR/DIL f/2255'-80'. Ran 53 jts 10-3/4", 45.5#/ft, K-55, BTC csg w/shoe @ 2239'. Cmtd 10-3/4" csg w/1800 sx AS III & 250 sx AS I. ND Hydril & diverter. NU BOPE & tstd to 3000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new hole. Tstd form to 12.5 ppg EMW. Drld 8-3/4" hole to 7470'. Ran DIL/GR/SP, FDC/CNL, GR/BHCS; could not get past 4360'. Reamed f/4350'-4410'. Ran DIL/GR/SP/FDC/CNL/BHCS. Ran RFT - unable to get sample due to tool failure. Ran Cal& DIL/GR. Shot sidewall cores. Reamed f/4330'-4460', 4590'-5200', 5400'-6000', & 6766'-7470'. Cont drlg 8-3/4" hole to 7970' TD (08/24/82). CBU. Circ hole - mix and pump 30 bbls Hi-Vis sweep pill. Mix & spot 40 bbl Soltex pill at TD. Ream f/6543'-6968'. CBU @ 6948', RIH; hit tight spot @ 6998' & stuck pipe. Worked pipe free. Reamed f/6905'-7700'. Ran 175 jts 7", 26#ft, K-55, ERW, BTC csg w/shoe @ 7957'. Cmtd 7" csg w/595 sx Class G. Instld 7" packoff & tstd to 3000 psi - ok. Ran gyro f/7800' to surf. Ran CBL/VDL/GR. Arctic packed 7" x 10-3/4" annulus w/300 bbls H20, 250 sx AS I & 97 bbls Arctic Pack. Ran CBL to 2000'. Ran 3-1/2" completion assembly w/tail @ C~9~ & pkr @ 6,~.57 . Ran CCL/GR. Tstd tbg hanger & packoff to 3000 psi - ok. ND BOPE. NU tree & tstd to 3000 psi. Disp well w/diesel. Dropped bar & fired guns. Flowed well. Dropped ball to release guns (estimated top of Vann Gun fish 7420') Closed SSSV @ i9'~9~ . Set BPV. Secured well & released rig @ 1800 hrs, 08/29/82. JG:sm 09/07/82 GRU/DH48 MEMORANDUM State of Alaska ~LAo~A OIL AI~D -;-CAS CONSERVATION CGi'.~MISSIO~Q 0:0. V/¥ r on FROM: DATE: AUgUSt 23, 1982 FILE NO: 108A/D' Comm~ ssioner TELEPHONE NO: "~: ~:., ~:- .... : ': :.. L. ~ ~.~..' , :' :-: ~-~:::' :' Petroleum inspector ~'~.?~,~": ?-~::'::': ..... ARCC' ' s ~,/el 1 No. lC-1 Kuparuk F~iver Unit Sec. 29, T12~, Ri0~, U~ Pe~it No. 82-130 Sund~_y, Au~ust.__15, 19.82 - I left Pum~; Station I,;o. 1, alter completing an inspection, s~ject of another report to go to ARCO's .Kupar~ River Unit 1G-I to witness another E©PL test, time 3:00 p.m. I witnesse~ the ~PE test on 1G-1 from 10:00 p. ni. to 11:30 p.m. There ~-~re no failures. I filled out an A.O.G.C.C. report which is attached. In sum~.a~~, I witnessed the DOPE test on AI~C©'s Ku~aruk River Unit ~--.'..o. iG-1. The test %-~as ~rformed satisfactorily. O&G #4 4/$0~ STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O,P.E. Inspection Report Inspector Operator ~F~7~ Location: Sec .~ Drilling Conhractmr Location, General' Well Sign,, General Housekeeping Reserve pit Rig,, BOPE Stack Annular Preventer Test PresSUre Well RepreSentative _ ¢~ Permit # ~'2 - /~Casing Set @ ~ ft. Rig # /fi/ Representativ~ _F F ACCUMULATOR SYSTEM Full Charge Pressure .~/~-~ psig Pressure After .ClOsure '/d ~' psig 2'00 psig Above Precharge Attained: / rain -- sec FUll Charge Pressure Attained: - ~ minaS"sec Control's: Master '/ ' ~ Rem6te" ~/~$1inds switch cover Kelly and Floor Safety, Valves Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve ?do Upper Kellx Lower Kelly Ball Typ~ !n&i,d9 BOP ~h0~e Manifold No'. Valves Tenth.Pressure _~V~ Test P~essure _~~ Test Pressure ~/~ ~ Test PresSUre /.//~ ~/f' Test Pressure~~ No. flanges ? '~ Adjustable Chokes ~;~Y~ ~ Hydrauically operated choke Test Results: Failures /./~r TestTime ~. hrs. Repair or Replacement Of failed equipment to be made within'' ' days and Inspector/Commission office notified. Remarks: ~/~/~.%/ /F ~/~ ./~ '?-~/- / ! / Distribution orig. - AO&GCC cc --Operator cc - Supervisor August 12, 1982 ~r. Jeffrey B. ~:ewtn Senior Drilling Engineer ARCO A!a~ka, Inc. ?. O. ~x 360 Anchorage, Alaska 995t0 Ke ? Kuparuk ~;iver Unit AB(X} Alaska, Inc. Persni t Mo. Sur. Loc. 895'FSL, 314'F%~L, Sec. 29, T12N, P. 10E, U~+~. ~t~ole Loc. 1940'FNL, 470'FEL, Sec. 31, TI2N, I{10E, ~r Kewin: Dear .~ . Enclosed is the approved revised application for permit to drill the above referenced wetl. The provisions of the cover letter, dated August 11, 1982, accompanyi~ the original approwed'pern~it are in effect for this revision. Very truly yours, : Lo~mie C. ~uith Co~issioner of Alaska Oil and (~as Conservation Co~tssion Enclosure cc Department of Fish & ~ ~ Habitat Eection w/o enel Department of Environmental Conservation w/o eccl. August 10, i982 ~. Jeffrey B. ~4ewin Senior Drilling Engineer ARC~ Al-aska, Inc. P. O. Box 360 Anchorage, Alaska 9~510 Kuparuk ~iver Unit 1~-t AROD Alask. a, Inc. Perr,uit-No. 82-130 ~tir. Lee. 895'FSL, 814'F~L, Sec. ~9, T12~.~, ~10E, U~. ~t~hole Loc. 239§'~*L, ~77'FF.L, Sec. 31, TI2N, F~10E, [Jf~. :Dear Mr. Ke~in: Enclosed ia the approved application for permit to drill the above referenced v~ell. Well aatr..ples and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.05{J(b)(5). If available, a ta~.~e containing the digitized log infor~nation shall be subr;~itted on all logs for copy'in[~-except, e~:t~erit.~ental logs, velocity surveys and dtt*.~meter surveys. ~.~any rivers in Alaska and their drainage systems have been classified as important for the spav~ning or ..migration of anadromot~s fish. Operation~ in these area~ are subject to AS 16.05.87~ and the regulations prou~.Ulgated thereunder (Title 5, Alaska AcLm_inistrative Code). Prior to cor~,;encing' operations you ~:~ay be cor~tacte~ by the i{abitat Coordinator's C~ff-ice, ~, ~ ~ . . De;-~a.t,-ent of Fish and Game Pollution of any waters of the State is prohibited by AS 46, Ci~apter 3, Article 7 and the re~-~lationa promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by thc Federal ~ater Pollution ~ntrol Act, aa an~ended. Prior to cc~encing operations you ~my be contacted by a representative of the Department of '~ ' ~nv~ronn:~ntal Conservat ion. To aid us in scheduling7 field ~vork, we would ap~.~reciate your notifying this office within 48 hours after the ~veil is spudded. ~ie would! also like to be notified so that a representative of the Cor~ni~ion .~4ay be present to ~ttnes~ Jeffrey Euparuk River Unit -2- August 10, 1982 testing of blOwout preventer equipment before surface casing s.hoe is drilled. · In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a wi tness present. VerY truly YOurs, C. V. Chatterton Chairman of BY ORDER OF ~HE CO,M~'~;IS$iON Alaska Oil and Gas Conservation Commission Eno 1 o ~ure cc: Department of Fish & Gsme, Habitat Section w/o enel. Department of Environmental Conservation w/o enel. CVC' be ARCO Alaska, Inc. Post Office B,. 360 Anchorage, Alaska 99510 Telephone 907 277 5637 August 10, 1982 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Drill Site 1G-1 Application for Permit to Drill (Revised) Dear Mr. Chatterton' Due to a change in the bottomhole location, we are resubmitting our application for Permit to Drill well 1G-1. Attachments include a drawing of the proposed wellbore, and a drawing and description of both the surface hole diverter system and the BOP equipment. Since we estimate spudding the well on August 13, 1982, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, Senior Drilling Engineer JBK/JG'sm Enclosures GRU1/L65 ARCO Alaska. Inc. is a subsidiary of AtlanticRichfieldCornpany RECEIVED AUG 1 o 1982 AI.asY, a 0il & Gas Oons. Co~nmission Anchorage STATE OF ALASKA ALASKA L,,L AND GAS CONSERVATION CO,.,IMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well 2. Name of operator ARCO Alaska, Inc. EXPLORATORY [] DEVELOPMENT OIL DEVELOPMENT GAS [] E£EIVEi) SERVICE [] STRATIGRAPHIC SINGLE ZONE [] MULTIPLE ZONE 3. Address P. 0. Box 360, Anchorage, Alaska 99510 AUG 1 0 i982 4. Location of well at surface 895' FSL, 314' FWL, Sec. 29, T12N, RIOE, UM (Ap~,~ At top of proposed producing interval Target: 6220' $S, 1500' FNL, 350' FEL, Sec. 31, T12N, At total depth 1940' FNL, 470' FEL, Sec. 31, T12N, RIOE, UM 0il & Gas Cons. Commissi, Anchorage R10E, UM 9. Unit or lease name 'fl Kuparuk River Unit 10. Well number 1G-1 11. Field and pool Kuparuk River Field 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. 60.5' PAD, 91' RKB(est,) I ADL 25640 ALK 2571 Federal insurance Company 12. Bond information (see 20 AAC 25.025) Type Statewi de Surety and/or number #8088-26-27 13. Distance and direction from nearest town 32 Miles NW Deadhorse 16. Proposed depth (MD & TVD) 7763' MD, 6870'TVD 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 2700 feet. , 21 ' SIZE I Hole Casing ~4~" 16" ~3-1/2" 10-3/4" 14. Distance to nearest property or lease line miles BH 2885' FSL of lease feet 17. Number of acres in lease feet 2560 20. Anticipated pressures MAXIMUM HOLE ANGLE 40 o (see 20AAC25.035(c) (2) Kuparuk River Oil Pool Amount $500,000 15. Distance to nearest drilling or completed well 5280' + 18. Approximate spud date 08/14/82 2755 psig@_ 80'~F . 3140 psig@ 6155 feet Surface ft. TD (TVD) Proposed Casing, Liner and Cementing Program CASING AND LINER SEI'I'ING DEPTH QUANTITY OF CEMENT Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 65# H-40 I PEB 80' ! 30' I 30' 11°' I 11°'1 +200 cf 45.5# K-55 IBTC 2170' 30' I 30' 2200' '.2200' 900sx AS III I I I I I 250SX AS II 8-1/2" 7" 26# K-55 /BTC 7874' 28' I 28' 7874' 16846' lO00sx "G" cmt. I / I I I 22. Describe proposed program: ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approx. 7874' MD, (6846'TVD). A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 10-3/4" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Maximum expected surface pressure is 2755 psig. Pressure calculations are based on virgin reservoir pressure. Surface pressure calculated with unexpanded gas bubble at surface including temperature effects. Selected intervals will be logged. The well will be completed with 3-1/2", 9.2#, J-55 buttress tbg. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be installed and tested upon completion of the job. This is the first well to be drilled on G-Pad. 23. I hereby certify that the foregoing is true and correct to the best of my knowledge SIGNED ~.~./_~__~ ~-~_~.~ TITLE Senior Drilling Engineer The space bel/f~)r~m/ion use CONDITIONS OF APPROVAL Samples required Mud log required []','ES ~NO []Yes ~NO Permit number Approval date Form 10401 GRU1/PD17 Directional Survey required [ APl number SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE Aug~ust 12, 1982 by order of the Commission Submit in triplicate General Purpose Worksheet 0 JSubJect IPage No. Of lay x~ ~ IDate ..................................... -.. ~ ............... . :; ..... ,o~_. ~ ....... ..........~ .... / / loc _~0 =3~_ ~= = ..... ~ 350- - ................................. - ........ ....... <a Oil & Gas {:0nS, C0~,rr~issi0r~ . .... 2000 ~,,- - · 4-000 5000 6000_ 0 Surface Diver"er Ssstem 1. 16" Bradenhead. 2. 16" x'20" 2000 psi double studded adapter. 3. 20" 2000 psi drilling spool w/lO" side outlets. 4. 10" ball valves, hyraulically actuated, w/lO" lines to reserve pit. Valves to open automati- cally upon closure of annular preventer. 5. 20" 2000 psi annular preventer. 6. -20" ~bell .nipple. 16" Conductor diverter line. Do not. shut in well under any circumstances. Maintenance & Operation ~-- 1. Upon initial installation close annular ! preventer and verify that ball valves ! - have opened properly. I 2. Close annular preventer and blow air ~__ . through diverter lines every 12 hours. t 3~ Close annular preventer in the event that gas or fluid flow to surface is · detected. If necessary, manual ly over- ride and close ball valve to upwind · J 4- !~-5/8" 5000 PSt ,~SRRA BOP STACK--- 2. 3. 4. ) l 6" Bradenhead 16" 2000 PSI x 10" 3~S3 ?SZ c~sing head · 10" 3000 PSI t,.-,bing head 10" 3000 PSI x 13-5/8" 5000 PSI .. adapter spool -:' 13-5/8" 5000 PSI pipe ra~s 13-5/8" 5000 PSI drilling spo~l w/choke and- kill lines -- 13-5/8" 5000 PSI pi~e'ra~s- -' _--_..'" :..... 13-5/8" 5000 PST_ blind r-~qs -- ' .... .- -: -- 13-5/8" 5000 PSI anr=zlar --. .:..-,-:.. ~.-"_.- · . . '~ ....- .'.',; . . -.. _ _ - · . ... _ _ o ACCL~-IULATOR CA2~SI Tlr TF__ST · --'1... -- - ' ~4E~ ~'~ FILL AC~%~O~ ~'~ WITH HYD2~ULIC ~ID~ ~S~Z ~AT A~-~T~ P~E ~I~ 1500 PSI ~~ ~ 7r~ ~~R_ ~S~YE TIME T~ C~E ~ C~ITS S~T~- ~LY ~qD REC02~ ~ T~ ~ 2~~ ~I~ - I~ ~ A~ DiITS ~ OFF. . L~IT IS 45 SE~';~ ~I~ ?~E ~ l~ ~SI ~NIl~ PP~SU~. - 13-5/8" BOP STA~( TEST --b - PiPE RRHS 3. s () -... F-ILL BOP STAC~ AI{D MA~XIF-OLD '~ITH ~C DI~EL. ~E~ ~PAT ~'IR S~T AID S~T IK ~~D. ~ I~ L~ ~N SCOWS IN H~. ~E ~'CqUL~R PR~~ ~D ~ ~ ~P~S ~JT ALL lO HIIDTES. I)(C~E PRESS~ T0 l0 NH;UTES. B~ED T0 ~0 ~SI. · -4 - - -"--.----" ' 8 O-,_.OSE W,,.LVES 0'~.,C~,__'r t. mS~ 0r - -'~ - ' . - - -. ' . ': ._ -l"--.. - -_ '' BLEED D~,,"NSTRE~( P?,.ESSU%~'~ ~ ZERO PSI T~ TF._S'T ¥,-.=YES. TES ~ P,.~.-L~,(.,,u UIt'F'_.S~-E-D , '.~-'¢J:FOLD G?~I TOP Sc"-[ OF PiPE RA-~ A.~D ~_..OS~ H!!~JTE.S. BLEED TO Z~ ?SI. RA~.'~S A~D TEST T0 3000 PSI FD~ lO - ' 2. ~{ BLI~ID PA'iS A~;D P. ECC~-,'F_P, TEST ''- DIESEL ?did ALL YALYES A~ S~'L-[ 'I)( t~II_LII~ i SLIT. F_ HgJlIFOLD ~u',D LI,~-~_S ~ F'd.'.J. ~c ARCTIC 'ri -1 ]]]]]>_- - ' ' :7 ':~]"' } - -13. TEST STA~IDPIPE YALYES TO 3Dm ?'SI. ' TEST FOPJ4 SIG:t A:ID S~ TO ~t.ILLIT"~ YISOR. . ' - ARCO Alaska, Inc. Post Office E, ~,60 Anchorage, Alaska 99510 Telephone 907 277 5637 August 6, 19.82 Mr. C. V. Chatterton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Kuparuk 1G-1 Dear Mr. Chatterton' Enclosed are' o An application for Permit to Drill Kuparuk 1G-l, along with a $100 application fee. o A diagram showing the proposed horizontal and vertical projections of the wellbore. o A diagram and description of the surface hole diverter system. o A diagram and description of the BOP equipment. · Since we expect to spud this weil-on August 14, 1982, your earliest approval would be iappreciated. · . If you have any questions, please. call me at 263-4970. Sincerely, Senior Drilling Engineer JBK/JG' llm Enclosures ECEIVED Oil & Gas Cons. Co nmissior /~nchorago ARCO Alaska. Inc. is a subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OiL AND GAS CONSERVATION CCtv, MiSSION PERMIT TO DRILL 20 AAC 25.O05 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL ;1~ DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE [] MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 360, Anchorage, Alaska 99510 4. Location of well at surface 895' FSL, 314' FWL, Sec. 29, T12N, R10E, UM (Approx) At top of proposed producing interval AUG -' 6 Target: 6220' SS; 1900' FNL, 700' FEL, Sec. 31, T12N, RIOE At total depth Naska 0il & Gas Cons. 2395' FNL, 877' FEL, Sec. 31, T12N, R10E, UM Anchorage 5. Elevation in feet (indicate KB, DF etc.) ] 6. Lease designation and serial no. 60.5' PAD, 91' RKB(est.) I ADL 25640 ALK 2571 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewi de Surety and/or number #8088-26-27 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 32 Miles NW Deadhorse miles BH 2885' FSL of lease feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 8102'MD, 6836'TVD feet 2560 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 2300 feet. MAXIMUM HOLEANGLB~2 Ol (see 20 AAC 25.035 (c) (2) 21 Proposed Casing, Liner and Cementing Program 9. Unit or lease name Kuparuk River Unit 10. Well number 1G-1 ,j§~LEield and pool ~(~aruk River Field Kuparuk River 0il Pool Amount $500,000 15. Distance to nearest drilling or completed well 5280' + feet 18. Approximate spud date 08/14/82 2755 psig@ 80°F Surface 3140 .psig@ 6155 ft. TD (TVD) SIZE ~ Hole I Casing ~Z4" 16" ~3-1/2" Weight 65# 10-3/4" 45.5# 8-1/2" 7" 26# 22. Describe proposed program: CASING AND LINER Grade Coupling Length H-40 PEB 80' K-55 BTC 2170 ' K-55 I BTC 8074 ' I SETTING DEPTH MD TOP TVD 30' I 30' 30' I 30' I 28' I 28' MD BOTTOM TVD 110' 110' 2200' 2200' I I 8102' 16836' I I QUANTITY OF CEMENT (include stage data) '±200 cf 900sx AS III 250sx AS II l O00sx "G" cmt. ARCO Alaska, inc., proposes to drill a Kuparuk River Field development well to approx. 8102' MD, (6836'TVD). A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 10-3/4" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Maximum expected surface pressure is 2755 psig. Pressure calculations are based on virgin reservoir pressure. Surface pressure calculated with unexpanded gas bubble at surface including temperature effects. Selected intervals will be logged. The well will be completed with 3-1/2", 9.2#, J-55 buttress tbg. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be installed and tested upon completion of the job. ~his is the first well to be drilled on G-Pad. 23. I hereby certify t_hat the foregoing is true and correct to the best of my knowledge SIGNED ~_~~ TITLE Senior Drilling Engineer CONDITIONS OF APPROVAL Samples required [~]YES Permit number APPROVED BY Mud Icg required []YES J~4XIO Approval date Directional Survey required I APl number ~[,YES []NO 50- ~ Z~" ~)(:~O~' SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE by order of the Commission August 10, 1982 Form 10-401 GRU1/PD17 Submit in triplicate 13,~-~!8" 5000 PSI °RSRRA BOP ST$~CK - I 'l ANNUL.qR -] PREVgE~TOR~ PIPE RRN$ 7 () _ .- C .) -) -l_t PiPE'RRMS F =5 ) 'C TBG HD 3 CSG HD 2 ( ) . and kill lines 7. 13-5/8" 5000 PSI pipe_ 8. 13-5/8" 5000 PSZ blind 9. 13-5/8" 5000 PSI an~.lar -- 1. 16" Bradenhead 2. 16" 2000 PSI x lO' 3%3 PSI czsing head 3. 10" 3000 PSI tubing he=_d 4. lO" 3000 PSI x 13-5/8= 5C00 adapter spool 5. 13-5/8" 5000 PSI pipe ra~s 6. 13-5/8" 5000 PSI drill in9 st~ool w/choke ._. . . , -- · - _ ACCLt-tULATOR C~£I~ T_ST ~-IECK M,'D FILL ACC~T-n.~%OR -~.~.SER~,"'OI~- lO PRgP~ '" L.c~'E[ WITr{ HYDP,~ULIC Fl_DID. 2. ASSt~,E TP&T ACO~-ib~_ATOR P~L~,,E I$ ~ P~I -- t~ITlt 1500 PSI DO',~'~T~.F_~ O~ T'r2 3. O~SEgJtE TIHE Th%N CLI~E ALL L~ITS ~_~SLT AI;D RECOP. D THE TI~.~ /~D ?~ .:~2Z~.AII~ ' . PIJ?~P OFF. . 4. ~ ON I~C R~P~. ~ A~~ ~IT IS 45 SE~';~ ~I~ T~E ~ 1~ PSI ~NI ~ P~SU~. - - . .~ 13-5/8" ~.O','F, ST2,~.( TF.~ 1. -LF!LL BOP STAC~ ~IO MA.N[FOLD l~l'~fl ¢~-"-'-'-'-'-'-'-'~6 DIESEl.. 7_. ~'~ECX l"~T AJ_L HO~ ~ S~ ~- FIJLLY RF_- -' TP~AC'FED. PFLEDETEF:.~II~E DEPT-' T~',AT ~ ~-'t.l.~ I~ILL SEAT AJ,'D SEAT IX I~?~U----~D. ~"J~"~ Il; LDOC D~J~N SCR~S IN HEAD. 2. CLOSE A~CNUL~2, P?,~ liTEP, AND ~-:~.S A~ YALVES 0:( ~tA~qIFOLD. -. ~. TEST ALL C~4PONEi~S TO 250 ?SZ A~'O ~g lO HII~TES. S. INC.-~REASE PRESSUT-~ TO l'~-~ PSI ~ND P~..D FOP. 10 MINUTES. BLEED TO Z~O ~[. 6. OP. ~'I 'AN~dLA2 PP,~I~,---TF?. ~;D i~_~E ~ SET PIPE ~.q. 7. ],~;C~,EASE PP.~SU2E TO %00 PSI' ~ND X~__D .:02 lO 8. C~05E YALYES DIRECTLT UPS~X OF O~C.SS. - BLEED ~NST' ~{ P?~.ESSb?~ ~ 7_SRO PS-I TO T'?_SQ' · ¥~I__¥ES. TEST P,~-L~N'.,h.~ UNI~_S~'--~-D_ X.~'I]FOLD V~:¥~, IF ~iY, '~I'TH 3'P_,,.-O PSi UP~-~'.~¢-1~_ ~. ¥~±~E ~Jig ZF.~O PSI D~A~,. B~ S~ . T ~ ' 0 ZD.O PSI. ~ . 9. OPgl TOP SET OF PiPE P~,-~ A.~D ~-- --~-~_ -~0 ,l-T~ SET OF, ?IPE RA,¥6. ,,'~ d"" 10. IN~.S~ PRE~SU~'~ TO ~--~ PSt ~.',D :OLD ~--'Jo ~[:m~. SLSED TO Z~O ~SZ. II. 02cji BOI'TON SET OF PIPE ?.A.~'~. BA~--( ~-"F ~J.~ '~; ;? ~ '? NI:;G JOIZ~T AND PULL ~JT OF ~r_~. CLUE 5LIND "~ ~¢~ - · ~ ~-..' . ~.'~S .~iD TEST TO 3000 PSI F~ ~0 ~.IJ~3TES. BLEED TO ZERO PSI. - ' 12. 13. 14. 15. . / -® Surface Dive~'~r S~/stem 1. 16" Bradenhead. 2. 16" x '20" 2000 psi double studded adapter. 3. 20" 2000 psi drilling spool w/10" side outlets. 4. 10" ball valves, hyraulically actuated, w/lO" lines to reserve pit. Valves to open automati- cally upon closure of annular preventer. 5. 20" 2000 psi annular preventer. 6. 20" bell ,nipple. 3~ Close annular preventer in the event 16" Conductor that gas or fluid flow to surface is 'detected. If necessary, manually over- ride and close ball valve to upwind diverter line. Do not. shut in well under an~/ circumstances. Maintenance & Operation ~ 1. Upon initial installation close annular I preventer and verify that ball valves ! _ have opened properly. ] 2. Close annular preventer and blow air ~__ . through diverter lines every 12 hours. CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE Company Lease & Well No. YES NO K R.c{ REMARKS (1) Fee (2 thru 8) (3) Admin ~~ (9 thru (4) Casg ~. ,%'~---7/-'g' (~f ~hru 20) 1 1 1 1 (5) BO PE ~~2~ ~21 thru 24) (6) Add~~.-_~ (~-?'/~'~"¥' 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 well bore plat included ........... 7. Is operator the only affected party ................................. 8. Can permit be approved before' ten-day wait .......................... /~ 9. Does oPerator .have a bond in force .................................. /J~ . 10. Is a conservation order needed ...................................... 11. Is administrative approval needed ........................... ~ ....... · 3. 4. 5. 6. 17. 18. 19. 20. 21. 22. 23. 24. 25. 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 surface casing protect fresh water zones .................... Will all casing give adequate safety in collapse, tension and burs Is this well to be kicked off from an existing wellbore .......... Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed .......................... Is a diverter system required ............ , .... .~ Are necessary diagrams of diverter ~'~6{ eq~i~g~ ;[[~g~e~ . . Does BOPE have sufficient pressure rating -Test to.'j~~ psig ..~__ Does the choke manifold comply w/API RP-53 (Feb.78) .................. Additional requirements ............................................. Additional Remarks: ;eology: IWK gngin~eDing: [,CS Y c"~' BEW/"~'i' MT~ ~ '"'" :ev: 01/13/82 INITIAL GEO. UNIT oN/OFF POOL CLASS STATUS AREA NO. SHORE .- CHECK LIST EOR NEW WELL PERMITS ITEM APPROVE DATE Company ~- '~/F'~ ~) Lease & Well No. YES NO K Lt. REMARKS --/ (2 thru 8) 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 well bore plat included ............... 7. Is operator the only affected party ................................. 8. Can permit be approved before ten-day wait .......................... (3) Admin ~K ~-g-~ 9. ~(~ thru 11) 10. 11. (4) Casg~~//~ ~.~-~g_. (12 thru 20) 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. \ (5) (21 thru 24) Does operator have a bond in force .................................. /~ Is a conservation order needed ...................................... Is administrative approval needed .................................... Is conductor string provided ........................................ Is enough cement used to circulate on conductor an~d surface ......... Will cement tie in surface and intermediate or production strings .... Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ........................... Is a diverter system required ....................................... ~ Are necessary diagrams of ,diverter and BOP equipment attached ''i' .... ~-- Does BOPE have sufficient pressure rating -Test to J~o ps g . Does the choke manifold comply w/API RP-53 (Feb.78) .................. 25. Additional requirements ............................................. Additional Remarks: Geology: Engin~oe~r ing: '~U-~ ~ LCS BEW .fAL / MT~ rev: 01/13/82 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well Histo.ry File A,PPENDIX Information of detailed nature that is not padiculady 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. LIBRARY TAPE CURVE SPECIFICATIONS Company ARCO ALASKA, INC. Well D.S. G-1 Field KUPARUK County, State N. SLOPE, ALASKA Date 8-22-82 Curve Name (Abbrev.) Standard Curve Name Logs Used Scale SP Spontaneous Potential BHC/AL 0-100, 100-200 GR1 Gamma Ray 1 , Cp/~N " " CAL Caliper 1 " 6 - 16 ,, AC Acoustic BHC/AL 150 - 50 RS1 Resistivity Short .2 - 2000 RD1 ', Deep ~ ,, CN Compensated Neutron CD/CN 60 - 0 , DEN Density CD/GR 2 - 3 DENP Density Porosity CD/CN 60 - 0 . CORR Correction CD/GR -.5 - .5 C13 Caliper Arm 1 + 3 Caliper Log 6 - 16 C24 " " 2 + 4 " 16 - 6 GR Gamma Ray CD/CN 0-100, 100-200 . , CAL Caliper " 6 - 16 ,, RECEiVEO , , SEP 2 8 82 -, Gas Cons. C~mmisston ECE "iU:-'i~-¢ER 1~+24. i;O ARCO PLA~SKA INC, ..:::.:....:.:.. ..... ...... ::~: :~: ..................... ~~~. G R CAL.___.p.E N P REC-EdYED SEP 2_8~982 Ac ::~1 RD CORR · 0,0 O,O O.O 0.0 0.0 0.0 0.0 0-0: - 0,0 0,0 O,D 0.0 0,0 0,0 0,0 0,0 O,O 0,0 U,O 13.0 11. [:.}25000.0 -1.0::i 10.825000.0 -:1.0 10./25000.0 -1.,.0: 11.9 162.4 -1.0 lq.125000.0 2.q 2.7.5 -1.0 2. ~ 27.5 .-! FL, t+ P7.5 -1 . 0 ~.8~.i, .~9,'-'~. '7:5,0 1U,2 ;i ,7 5A,7.. 3/;,7 qt-O_ .'J 2, q :~":': "":":" '""'" "-]- ~'"e":'"';::.`':''':~:':,>:~I z~ ~ ~ ~ ............................ ~>v~.~:-:: .... -/~::~:~X::~?::,~ >.-; ::~ :'~ -::,:-::...-:v..s........... :~ ~.:-~..-:..:.:...:: ...... :~,~--~: :;'f: i:::; :::::::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::: :'~'{: ::':'::~' .... ~ .......... 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