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Home My WebLink About182-010ORIGINATED TRANSMITTAL DATE: 1/7/2025 ALASKA E-LINE SERVICES TRANSMITTAL #: 5218 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 5218 1A-14 50029207060000 Plug Setting Record 25-Dec-2024 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 Richard.E.Elgarico@conocophillips.com 700 G Street Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 ShareFile 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 182-010 T39935 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.01.08 08:10:40 -09'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com AKGGREDTSupport@ConocoPhillips.onmicrosoft.com 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 1A-14 (PTD 182-010) Report of suspect IA pressure update 10/23/24 Date:Wednesday, October 23, 2024 11:20:54 AM Attachments:1A-14 90 Day TIO Plot & Schematic.pdf From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Wednesday, October 23, 2024 11:18 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU 1A-14 (PTD 182-010) Report of suspect IA pressure update 10/23/24 Chris, KRU 1A-14 (PTD 182-010) (AIO 2C.082) second 90 day monitor period comes to an end today 10/23/24. During the monitor period the IA pressure showed no signs of IA pressure fall off or annular communication. 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: Thursday, July 25, 2024 1:00 PM To: Wallace, Chris D (DOA) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU 1A-14 (PTD 182-010) Report of suspect IA pressure update 7/25/24 Chris, KRU 1A-14 (PTD 182-010) (AIO 2C.082) was reported 4/25/24 to be exhibiting a slow IA pressure fall off when reviewing a TIO trend. DHD performed IC pack off tests that passed, a MITIA that passed (see attached 10-426) on 4/29/24, and manipulated IA pressure for the monitor period. With the 90 day monitor period coming to an end on 7/29/24. CPAI plans to extend the monitor period for another 90 days to manipulate the IA pressure and continue monitoring the IA for pressure fall off. Due to the slow nature of the IA pressure fall off and the well being shut in for 9 days in June due to the CPF1 shut down for maintenance, more time is needed to help determine if the IA pressure fall off is a thermal or injection rate related response or annular communication. Any required paperwork for continued injection or corrective action will be submitted upon completion of the extended monitor period. 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 7,701.0 1A-14 9/24/2017 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled plug & gauges 1A-14 10/24/2023 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: Waivered for Water Injection Only with known TxIA communication on gas injection 1/5/2021 jbyrne NOTE: View Schematic w/ Alaska Schematic9.0 8/2/2010 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 33.0 80.0 80.0 65.00 H-40 WELDED SURFACE 10 3/4 9.95 31.2 2,390.8 2,390.5 45.50 K-55 BTC PRODUCTION 7 6.28 29.7 8,263.3 6,915.2 26.00 K-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 27.1 Set Depth … 7,487.5 Set Depth … 6,292.3 String Max No… 3 1/2 Tubing Description TUBING WO 3.5"x2.875" Wt (lb/ft) 9.20 Grade J-55 Top Connection BTC AB-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) 27.1 27.1 0.00 HANGER 8.000 MCEVOY HANGER 3.500 1,806.2 1,805.9 0.90 SAFETY VLV 5.937 CAMCO TRDP-1A SAFETY VALVE (LOCKED OUT 2/23/2004) 2.812 4,663.6 4,225.3 45.35 XO Reducing 4.250 CROSSOVER 3.5 x 2.875 2.875 4,664.9 4,226.2 45.35 PACKER 5.937 BAKER 7" AL-5 DUAL PACKER; 1.9" OD (1.61" ID) short string 2.438 4,744.3 4,282.1 45.01 PACKER 5.937 BAKER 7" AL-5 DUAL PACKER 2.438 7,063.4 5,977.0 43.77 GAS LIFT 5.500 CAMCO MMG-P 2.375 7,110.6 6,011.3 43.04 SEAL ASSY 3.625 BAKER 80-30 LOCATOR SEAL ASSEMBLY 2.406 7,112.6 6,012.8 43.02 PACKER 5.687 BAKER DB PERM PACKER 3.250 7,116.3 6,015.4 42.99 SBE 4.250 BAKER SEAL BORE EXTENSION 3.250 7,158.7 6,046.6 42.62 INJECTION 5.453 OTIS LB 2.344 7,231.4 6,100.3 42.20 INJECTION 5.453 OTIS LB 2.344 7,271.8 6,130.3 42.11 BLAST JTS 3.668 2.347 7,443.3 6,258.7 40.73 INJECTION 5.453 OTIS LB 2.344 7,462.4 6,273.2 40.52 SEAL ASSY 4.000 OTIS LOCATOR SEAL ASSEMBLY 2.441 7,463.4 6,273.9 40.51 PACKER 6.156 OTIS WD PACKER 3.250 7,479.2 6,285.9 40.33 NIPPLE 3.668 CAMCO D NIPPLE NO GO 2.250 7,486.6 6,291.6 40.25 SOS 3.750 OTIS SHEAR OUT SUB 2.441 Top (ftKB) 4,660.0 Set Depth … 4,756.7 Set Depth … 4,290.9 String Max No… 1.9 Tubing Description TUBING BYPASS WO Wt (lb/ft) Grade Top Connection ID (in) 1.61 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) 4,660.0 4,222.8 45.34 PLUG 2.200 PERF BULL PLUG 1.610 4,663.8 4,225.4 45.35 CONNECTOR 2.500 LEFT SAFETY CONNECT 1.625 4,664.0 4,225.6 45.35 PACKER 1.900 BAKER AL5 DUAL PACKER 1.610 4,679.2 4,236.2 45.37 SWIVEL 2.250 TELSCOPING SWIVEL 1.562 4,733.9 4,274.7 45.11 SAFETY SOS 2.500 SHEAR OUT SAFETY JT. 1.670 4,742.3 4,280.6 45.03 CONNECTOR 2.500 LEFT SAFETY CONNECT 1.625 4,742.5 4,280.8 45.03 PACKER 1.900 BAKER AL5 DUAL PACKER 1.610 4,752.7 4,288.0 44.94 BULL PLUG 2.200 PERF BULL PLUG 1.610 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) 7,160.0 6,047.6 42.61 FISH CV 6/1/2005 - PULLED 1.5"" CV @ 7159' RKB, NOSE CONE WAS ERODED OFF. CV nose cone, eroded off; attempt spear cone out unsuccessful. 2/26/06, ran impression block to GLM #2, confirmed broken CV still in mandrel; could not pull fish in broken CV after 3 attempts. 6/1/2005 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 7,063.4 5,977.0 43.77 1 GAS LIFT DMY RK 1 1/2 0.0 7/17/2004 0.000 7,158.7 6,046.6 42.62 2 INJ PATCH RM 1 1/2 0.0 6/1/2005 Broke 0.000 7,231.4 6,100.3 42.20 3 INJ DMY T-2 1 1/2 0.0 2/7/1988 0.000 7,443.3 6,258.7 40.73 4 INJ HFCV RM 1 1/2 0.0 9/1/2011 0.000 1A-14, 10/25/2023 9:50:40 AM Vertical schematic (actual) PRODUCTION; 29.7-8,263.3 IPERF; 7,594.0-7,626.0 IPERF; 7,572.0-7,584.0 PACKER; 7,463.4 INJECTION; 7,443.3 IPERF; 7,379.0-7,402.0 IPERF; 7,353.0-7,359.0 IPERF; 7,339.0-7,347.0 IPERF; 7,280.0-7,334.0 INJECTION; 7,231.4 INJECTION; 7,158.7 FISH; 7,160.0 PACKER; 7,112.6 GAS LIFT; 7,063.4 PACKER; 4,744.3 PACKER; 4,742.5 PACKER; 4,664.9 PACKER; 4,664.0 SURFACE; 31.2-2,390.8 SAFETY VLV; 1,806.2 CONDUCTOR; 33.0-80.0 KUP INJ KB-Grd (ft) 39.01 RR Date 2/11/1982 Other Elev… 1A-14 ... TD Act Btm (ftKB) 8,285.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292070600 Wellbore Status INJ Max Angle & MD Incl (°) 49.93 MD (ftKB) 6,600.00 WELLNAME WELLBORE1A-14 Annotation Last WO: End Date 2/7/1988 H2S (ppm) DateComment SSSV: LOCKED OUT Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,280.0 7,334.0 6,136.4 6,176.5 C-4, C-3, 1A-14 2/11/1982 4.0 IPERF 120° Phasing; 4" Vann Guns 7,339.0 7,347.0 6,180.2 6,186.2 C-2, 1A-14 2/11/1982 4.0 IPERF 120° Phasing; 4" Vann Guns 7,353.0 7,359.0 6,190.7 6,195.2 C-2, 1A-14 2/11/1982 4.0 IPERF 120° Phasing; 4" Vann Guns 7,379.0 7,402.0 6,210.2 6,227.5 C-1, UNIT B, 1A- 14 2/11/1982 4.0 IPERF 120° Phasing; 4" Vann Guns 7,572.0 7,584.0 6,357.2 6,366.5 A-5, 1A-14 2/11/1982 4.0 IPERF 120° Phasing; 4" Vann Guns 7,594.0 7,626.0 6,374.3 6,399.2 A-4, 1A-14 2/11/1982 4.0 IPERF 120° Phasing; 4" Vann Guns 1A-14, 10/25/2023 9:50:41 AM Vertical schematic (actual) PRODUCTION; 29.7-8,263.3 IPERF; 7,594.0-7,626.0 IPERF; 7,572.0-7,584.0 PACKER; 7,463.4 INJECTION; 7,443.3 IPERF; 7,379.0-7,402.0 IPERF; 7,353.0-7,359.0 IPERF; 7,339.0-7,347.0 IPERF; 7,280.0-7,334.0 INJECTION; 7,231.4 INJECTION; 7,158.7 FISH; 7,160.0 PACKER; 7,112.6 GAS LIFT; 7,063.4 PACKER; 4,744.3 PACKER; 4,742.5 PACKER; 4,664.9 PACKER; 4,664.0 SURFACE; 31.2-2,390.8 SAFETY VLV; 1,806.2 CONDUCTOR; 33.0-80.0 KUP INJ 1A-14 ... WELLNAME WELLBORE1A-14 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 1A-14 (PTD 182-010) Report of suspect IA pressure Date:Thursday, April 25, 2024 4:21:26 PM Attachments:AnnComm Surveillance TIO for 1A-14.pdf From: Byrne, Jan <Jan.Byrne@conocophillips.com> Sent: Thursday, April 25, 2024 12:21 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU 1A-14 (PTD 182-010) Report of suspect IA pressure Chris, KRU 1A-14 (PTD 182-010) (AIO 2C.082) was noted to be exhibiting a slow IA pressure fall off when reviewing a TIO trend. CPAI plans to have DHD perform initial diagnostics including an MITIA, pack off testing, and manipulate annuli pressures for a monitor period. Due to the slow nature of the IA pressure fall off CPAI plans to monitor the well for 90 days. Any required paperwork for continued injection or corrective action will be submitted upon completion of the diagnostics and monitor period. 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 1A-14 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 1A-14 2024-03-16 523 1039 516 IA Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 7,701.0 1A-14 9/24/2017 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled plug & gauges 1A-14 10/24/2023 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: Waivered for Water Injection Only with known TxIA communication on gas injection 1/5/2021 jbyrne NOTE: View Schematic w/ Alaska Schematic9.0 8/2/2010 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 33.0 80.0 80.0 65.00 H-40 WELDED SURFACE 10 3/4 9.95 31.2 2,390.8 2,390.5 45.50 K-55 BTC PRODUCTION 7 6.28 29.7 8,263.3 6,915.2 26.00 K-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 27.1 Set Depth … 7,487.5 Set Depth … 6,292.3 String Max No… 3 1/2 Tubing Description TUBING WO 3.5"x2.875" Wt (lb/ft) 9.20 Grade J-55 Top Connection BTC AB-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) 27.1 27.1 0.00 HANGER 8.000 MCEVOY HANGER 3.500 1,806.2 1,805.9 0.90 SAFETY VLV 5.937 CAMCO TRDP-1A SAFETY VALVE (LOCKED OUT 2/23/2004) 2.812 4,663.6 4,225.3 45.35 XO Reducing 4.250 CROSSOVER 3.5 x 2.875 2.875 4,664.9 4,226.2 45.35 PACKER 5.937 BAKER 7" AL-5 DUAL PACKER; 1.9" OD (1.61" ID) short string 2.438 4,744.3 4,282.1 45.01 PACKER 5.937 BAKER 7" AL-5 DUAL PACKER 2.438 7,063.4 5,977.0 43.77 GAS LIFT 5.500 CAMCO MMG-P 2.375 7,110.6 6,011.3 43.04 SEAL ASSY 3.625 BAKER 80-30 LOCATOR SEAL ASSEMBLY 2.406 7,112.6 6,012.8 43.02 PACKER 5.687 BAKER DB PERM PACKER 3.250 7,116.3 6,015.4 42.99 SBE 4.250 BAKER SEAL BORE EXTENSION 3.250 7,158.7 6,046.6 42.62 INJECTION 5.453 OTIS LB 2.344 7,231.4 6,100.3 42.20 INJECTION 5.453 OTIS LB 2.344 7,271.8 6,130.3 42.11 BLAST JTS 3.668 2.347 7,443.3 6,258.7 40.73 INJECTION 5.453 OTIS LB 2.344 7,462.4 6,273.2 40.52 SEAL ASSY 4.000 OTIS LOCATOR SEAL ASSEMBLY 2.441 7,463.4 6,273.9 40.51 PACKER 6.156 OTIS WD PACKER 3.250 7,479.2 6,285.9 40.33 NIPPLE 3.668 CAMCO D NIPPLE NO GO 2.250 7,486.6 6,291.6 40.25 SOS 3.750 OTIS SHEAR OUT SUB 2.441 Top (ftKB) 4,660.0 Set Depth … 4,756.7 Set Depth … 4,290.9 String Max No… 1.9 Tubing Description TUBING BYPASS WO Wt (lb/ft) Grade Top Connection ID (in) 1.61 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) 4,660.0 4,222.8 45.34 PLUG 2.200 PERF BULL PLUG 1.610 4,663.8 4,225.4 45.35 CONNECTOR 2.500 LEFT SAFETY CONNECT 1.625 4,664.0 4,225.6 45.35 PACKER 1.900 BAKER AL5 DUAL PACKER 1.610 4,679.2 4,236.2 45.37 SWIVEL 2.250 TELSCOPING SWIVEL 1.562 4,733.9 4,274.7 45.11 SAFETY SOS 2.500 SHEAR OUT SAFETY JT. 1.670 4,742.3 4,280.6 45.03 CONNECTOR 2.500 LEFT SAFETY CONNECT 1.625 4,742.5 4,280.8 45.03 PACKER 1.900 BAKER AL5 DUAL PACKER 1.610 4,752.7 4,288.0 44.94 BULL PLUG 2.200 PERF BULL PLUG 1.610 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) 7,160.0 6,047.6 42.61 FISH CV 6/1/2005 - PULLED 1.5"" CV @ 7159' RKB, NOSE CONE WAS ERODED OFF. CV nose cone, eroded off; attempt spear cone out unsuccessful. 2/26/06, ran impression block to GLM #2, confirmed broken CV still in mandrel; could not pull fish in broken CV after 3 attempts. 6/1/2005 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 7,063.4 5,977.0 43.77 1 GAS LIFT DMY RK 1 1/2 0.0 7/17/2004 0.000 7,158.7 6,046.6 42.62 2 INJ PATCH RM 1 1/2 0.0 6/1/2005 Broke 0.000 7,231.4 6,100.3 42.20 3 INJ DMY T-2 1 1/2 0.0 2/7/1988 0.000 7,443.3 6,258.7 40.73 4 INJ HFCV RM 1 1/2 0.0 9/1/2011 0.000 1A-14, 10/25/2023 9:50:40 AM Vertical schematic (actual) PRODUCTION; 29.7-8,263.3 IPERF; 7,594.0-7,626.0 IPERF; 7,572.0-7,584.0 PACKER; 7,463.4 INJECTION; 7,443.3 IPERF; 7,379.0-7,402.0 IPERF; 7,353.0-7,359.0 IPERF; 7,339.0-7,347.0 IPERF; 7,280.0-7,334.0 INJECTION; 7,231.4 INJECTION; 7,158.7 FISH; 7,160.0 PACKER; 7,112.6 GAS LIFT; 7,063.4 PACKER; 4,744.3 PACKER; 4,742.5 PACKER; 4,664.9 PACKER; 4,664.0 SURFACE; 31.2-2,390.8 SAFETY VLV; 1,806.2 CONDUCTOR; 33.0-80.0 KUP INJ KB-Grd (ft) 39.01 RR Date 2/11/1982 Other Elev… 1A-14 ... TD Act Btm (ftKB) 8,285.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292070600 Wellbore Status INJ Max Angle & MD Incl (°) 49.93 MD (ftKB) 6,600.00 WELLNAME WELLBORE1A-14 Annotation Last WO: End Date 2/7/1988 H2S (ppm) DateComment SSSV: LOCKED OUT Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,280.0 7,334.0 6,136.4 6,176.5 C-4, C-3, 1A-14 2/11/1982 4.0 IPERF 120° Phasing; 4" Vann Guns 7,339.0 7,347.0 6,180.2 6,186.2 C-2, 1A-14 2/11/1982 4.0 IPERF 120° Phasing; 4" Vann Guns 7,353.0 7,359.0 6,190.7 6,195.2 C-2, 1A-14 2/11/1982 4.0 IPERF 120° Phasing; 4" Vann Guns 7,379.0 7,402.0 6,210.2 6,227.5 C-1, UNIT B, 1A- 14 2/11/1982 4.0 IPERF 120° Phasing; 4" Vann Guns 7,572.0 7,584.0 6,357.2 6,366.5 A-5, 1A-14 2/11/1982 4.0 IPERF 120° Phasing; 4" Vann Guns 7,594.0 7,626.0 6,374.3 6,399.2 A-4, 1A-14 2/11/1982 4.0 IPERF 120° Phasing; 4" Vann Guns 1A-14, 10/25/2023 9:50:41 AM Vertical schematic (actual) PRODUCTION; 29.7-8,263.3 IPERF; 7,594.0-7,626.0 IPERF; 7,572.0-7,584.0 PACKER; 7,463.4 INJECTION; 7,443.3 IPERF; 7,379.0-7,402.0 IPERF; 7,353.0-7,359.0 IPERF; 7,339.0-7,347.0 IPERF; 7,280.0-7,334.0 INJECTION; 7,231.4 INJECTION; 7,158.7 FISH; 7,160.0 PACKER; 7,112.6 GAS LIFT; 7,063.4 PACKER; 4,744.3 PACKER; 4,742.5 PACKER; 4,664.9 PACKER; 4,664.0 SURFACE; 31.2-2,390.8 SAFETY VLV; 1,806.2 CONDUCTOR; 33.0-80.0 KUP INJ 1A-14 ... WELLNAME WELLBORE1A-14 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, September 1, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1A-14 KUPARUK RIV UNIT 1A-14 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/01/2023 1A-14 50-029-20706-00-00 182-010-0 W SPT 6014 1820100 3000 2250 2250 2250 2250 367 460 460 460 REQVAR P Adam Earl 7/12/2023 MIT-IA tested as per AIO 2C.082 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 1A-14 Inspection Date: Tubing OA Packer Depth 560 3310 3160 3120IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE230714091512 BBL Pumped:4.3 BBL Returned:4.2 Friday, September 1, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 9 MIT-IA AIO 2C.082 James B. Regg Digitally signed by James B. Regg Date: 2023.09.01 16:06:00 -08'00' MEMORANDUM TO: Jim Regg --? P.I. Supervisor2C' Z'� FROM: Austin McLeod Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 14, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 1A-14 KUPARUK RIV UNIT 1A-14 Src: Inspector Reviewed By: P.I. Supry -:T-99 v Comm Well Name KUPARUK RIV UNIT 1A-14 API Well Number 50-029-20706-00-00 Permit Number: 182-010-0 Insp Num: mitSAM210704163531 Rel Insp Num: Inspector Name: Austin McLeod Inspection Date: 7/3/2021 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1A-14 Type InJ w- TVD 6014 Tubing— 2560 2550 I 2550 2540 _ PTD1820100 Type Test SPT' Test psi 3000— IA 650 00 _ _ 3150 - 3115, BBL Pumped: 4 BBL Returned: 3.8 OA 450 640 ' — — 615 610 - -- T - — - - — Interval L REQVAR P/F P Notes: MITIA to MAIP. AIO 2C.082. Wednesday, July 14, 2021 Page 1 of 1 Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Tuesday, December 8, 2020 11:38 AM To: Wallace, Chris D (CED) Cc: Senden, R. Tyler Subject: KRU 1A-14 (PTD182-010) Report of IA pressure increase on gas injection Attachments: 1A-14 90 day TIO trend 12.8.20.pdf Chris, KRU 1A-14 (PTD 182-010) was last reported 10/29/20 when the well was returned to 'normal' status subsequent passing 60 days of monitor period on water injection. Shortly after the last report the well was WAG'd to gas injection and while on gas injection the well has exhibited signs of IA pressurization. The plan is to WAG the well to water injection as soon as possible and submit an AA application for continued water injection only with known TxIA communication on gas (utilizing the previous passing monitor period). The well will be left online in water injection service during the interim. A 90 day TIO tend is attached. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne / Dusty Freeborn Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Thursday, October 29, 2020 7:49 AM To: Wallace, Chris D (CED) Cc: Senden, R. Tyler Subject: KRU 1A-14 (PTD 182-010) Report of suspect IA fluid level fall out update 10/29/20 Attachments: 1A-14 90 day TIO trend 10.29.20.pdf Chris, KRU 1A-14 (PTD 182-010) was previously reported for IA fluid level fall out and potential annular communication. After lubing and bleeding fluids into the IA a passing diagnostic MITIA was acquired and the initial 30 day monitor period did not exhibit annular communication. The IA pressure was then increased above the OA pressure to establish significant differential pressure and an additional 30 day monitor period did not exhibit annular communication. CPAI intends to return the well to 'normal' status at this time. A 90 day TIO trend is attached. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne / Dusty Freeborn Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 RIcm,,anmp, WELLS TEAM Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Tuesday, September 29, 2020 11:33 AM To: Wallace, Chris D (CED) Cc: CPA Wells Supt; Well Integrity Compliance Specialist CPF1 & 2 Subject: RE: 1A-14 (PTD# 182-010) Report of suspect IA fluid level fall out Attachments: 1A-14 90 Day TIO plot.pdf Chris- Kuparuk Injector 1A-14 (PTD #182-010) is completing the 30 day monitor period for the depressed IA fluid level. The IA passed a diagnostic MIT -IA at the beginning of the 30 day monitor period and the IA pressure was reduced below the OA pressure to investigate for IAxOA communication. The IA showed minor pressure increase but the OA did not show indications of communication with the IA. DHD will be mobilized to increase the IAP above the OA pressure and then monitor the IA for pressure stabilization. CPAI intention is to extend the monitor period by an additional 30 days to investigate if the IA will continue to increase is pressure. Attached is a copy of the current 90 day TIO plot. Please let me know if you have any questions or disagree with the plan. Dusty Freeborn/Jan Byrne Wells Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 WELLS TEAM Conoco'Philiips From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Saturday, August 29, 2020 11:50 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: CPA Wells Supt <n1030@conocophillips.com>; Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Subject: 1A-14 (PTD# 182-010) Report of suspect IA fluid level fall out Chris- Kuparuk Injector 1A-14 (PTD# 182-010) was found with a deeper than expected IA fluid level. Because the completion of the well does not allow for the IA to be circulated out with fresh fluids it is CPAI's intention to bleed the IA substantially and then "Lubricate and Bleed" to fill the annulus. Once the IA has been fluid packed the initial set of diagnostics will be conducted and the well will be monitored for 30 days to investigate the IA fluid level fall out. Please let me know if you have any questions or disagree with the plan. Attached is a copy of the current 90 day TIO plot and well bore schematic. Dusty Freeborn/Jan Byrne Wells Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 WELLS TEAM ConocoPhillips Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Saturday, August 29, 2020 11:50 AM To: Wallace, Chris D (CED) Cc: CPA Wells Supt; Well Integrity Compliance Specialist CPF1 & 2 Subject: 1A -14P( TD# 182-010) Report of suspect IA fluid level fall out Attachments: 1A-14 90 Day TIO plot .pdf; 1A-14.pdf Chris- Kuparuk Injector 1A-14 (PTD# 182-010) was found with a deeper than expected IA fluid level. Because the completion of the well does not allow for the IA to be circulated out with fresh fluids it is CPAI's intention to bleed the IA substantially and then "Lubricate and Bleed" to fill the annulus. Once the IA has been fluid packed the initial set of diagnostics will be conducted and the well will be monitored for 30 days to investigate the IA fluid level fall out. Please let me know if you have any questions or disagree with the plan. Attached is a copy of the current 90 day TIO plot and well bore schematic. Dusty Freeborn/Jan Byrne Wells Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 Aft WELLS TEAM Conoco miips Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Saturday, August 29, 2020 11:50 AM To: Wallace, Chris D (CED) Cc: CPA Wells Supt; Well Integrity Compliance Specialist CPF1 & 2 Subject: 1A -14P( TD# 182-010) Report of suspect IA fluid level fall out Attachments: 1A-14 90 Day TIO plot .pdf; 1A-14.pdf Chris- Kuparuk Injector 1A-14 (PTD# 182-010) was found with a deeper than expected IA fluid level. Because the completion of the well does not allow for the IA to be circulated out with fresh fluids it is CPAI's intention to bleed the IA substantially and then "Lubricate and Bleed" to fill the annulus. Once the IA has been fluid packed the initial set of diagnostics will be conducted and the well will be monitored for 30 days to investigate the IA fluid level fall out. Please let me know if you have any questions or disagree with the plan. Attached is a copy of the current 90 day TIO plot and well bore schematic. Dusty Freeborn/Jan Byrne Wells Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 Aft WELLS TEAM Conoco miips MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, August 26, 2019 TO: Jim Regg P.I. Superviso�Q- e j y'��i 1 SUBJECT: Mechanical Integrity Tests GG I/ ConocoPt illips Alaska, Inc. IA -14 FROM: Adam Earl KUPARUK RIV UNIT IA -14 Petroleum Inspector Sre: Inspector Reviewed By: P.I. Supry NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT IA -14 API Well Number 50-029-20706-00-00 Inspector Name: Adam Earl Permit Number: 182-010-0 Inspection Date: 8/242019 Insp Num: mitAGE190826082739 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1A-14 Type Inj G - TVD 6014 Tubing 2460 - 2460 2460 2460 PTD Iszoloo Type Test sPT Test psi 1so4 - IA 1400 1900 - 1840 - 1820 -� BBL Pumped: as BBL Returned: 0.8 OA 570 600 � 600 600 Interval _ 4YRTST Notes: MIT IA Monday, August 26, 2019 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg -'e r S DATE: Monday,July 20,2015 P.I.Supervisor f SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC IA-14 FROM: Bob Noble KUPARUK RIV UNIT 1A-14 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1A-14 API Well Number 50-029-20706-00-00 Inspector Name: Bob Noble Permit Number: 182-010-0 Inspection Date: 7/17/2015 Insp Num: mitRCN150719140711 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min FT- Well T 1A-14 Type Inj W 7TVD 6014 - Tubing 1900 . 1900 _ 1900 1900 PTD 1820100 Type Test SPT ETest psi 1504 " IA 1070 2700 - 2580 - 2570 - Interval 4\RTST P/F P / OA 245 245 245 - 245- Notes: u 0.161455 Monday,July 20,2015 Page 1 of 1 • 0 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 27, 2011 TO: Jim Regg P1. Supervisor i( 9 1(01V V SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC IA -14 FROM: Chuck Scheve KUPARUK RIV UNIT IA -14 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry ,.1./ NON - CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT IA - 14 API Well Number: 50 029 - 20706 - 00 - 00 Inspector Name: Chuck Scheve Insp Num: mitCS110727070622 Permit Number: 182 - 010 - Inspection Date: 7/26/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1A-14 'IType Inj. N ' TVD 60 14 ' 1 IA 800 1980 1940 1940 - P.T.D 182 0100 ' I SPT Test psi 1503 ' OA 440 440 440 440 Interval 4YRTST - p/F P - Tubing 1050 1050 1050 1050 Notes: Wednesday, July 27, 2011 Page 1 of 1 ConacoPhillips a~~ P.O. BOX 100360 ANCHORAGE, AIASKA 99510-0360 July 16~', 2010 Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Commissioner Dan Seamount: • ~~4~G~ V GQ JUL 2 ~ 2010 #~leska ~! & Ga. Cott. Cemrnission ~ncfibrage Isa-oho /r~-~4 Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRin. Each of these wells was found to have a void in the conductor. These voids were filled with corrosion inhibitor, engineered to prevent water from entering the annulaz space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped November 25~' 2007 & Mazch 21 2009, the corrosion inhibitor/sealant was pumped July 6~', 7~', 8~' 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, Perry Klein ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips~ Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 7116110 1A.1 C.1 E PAD Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1A-11 50029206850000 1811730 10" Na 10" Na 3.4 7/8/2010 1A-12 50029206880000 1811780 2" Na 2" Na 1.7 7/8/2010 1A-13 50029207000000 1811950 11" Na 11" n/a 3.4 7/8/2010 A-14 5~29207~0000 1820100 4" Na 4" Na 2.1 7/8/2010 1C-01 50029205260000 1801280 SF n/a 24" n/a 4.3 7/6/2010 1 C-02 50029205320000 1801350 24" n/a 24" Na 8.5 7/6!2010 1 C-03A 50029205350100 2070630 SF n/a 16" Na 7.7 7/6/2010 1 C-04 50029205470000 1801550 SF n/a 5" n/a 2.6 7/6/2010 1C-06 50029205640000 1810250 76 17.70 32" 3/21/2009 9.4 7/6/2010 1 C-09 50029208590000 1821850 38' 8.00 6" 11 /25!2007 6.8 7/6/2010 1C-10 50029208650000 1821930 37'6" 8.00 8" 11/25/2007 6.8 7/6/2010 1E-02 50029204720000 1800500 21" n/a 21" n/a 1.7 7/7/2010 1 E-03 50029204770000 1800560 4" n/a 4" Na 2.4 7/7/2010 1E-06 50029204930000 1800780 12" n/a 12" n/a 13.6 7/7/2010 1 E-07 50029204950000 1800800 5" n/a 5" Na 2.6 7/7/2010 1 E-08 50029204960000 1800810 5" n/a 5" Na 2.6 7/7/2010 1 E-10 50029207250000 1820360 2" n/a 2" Na 1.7 7/7/2010 1 E-13 50029207500000 1820780 5" Na 5" Na 2.6 717/2010 1E-19 50029209050000 1830170 1" Na 1" Na 1.7 7R/2010 1 E-21 50029208920000 1830020 3" Na 3" Na 2.6 7/7/2010 1 E-24A 50029208570100 1971870 2" Na 2" Na 1.7 7/7/2010 1E-25 50029208440000 1821700 3" Na 3" n/a 1.7 7/7/2010 1 E-28 50029208320000 1821580 4" n/a 4" n/a 2.5 7/8/2010 1E-29 50029208280000 1821540 7" n/a 7" n/a 2.5 7/8/2010 • • SEAN PARNELL, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Darrell R. Humphrey Production Engineering Specialist ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 ~~~~ ,~al~ ~ ~~~ Re: Kuparuk River Field, Kuparuk Oil Pool, 1A-14 Sundry Number: 310-014 Dear Mr. Humphrey: .0~~ ~~ ~ 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this 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 rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this 2 0 day of January, 2010 Encl. • • ConocoPhillips January 15, 2010 Dan Seamount AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 33 W. 7`" Ave. Ste. 100 Anchorage, AK 99501 Robert Christensen/Darrell Humphrey Production Engineering Specialists. Greater Kuparuk Unit , NSK-69 PO Box 196105 Anchorage, AK 99519-6105 Phone: (907)659-7535 Fax: 659-7314 RECEIVED JAN 1 ~ zoo Ai~tlca Oil & 6ea Cerra. Comm=aion l~~~hara~ Dear Mr. Seamount, ConocoPhillips Alaska, Inc. requests approval to pull a patch to open C sand for Kuparuk Well 1A-14. Enclosed you will find 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. regarding 1A-14 (PTD 182-010). If you have any questions regarding this matter, please contact myself or Robert D. Christensen at 659-7535. Sincerely, Darrell R. Humphrey Attachments Sundry application Well schematic r' ,. STATE OF ALASKA Al~ OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 '~~ ~ r \O 1 ~ ~ ~,v 1. Type of Request: Abandon r Rug for t2edrill C Pr;rforate New Fool ^ Repair w ell [~trenge Approved Program Suspend ^ Rug Pertoratbns [` Perforate C Pub Tubing r Time 6ctensan Operational Shutdaw n ^ Re-enter Susp. Well r Stimulate C Alter casing (- Other: Pull PatcFCJ1 . 2.Operator Name: 4. Current Well Class: 5. Permit to Orill Number. ConocoPhillips Alaska, Inc. Development r Exploratory ^ 182-010 • 3. Address: SVatgraphic C Service n ' 6. API Number. P. O. Box 100360, Anchorage, Alaska 99510 50-029-20706-00 • 7. If perforating, dosest approach in pool(s) opened by this operation to nearest property line where 8. Well Name and Number: ownership or landownership changes: Sparing Exception Required? YeS ~ No +~ 1A-14 9. Property Designation: 2~b ~ 7 1~•Z%~ .•L~ , r v 10. Field/Pool(s): ADL 2/ ALK 465 Kuparuk River Field / Kuparuk Oil Pool ' 11. P RESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 8285 6934 7729' 6838' 4460,4752 7160' Casing Length Size MD ND Burst Collapse CONDUCTOR 80 16 80' 80' SURFACE 2391 10.75 2391' 2391' PRODUCTION 8263 7 8263' 6915' e ora on ep e o ion ep u ing ¢e: u mg ra e: u tng 7280-7334,7339-7347,7353-7359,7379- 6137-6177, 6181-6187,6191-6196,6211- 7402,7572-7584,7594-7626 6228,6358-6367,6375-6400 2.875 J-55 7487 Packers and SSSV Type: PLUG -PERF BULL PLUG FOR PACKER BY-PASS SET 1/1/1987 Packers and SSSV MD (ft) and ND (ft) MD= 4460 ND= 4085 ~~'~~' V E~ PACKER -BAKER 7" AL-5 DUAL PACKER; 1.9" 00 (1.61" ID) SHORT MD= 4665 ND= 4227 STRING PACKER -BAKER 7" AL-5 DUAL PACKER MD= 4744 ND= 4283 JAN 1 ~ 2 0 ~ 0 PLUG -PERF BULL PLUG FOR PACKER BY-PASS SET 1/1/1987 MD= 4752 ND= 4288 ~+ NNlalta Oil 8 6>as Cana. C PACKER -BAKER 'DB' PACKER MD= 7113 ND= 6014 PATCH -SET 2.875" PATCH 7142'-7166', 5/15/2006, LOWER ELEMENT MD= 7142 ND= 6035 A~~~~I'~~~ SET 7' BELOW LEAKING C SAND INJ MNDRL, LOWER SNAP LATCH SHEAR #4800 PACKER - OTIS'WD' PACKER MD= 7463 ND= 6274 SSSV LOCKED OUT - CAMCO TRDP-1A (LOCKED OUT 2/23/2004) MD=1806 ND= 1806 12. Attachments: Descriptan Summary of Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ~ ~lomtory ~ Deeelopment ^ Service r 14. Estimated Date for Commenting Operations: 15. Well Status after proposed work: JaN2o1o Gas G WDSPL ~ Plugged Oil ~ 16. Verbal Approval: Date: . WINJ GINJ r WAG ~ Abandoned Commission Representative: . Zv !o - GSTOR ^ SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Bob ChristenseNDarrell Humphrey Printed Name Darrell R. Humphrey Title: Production Engineering Spedalist Signature Phone: 659-7535 Date (s •. j Commission U e nl Sundry Nu er. Condfions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test ~ Location Clearance r Other. Subsequent Form Required: ~ D • y ~ Y APPROVED BY Zo / 0 Approved by: COMMISSIONER THE COMMISSION Date: I$glr' T~°'f D Submit in Du Itcate .~~~o • w ~ ~~ ~. . 1A-14 DESCRIPTION SUMMARY OF PROPOSAL Proposed Operation. ;Opening C sand in 1A-14 will enable lean gas injection to mobilze and recover NGLs remaining from the ;mature MI flood in the pattern. ;Pull the patch across the top selective mandrel -;Pull the DV from the bottom selective mandrel and replace with a CV ;1. MI, RU. Pull the patch at 7142' MD. ;2. Replace DV at 7443' MD with the largest port 1.5" CV possible. ;3. RD. Turn well over to DSO to be put on lean gas injection. k F ~ . . ~~,~ KUP ~ 1A-14 ~q'~p~1)j~~jp$ ell Attributes Max An le 8 MD TD AIeSi1d )t1 , Wallhore API/UWI Fleltl Name Well Status Inc! (°) MD (RKB) Act etm (RKB) 500292070600 KUPARUK RIVER UNIT INJ 49.93 6,600.00 8,285.0 Comment 923 (ppm) Dah Mnobtlon Entl Data KB-Grtl (R) Rlg Release Data ~~• LOCKED OUT Camc 0 7/1/2008 last WO: 2/711968 39 01 2/11/1982 WNI - A-11 7 1/2009 3.50'.04 PM ... . Scnemelk-Noel Annotation Depth (RNB) Entl Dale Annoatlon last Mod By Entl Data Last Tag: 7,739.0 52/2006 Rev Reason: add TTl wmments ehelton 524/2009 Casln Strin s String OD String ID Se[ Depth Sat Daplh (TVD) String Wt String CONDUCTOR, Caaing Description (In) (In) lop (RKB) (ftK8) (RKB) 9ba/R) Gratle String Top Thrtl SD CONDUCTOR i 6 15.062 0.0 80.0 80.0 65.00 H-40 ' SURFACE 10 3/ 4 9.794 0.0 2,391.0 2,390.8 45.50 K-55 sssv, t ea5 . ~ PRODUCTION 7 6.151 0.0 8,263.0 6,915.5 26.00 K-55 Tobin Strin s SURFACE, Slring OD String ID Set Deplh Set Depth (TVD) String Wt String 2.391 Tu61ng Description (In) (In) Top (RKB) (ftK8) (ftK8) (10sm) Grade gtring Top Thrtl TUBING 3 1 2 2.992 0.0 4,663.0 4,225.6 9.20 J-55 BTC AB-MOD PLUG, /.aso TUBING 2 7/ 8 2.441 4,663.0 7,487.0 6,292.5 6.50 J-55 EUE 8R0 AB-MOD aYPAa3. <.183 Other In Hole All Jewe l : Tobin Run 8L Retrievable Flsh etc. Top Deptn (TVD) Top Inc! Top (RKB) (RKB) (•) Dsacrlptlon Comment Run Date ID (In) PACKER, 6,865 1,806 1,805.9 1.10 S SSV LOCKED OUT Camco TRDP-1A (LOCKED OUT 2!7/1988 2.812 223/2004) 4,460 4,085.5 46.94 P LUG PERF BULL PLUG FOR PACKER BY-PASS set 1/117987 1/1/1997 1.610 PACKER. 1.714 4,463 4,087.5 46.92 B YPASS PUP JOINT W/LEFT HAND SAFETY CONNECTOR AND 1/1/1997 1.670 TELESCOPING SWIVEL BY-PASSING DUAL PACKERS. HOLE @4707-4712', FIXED WITH ISOLATION PACKERS & 1.9" TBG PUP FROM 4463-0757'STRING BETWEEN PACKERS TO ALLOW PRESSURE COMMUNICATION TO PLUG, a.7sz CASING BELOW 4,665 4,227.0 45.66 P ACKER Baker 7" AL-5 Dual Packer; 1.9" OD (1.61" ID) short stung 27711988 2.438 GAS LIFT. 4,744 4,282.8 45.26 P ACKER Baker 7" AL-5 Dual Packer 21711988 2.438 7 os3 4,752 4,288.4 45.16 P LUG PERF BULL PLUG FOR PACKER BY-PASS set 111/1987 12/7997 1.610 7,063 5,977.3 43.45 G AS LIFT CAMCOIMMG-PI1.5IDMY/RK//I Comment: STA 1 71172004 2.375 7,111 6,012.0 42.46 S 8R Baker 80-30 Loc Seal Assy 217/1988 2.047 sea, 7,111 7,113 6,013.5 42.46 P ACKER Baker'DB'PACKER 2!7/1988 3.250 7,742 6,034.8 42.39 P ATCH SET 2.875" PATCH 7142'-7166', 5/152006, LOWER 51152006 1.380 ELEMENT SET 7' BELOW LEAKING C SAND INJ MNDRL, LOWER SNAP LATCH SHEAR #4800 PACKER, 7,113 7,159 6,047.4 42.361N JECTION OTISI'L8'/1.5//RMII/Comment: BROKEN STA2 8172005 2.344 7,160 6,048.1 42.35 F ISH CV 6/12005 -PULLED 1.5"" CV @ 7159' RKB, NOSE 8/12005 CONE WAS ERODED OFF. ATTEMPT TO SPEAR CONE PATCH. 7.11] OUT, NO SUCCESS 2262006 -RAN IMPRESSION BLOCK TO STA # 2 @ ~G 7159' RKB AND CONFIRMED BROKEN CV STILL IN P MANDREL. MADE THREE RUNS W/ SPEAR IN ATTEMPT INJECTION. TO FISH BROKEN CV @ 7159' RKB (FISH STILL THERE 7.159 FISH. 7,180 - 7,231 6,100.6 42.201N JECTION OTISPLB'/1.5IDMY/T-2/I/Comment: CLOSED STA3 2/7/1988 2.344 7,443 6,259.1 40.741N JECTION OTISfLB'/1.5/DMY7r-2/I/Comment: CLOSED STA4 2/711988 2.344 INJECTION, 7,463 6,274.3 40.51 P ACKER Otis'WD'PACKER 2(711988 4.000 7,231 7,479 6,286.4 40.33 N IPPLE Camco'D'Nipple NO GO 217/1988 2.250 7,487 6,292.5 40.25 S OS Otis 2(7/1988 2.441 (PERF, 7,487 6,292.5 40.25 T TL ELMD TTl @ 7476' during (PROF on 9/142004 2/7/1988 2.441 7 280.1,33/ Perfora tions 8 Slots Top (TVD) Btm (TVD) Shot Dens (PERF, Top (RKB) Btm (RNB) (RKB) (RNa) Zons Dab (ah... Type Commsnt ~ 339-7,317 7,280 7,334 6,137.0 6.177.5 C -4, C-3, 1A-14 2111/1982 4.0 (PERF 120 deg. Phasing; 4" Vann Guns 7,339 7,347 6,181.2 6,187.1 C -2, 1A-14 2/71/1982 4.0 (PERF 120 deg. Phasing; 4' Vann Guns IPERF, 7,353 7,359 6,191.5 6,195.9 C -2, 1A-14 2/71/1982 4.0 (PERF 120 deg. Phasing; 4" Vann Guns 7,353-7.359 7,379 7,402 6,270.8 6,228.1 C -7, UNIT B, 2!11/1982 4.0 (PERF 120 deg. Phasing; 4" Vann Guns 1 A-14 PERF 7,572 7,584 6,357.9 8,367.1 A -5, 1A-14 2/1111982 4.0 (PERF 120 deg. Phasing;4" Vann Guns ( , 1.379-7.001 ],5gq 7,626 8,374.9 6,399.9 A -0, 1A-14 2/17/1982 4.0 (PERF 120 d Phesin 4" Vann Guns e9~ 9. INJECTION. 7.003 PACKER, 1,153 NIPPLE, 7,178 TTL. 7,181 ~;'. SOS, 7,181 IPERF, ~ sn-7sea IPERF, 7,581-7 828 PRODUCTION, 8283 TD, 8 285 L~L.-.-. ..... '...d'-'-' UH L L"...., u.., .. '-', "L , . u.., ~JJJ u.., ~JJ"" . ragt: 1 01 L. Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Monday, July 30,20078:02 PM To: Regg, James B (DOA) Subject: RE: KRU & CRU MITIAs 1A, 1G, 1F, & 1J & CD3 & CD4 Attachments: 1A-14.pdf I '01 ~(tt 1 \6\\ -O\(J \~d- ,,\L.t ~p\ Jim, You are correct. It appears that we made a mistake and noted the top portion of the dual packer in the short string at 4665' MD and 4227' TVO, Our schematic shows the top packer of the selective completion at 7113' MD and 6014" TVD which is comparable to your ,,/ calculations based on the sundry information. It looks like we tested the the IA at 2100 psi, fortunately that was above the required test pressure. I am correcting the depth on my form and reprinting the test for our hard files, Would you like me to resubmit the test with the corrected packer TVO? Thanks for the catch and I apologize for the mistake. We'll pay closer attention to detail in the future, Perry Klein Problem Well Supervisor office (907) 659-7224 Cell (907) 943-1244 Pager (907) 659-7000 x909 n1617@conocophillips.com SCANNED AUG 2 3 2007 MI_ .I!.. . .W , .1 ~,...,.___::.. ~""'~..1i/:ift¡#,·:-~_'.-:'~--:'_":· From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Monday, July 30, 2007 3:39 PM To: NSK Problem Well Supv Subject: RE: KRU & CRU MmAs lA, lG, lF, & 1] & CD3 & CD4 Please check the packer depth for KRU 1A-14; I calculate the TVD to be 6081 ft based on depth (MD) reported on most recent sundry approvals and directional survey, MIT form for 1A-14 shows TVD of packer to be 4227 ft 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: Thursday, July 26, 2007 9:55 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Fleckenstein, Robert J (DOA) Cc: Cawvey, Von; NSK Problem Well Supv Subject: KRU & CRU MmAs lA, lG, lF, & 1] & CD3 & CD4 7/31/2007 l......RU (X.. L-RU IV1111rt:s lrt, IV, lr,. (X, \....V.J (X, \....V't . rage L. or L Tom, Jim, & Bob, Attached are passing MITIAs as witnessed by Bob Noble on 7/14 and 7/15. 1J, CD3 & C04 were initial MITIAs for new wells. 1A, 1G, & 1F are 4 yr MITIAs. 31 pad is the only pad left to MITIA before 7/31/07, we plan to schedule it soon. Please let me, Perry Klein, or MJ Loveland know if there are any questions, Marie McConnell Problem Well Supervisor (907) 659-7224 n1617@conocophillips.com «MIT KRU 1J 07-14-07.xls» «MIT KRU 1F-02 07-15-07,xls» «MIT KRU 1G 07-14-07.xls» «MIT KRU 1G 07-15- 07.xls» «MIT KRU 1A 07-15-07.xls» «MIT CRU CD3-302 7-19-07.xls» «MIT CRU CD4-302 7-18-07.xls» 7/31/2007 MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: DATE: Friday, July 20, 2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC IA-14 KUPARUK RlV UNIT IA-14 Jim Regg K· ( Pol. S"P"~ro, "-'0/7 7 1il D'7 FROM: Bob Noble Petroleum Inspector Src: Inspector Reviewed B~ P.l. Suprv ',,- \ rs{L Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT IA-14 API Well Number: 50-029-20706-00-00 Inspector Name: Bob Noble Insp Num: mitRCN070719132921 Permit Number: 182-010-0 Inspection Date: 7/15/2007 ReI Insp Num: Packer ¡ Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Depth /-, D \.4; Well i IA-14 ¡Type Inj. i W ¡ TVD i ~l IA i 700 i 2740 2700 I 2690 i P.T.Di 1820100 !TypeTest I SPT i Test psi I i OA ì I ì 2740 i 200 ¡ 230 230 230 I i ! I i Interval 4YRTST P/F P Tubing; 2050 I 2100 2100 I 2100 I , Notes: ! 1 ' I\.v't-e P C{Ckff T V~ eJvliL:~ Ca2.Cl'LtJeS '0 ìA I 5?-< - j)J_ Ct' ._ 1 ~~L ~\PcJ Friday, July 20, 2007 Page I of I Schlumberger NO. 3213 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: 8eth !j¿7 09/24/04 Company: Alaska Oil & Gas Cons Comm AUn: Robin Deason 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job# Log Description Date 8L Color <¡ £f -OL{ 2- 3C-06 10922465 PRODUCTION PROFILE W/DEFT 09/19/04 1 ~5 -05' 2A-18 10802936 PRODUCTION PROFILE W/DEFT 09/12/04 1 111{" 038 28-12 10802934 INJECTION PROFILE 09/10/04 1 ~ lj- I b'1 I 2X-11 10802933 PRODUCTION PROFILE 09/09/04 1 (~L- ~.f 18-10 10922467 PRODUCTION PROFILE 09/21/04 1 ) () ". fJ5 3G-08 10802935 PRODUCTION PROFILE 09/11/04 1 r.¡-OZ( 2F-08 10922466 PRODUCTION PROFILE 09/20/04 1 ~'Í- (( 7 2G-11 10884019 PRODUCTION PROFILE 09/08/04 1 f ~2. -I~~ 1 H-19 10802940 INJECTION PROFILE 09/14/04 1 1 2.-0 If 1H-07 10802939 INJECTION PROFILE 09/14/04 1 ~2. -()(O 1A-14 10802938 INJECTION PROFILE 09/13/04 1 t Li-- 010 2H-03 10802945 INJECTION PROFILE 09/18/04 1 Iß?'-O 5' _1Y-02 10802942 INJECTION PROFILE 09/16/04 1 '~- Ot.f'f 1Q-13 10802941 INJECTION PROFILE 09/15/04 1 7 -H ~ 3H-09 10922468 INJECTION PROFILE 09/22/04 1 ¡1l6-llfl 2T-02 10802944 TEMPERATURE SURVEY 09/18/04 1 .ltjt) -I r,{p1A-26 10802943 LEAK DETECTION LOG 09/17/04 1 Kuparuk CD ~ Sl¿;~ I. ál'~ ~CANNED NOli /J B 2004 DATE: /f 0/ Please sign and returle copy of this transm iltal to Beth at the above address or fax to (907) 561-8317. Thank you. r-" ~ MEM 0 RAND UM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ":Ka[iO¡ k,\í\cŸ\' Pol. Supervisor ( I DATE: Wednesday, June 02, 2004 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC ]A.]4 KUPARUK R]V UN]T ]A-]4 I~~--()JD FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.Io Suprv~:g.e./ Comm NON-CO NFID ENTIAL Well Name: KUPARUK RIV UNIT ]A-14 API Well Numbe Permit Number 50-029-20706-00-00 Inspector Name: 1820100 Inspection Date: Chuck Scheve 5/30/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well: ]A-]4 Type Inj. p TVD 6933 IA ]200 ]850 ]850 ]850 P.T. ]820100 TypeTest SPT Test psi 1503.5 OA 200 250 250 250 Interval 4YRTST P/F P Tubing 2600 2600 2600 2600 Notes: The pretest pressures were observed for 30+ minutes and found stable. Well demonstrated good mechanical integrity. Wednesday, June 02, 2004 Page I of I 3BG TIME 'lIME *P q TYPE OF PKR REQ CgG ~ ~o~ ' e~o ~zev ~zoo ........ ~ll~ .... 5~0 2z~O Zl3g DIESEL (~YCCL SALT WATER DRIIZ~G MUD OTEE~ ~: ~: In/rial __ 4-F~r ~ Workover -- Explain: To Ms. B~ W'm~z=l.1 (27~7~42} (Fg= 2.16.3) COMPANY REP SIGNATURE: - RE EI-VED L ~ 7 !992 Bas Cons. Commission STATE OF ALASKA ALAS ~ OIL AND GAS CONSERVATION COM ,,.sSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other~ 2. Name of Operator AI~£~ Alaska.; Tn.c: 3. Address P.O. Box 100360. Anchoraae. Alaska 9cJ510-0360 4. Location of well at surface 1169' FSL, 493' FWL, Sec 5 TllN R10E UM At top of productive interval ' ' ' ' 1197' FSL, 1862' FWL, Sec. 5, T11N, R10E, UM At effective depth 887' FSL, 1311' FEL, Sec. 5, T11N, R10E, UM At total depth 887' FSL. 1311' FEL. Sec. 5. TllN: RIOE. UM 11. Present well condition summary Total depth: measured 8285' MD feet true vertical 6933' TVD feet 5. Datum elevation (DF or KB) RKB 93' 6. Unit or Property name Kuparuk RivPr Ilnit 7. Well number 8. ApprovaF number 7_")~7 9. APl n'urn~b~e'r 50-- 029-20706 10. Pool Feet Kuparuk River Oil Pool Plugs (measured) 8170' 12. Effective depth: measured 8170' MD feet true vertical feet 6839' TVD Casing Length Size Structural Conductor Surface Intermediate Production Liner Perforation depth: 80' 16" 2391' 10-3/4" 8263' 7" measured Junk (measured) None Cemented Measured depth True Vertical depth 200 SX PF 80' MD 950 SX FONDN & 2391' MD 259 SX ASII 1225 SX Class G 8263' MD 7280'-7334', 7339'-7347', 7353'-7359, 7379'-7402'MD 7572'-7584, 7594' -7626' 80' TVD 2391' TVD true vertical 6137'-6176' 6181'-6186' 6192'-6196' 6210'-6228' Tubing (size, grade and measured dep6t3n~8'-6367', 6375'-6400' 6915' TVD TVD 3½", J-55, @ 7488' MD Packers and SSSV (type and measured depth) CAMCO TRDP-]A SSSV Fa 19.~7' Mil; {lt~ I~l~H packer @ 7_?05' MD; Otis W9 Packer @ 7~,55' Stimulation or cement squeeze summary Mr~ Intervals treated (measured) . Treatment description including volumes used and final pressure 13. Prior to well operation Representative Daily Average Production or Injection Dalta OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure NA '; Tu bi ng ' Pressu re Subsequent to operation 14. Attachments Daily Report of Well Operations COpies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~'~~ ~~~~c~Title '~~ ~/~~~7 Form 10-,~04 Rev. 1~5' ' ~ Date Submit in I~uplfcate(~' ARCO Alaska, Inc.(~ '* Subsidiary of Atlantic Richfield Company WELL SERVICE REPORT WELL N]'RACTOR REMARKS tFIELD~ DISTRICT- STATE , DAYS IDASE REPORT TIME [] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK D ESC RI PTION DAILY ACCU M. TOTAL CAMCO OTIS sCHLUMBERGER DRESSER-ATLAS DOWELL HALLIBURTON ARCTIC COIL TUBING , , FRACMASTER B. J. HUGHES Roustabouts ,,, Diesel Methanol Supervision , Pre-Job Safety Meeting AFE FIELD ESTIMATE [~'~/g~,, ,~J g~ _ TOTAL REPORT OF SUNDRY WELL-OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other 1~ 2. Name of Operator ARCO .a.! as ka~ ! Dc. 3. Address P,0, BOx 100360. Anchorage? Alaska 99510-0360 4. Location of well at surface 1169' FSL., 493' FWL, Sec. 5, T11N, RIOE UN At top of productive interval ' 5. Datum elevation (DF or KB) RK_R 93' 6. Unit or Property name KuDaruk River Unit 7. Well number 1197' FSL, 1862' At effective depth 887' FSL, 1311' At total depth 887' FSL, 1311' 11. 12. lA 8. Approval number 7-43m. 9. APl number 50-- 0_9-20706 10. Pool Kuparuk River 0il FWL, Sec. 5, T11N, RIOE, UM FEL, Sec. 5, T11N, RIOE, UM FEI., Sec. 5; T11N; RIOE: UM Present well condition summary Total depth: measured 8285' MD feet true vertical 6933' TVD feet Effective depth: measured 8170' MD feet true vertical 6839' TVD feet Casing Length Size Structural Conductor 80' Surface 2391' Intermediate Production 8263' Liner Perforation depth: Plugs (measured) 8170' Junk (measured) 16" 10-3/4" 7" None Measured depth Cemented 200 SX PF 80' MD 950 SX FONDN & 2391' MD 259 SX ASII 1225 SX Class G 8263' MD True Vertical depth 80' TVD 2391' TVD 6915' TVD measured 7280'-7334' 7339' 7347' 7353'-7359, 7379'-7402'MD 7572'-7584, 7594 '-7626' true vertical 6137'-6176' 6181'-6186' 6192'-6196' 6210'-6228' TVD . 6358' -6367' 6375' -6400' Tubing (size, grade and measured aep~n~ ~ 3½" J-55 @ 7488' MD Packers and SSSV (type and measured depth) CAMCO TRDP-1A SS.qV @ 1957' MD: (lt-i~ RRM ,nacl~er @ 7?05' M_n; Otis WP Packer @ 7455' Stimulation or cement squeeze summary Feet Pool Form 10-404 Rev. 12-1-8~/ Date ~'~/'3,- ~)/'~'~ Submit in Duplicate Intervals treated (measured) Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation NA Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments Daily Report of Well Operations ~ Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ,~.-t~. -~- ~c,-..,. ~F',,,~ ARCO Alaska, Inc.(",~ Subsidiary of Atlantic Richfield ComDany WELL 'T' PBDT ~/.7,.~ ~; ')NTRACTOR · REMARKS t~°(' ~'°r'~WELL SERVICE REPORT FIELD- DISTRICT- STATE IOPERATION AT REPORT TIME DAYS i D~/TE CHECK THIS BLOCK IF SUMMARY CONTINUED ON ISigned d' DESCRIPTION DAILY ACCUM. TOTAL CAMCO OTIS SCHLUMBERGER DRESSER.ATLAS DOWELL HALLIBURTON ARCTIC COIL TUBING FRACMASTER B. J. HUGHES Methanol Supervision Diesel .... Pre-Job Safety Meeting AFE .'~,.2~o3/.¢ 6',./.. TOTAL FIELD ESTIMATE STATE OF ALASKA ALA ,~ OIL AND GAS CONSERVATION COM ,5SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other'~ 2. Name of Operator ARCO A1R~Ea. Tnt_ 3. Address P.O. Box 100360, Anchoraqe, Alaska 99510-0360 4. Location of well at surface 1169' FSL, 493' FWL, Sec. 5 T11N RIOE UM At top of productive interval ' ' ' 1197' FSL, 1862' At effective depth 887' FSL, 1311' At total depth 887' FSL, 1311' 11. Present well condition summary Total depth: measured true vertical FWL, Sec. 5, T11N, RIOE, UM FEL, Sec. 5, T11N, RIOE, UM FEL, Sec. 5, T11N, RIOE, UM 8285' MD feet 6933' TVD feet Plugs (measured) 5. Datum elevation (DF or KB) RI<B 03' Feet 6. Unit or Property name Kuparuk River Unit 7. Well number 8. Approval number 7-295 9. APl number 50-- 10. Pool Kuparuk River 0i1' Pool 8170' Effective depth: measured 8170' MD feet true vertical 6839' TVD feet Casing Length Size Structural Conductor 80' 16" Surface 2391' 10-3/4" Intermediate Production 8263 ' 7" Liner Perforation depth: measured Junk (measured) None Cemented Measured depth True Vertical depth true vertical 200 SX PF 80' MD 950 SX FONDN & 2391' MD 259 SX ASII 1225 SX Class G 8263' MD 80' TVD 2391' TVD 6915' TVD 7280'-7334', 7339'-7347', 7353'-7359, 7379'-7402'MD 7572'-7584, 7594'-7626' 6137'-6176' 6181'-6186' 6192'-6196' 6210'-6228' TVD Tubing (size, grade and measured de6p:~8'-6367', 6375'-6400' 3½", J-55, @ 7488' MD Packers and SSSV (type and measured depth) CAMCO TRDP-1A SSSV ~ 1957' MD: Otis RRH par. k~r fa 77fl_~' Mn: Otis WD Packer ~'7455' MD 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Prior to well operation Representative Daily Average Production or Injection Data Oil-Bbl NA Gas-Mcf Water-Bbl Casing. Pressure Tubing Pressu re Subsequent to operation 14. Attachments Daily Report of Well Operations'~ Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~ Signed ,~dj,A.~ /~ .4~~~¢.~~ Title Form 10-404 Rev. 12-'1-85 Date ~ubmit in Duplicate ARCO Alaska, Inc!~ ~,~ Subsidiar~ of Atlantic Richfield Company Old-TRACToR REMARKS WELL SERVICE REPORT IFIEJ~3~- DISTRICT- STATE · DAYS ._ ~~ ~/~ ) ~ IDATE /4-/?-~'7 [] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ~ DESCRIPTION DALLY ACCUMo TOTAL CAMCO OTIS SCHLUMBERGER DRESSER.ATLAS DOWELL HALLIBURTON ARCTIC COIL TUBING FRACMASTER B. J. HUGHES Roustabouts ~ , Diesel , Methanol Supervision Pre-Job Safety Meeting AFE · ~ _ TOTAL FIELD ESTIMATE T~E EVE~ iiii ,, i u s..~uOH. P ~ 1310 x ~r Cso?~ = · iii iii i : t'750.7~; /,w/IF' IF STATE OF ALASKA ALASka' OIL AND GAS CONSERVATION COM~ SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate [] Plugging ~ Perforate ~ Pull tubing Alter Casing [] Other ~ WORKOVER 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. RKB 100' Feet 3. Address 6. ~nit or Property.na~e P.O. Box 100360, Anchorage, AK 99510-0360 ~uparuk River unit 4. Location of well at surface 1169' FSL, 493' FWL, Sec. 5, T11N, R10E, UM At top of productive interval 1068' FSL, 1613' FEL, Sec. 5, TllN, R10E, UM 7. Well number /... '.~ .... ~, .~ 8. Approval number ~7-780 At effective depth 922' FSL, 1365' FEL, Sec. 5, TllN, At total depth 887' FSL~ 1311' FEL~ Sec. 5~ TllN~ 11. Present well condition summary Total depth: measured 8285 .true vertical 6933 RIOE, UM RIOE~ UM 9. APl number 50-- 029-20706 10. Pool Kuparuk River Oil Pool 'MD ' TVD feet feet Plugs (measured) None Effective depth: measured 8170 'MD true vertical 6838'TVD feet feet Junk (measured) Fill ~ 7729' Casing Length Size Conductor 80' 16" Surface 2360' 10-3/4" Production 8234' 7" Cemented 200 sx PF 950 sx Fondu & 250 sx AS il 1225 sx Class G & 250 sx AS II Perforation depth: measured 7280'.-7334', 7339'-7347' 7379'-7402', 7572'-7584' , 7353'-7359' , 7594'-7626' , 6191'-6195' , 6374'-6399' 'Measured depth 80'MD 2391'MD 8263'MD true vertical 6136'-6177', 6180' -6186 ' , 6210 ' -6227 ', 6357 ' -6367 ' Tubing (size, grade and measured depth) 3-1/2"/2-7/8", J-55, tbg w/tail ~ 7488', 2-7/8", J-55, tbg w/tail @ 4757' Packers and SSSV (type and measured depth) AL-5 dual pkrs ~ 4665' & 4744', DB pkr ~ 7113' & WD pkr ~ 7463' True Vertical depth 80'TVD 2391'TVD 6922'TVD , TRDP-1A SSSV @ 1806' 12. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Workover', Well History) Daily Report of Well' Operations [~ Copies of Logs and Surveys Run [] 15. I hereby certify that the' foregoing is true and correct to the best of my knowledge Signed Form 10-404 Rev. 12-1-85 Title Associate Engineer (Dani) 5W03/51 Date ~4~ -~1 Submit in Duplicate ARCO Oil and Gas Company ~) Well History- Initial Report- Daily Instn~¢ti~na: Prepare and submit the "Initial Rel~ort" on the first Wednesday after a well is spudded or workover operations are started, Daily work prior tO spudding should be summarized on the form giving inclusive dates only. District ARCO Alaska, Inc. Field KUPARUK RIVER FIELD Auth. or W.O. no. AK2793 ICounty. parish or borough NORTH SLOPE Lease or Unit ADL: 25647 Tiffs WORKOVER 1A-14 Well no. Operator ARCO API: 50-029-20706 rate 01/30/88 IHOur IARCO W.I. 56.0000 Prior status if a W.O. Spudded or W.O. begun ACCEPT Date and depth as of 8:00 a.m. 01/30/88 ( 1 TD: 8285 PB: 7729 (FILl,) SUPV: SC 01/31/88 ( TD: 8285 PB: 7729 (FIL]o) SUPV: SC 02/01/88 ( 3] TD: 8285 PB: 7729 (FILl SUPV: SC 02/02/88 ( 4) TD: 8285 (FIL! PB: 7729 SUPV: SC 02/O3/88 (5) TD: 8285 PB: 7729 (FILl SUPV:SC 02/04/88 ( 6) TD: 8285 PB: 7729 (FILl SUPV:SC PB: 7729 (FILL SUPV: DL Complete record for each day reported NORDIC ]. 0115 HRS POOH & STAND BACK TBG MW:10.2 NaCl MOVE RIG FROM 1Y-13 TO 1A-14. RIG UP TANKS. ND TREE. ACCEPT RIG AT 0115 HRS, 1/30/88. NU AND TEST BOPE.. POOH W/ 3-1/2" TUBING. DAILY:S22,659 CUM:$22,659 ETD:S22,659 EFC:$380,000 POOH W/ DP PULL TUBING. POOH. RIH W/ PACKER PLUG. MW:10.2 NaCl/Br SPOT 6 SXS SAND ON PLUG. DAILY:S31,559 CUM:$54,218 ETD:S54,218 EFC:$380,000 POOH W/ SCRAPER MW:10.2 NaCl/Br SET PACKER PLUG. POOH. RIH W/ MILL. MILL OUT PATCH. RIH. POOH. PU SCRAPER. RIH. POOH. DAILY:S35,044 CUM:$89,262 ETD:S89,262 EFC:$380,000 POH W/SCRAPER MW:10.2 NaCl/Br POH WITH SCRAPER. RIH WITH BAKER RETRIEVE-A-MATIC. ISOLATED LEAK (4712'- 4705'). POOH. RU DRESSER. UNABLE TO GET MAGNALOG BELOW 4705'. RD DRESSER. RIH WITH 7" SCRAPER TO INSURE THAT THE HOLE IS CLEAR. POOH W/SCRAPER. DAILY:S39,733 CUM:$128,995 ETD:S128,995 EFC:$380,000 RIH W/GLOBE BASKET MW:10.2 NaCl/Br POOH WITH SCRAPER. RE-RAN 6-1/8" MILL. MILLED 4696'-4717'. POOH. RAN DRESSER MAGNALOG F/2500'-5024' RAN VERTILOG F/2500'-5024'. RD DRESSER. RIH WITH GLOBE BASKET. DAILY:S44,779 CUM:$173,774 ETD:S173,774 EFC:$380,000 POOH WITH DP MW:10.2 NaCl/Br FINISHED RIH W/REV. BASKET. CLEANED OUT SAND TO 7104' PUMPED SWEEP. NO SAND IN RETURNS. POH WITH BASKET. LEFT CATCHER FINGERS IN THE HOLE. RIH WITH REV. BASKET. CLEANED OUT SAND F/7088'-7095' DROPPED BALL. CLEANED OUT SAND TO 7104'. PUMPED HI-VIS SWEEP. STARTED POH WITH BASKET. DAILY:S30,655 CUM:$204,429 ETD:S204,429 EFC:$380,000 POH WITH DP MW:10.2 NaCl/Br SERVICED RIG. POH WITH BHA. RECOVERED PIECES OF CASING PATCH & 3 CATCHER FINGERS. RIH WITH GLOBE BASKET & REV. SUB. CIRC. WELL. POH WITH BHA. RECOVERED PIECES OF CASING PATCH & 3 CATCHER FINGERS (10 FINGERS STILL IN THE HOLE). RIH WITH SHOE & GLOBE BASKET. CIRCULATE BOTTOMS UP CONVENTIONALLY. REV. CIRCULATE HI-VIS PILL. POH WITH DP. DAILY:S30,800 CUM:$235,229 ETD:S235,229 EFC:$380,000 The above is correct Signature / I Date For form preparation a~'~l distribution, see Procedures Manu,a'l~,/Section 10, Drilling, Pages 86 an4~7. ASSOCIATE ENGINEER History--Interim Daily Well ARCO Oil and Gas Company on Wednesday ot the --;-- ~ ish Di,tri t InD. I .N.0RT, SLOPE ' iLease or Unit -----"'--- Field - ~ ~ ADL: 25647 KUPARUK ...... a d.otl~-- Complete record (or each day ~rkover in p~ogress O~te and oep as of 8:~ a.m. NORDIC 1 02/06/88 ( TD: 8285 PB: 7729 (F SUPV: DL 02/07/88 TD: 8285 (F PB: 7729 sUP V: DL 81 9) MW:10.2 NaCl/Br POH W/3-1/2" DP POH W/BHA. RECOVERED 1 CATCHER FINGER. RIH W/SHOE TO 7104'. MILL 4" ON TOP OF pACKER, pUMPED SWEEP. ?OH. NO RECOVERY IN JB'S. RIH WITH RET. TOOL. ENGAGED PLUG & RELEASED SAM~. ?OH. DAILY:S36,972 CUM:$272,201 ETD:S272,201 EFC:$380,000 MW:10.2 NaCl/Br RIH W/3-1/2" TUBING LD RET. TOOL & pKR PLUG. RIH WITH sEAL ASSY ON 3-1/2" DP. LOCATED INTO PKR & TESTED TO 2500 pSI. ?OH' LDD? & SEAL ASSY. RIH WITH 2-7/8" COMPLETION EQU[PMENT, DUAL pKR ASSY 3-1/2" TUBING. DAiLY:$31i300 CUM:$303,501 ETD:S303,501 EFC:$380,000 '~"~e above is correct ~ Date :Title ~m prepar~'j~' ~t/. ': '- ........ seer Procedures Manual Se on 10, Drilling, pages 86 and 87 ASSOCIATE ENGINEER ARCO Oil and s Company Daily Well History-Final Report Instructions: Prepare and submit the "Final RelN3rt" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Rnl~Ort" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is n(~t required upon completion, report complelion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code District ICounty or Parish State ARCO Alaska, Inc. I NORTH SLOPE AK Field I Lease or Unit I Well no. KUPAROK RIVER I ADL: 25647 lA-14 Auth. or W.O. no. ITM AK2793 I WORKOVER Operator ~M~CO Spudded or W.O. begun ACCE?T Date and depth as of 8:00 a.m. 02/08/88 ( 1~ TD: 8285 PB: 7729 FIL~ SUPV:DL API: 50-029-20706 IA.R.Co. W.I. ~otal number of wells (active or inactive) on thisI ~ost center prior to plugging and 56. 0000 ~bandonment of this well 01/30/88 / 0115 HRS Complete record for each day reposed 'NORDIC 1 RELEASED RIG MW: 0.0 DIESEL FINISHED RIH WITH 3-1/2" & 2-7/8" DUAL COMPL. EQUIP. LONG STRING TAIL @ 7488', SSSV @ 1806', PKRS @ 4665', 4744', 7113', & 7463' SHORT STRING TAIL @ 4757', PKRS @ 4665' & 4744'. SPACED WELL OUT & LAND TUBING. PRESS. TUBING TO 2500 PSI TO SET PKRS. TESTED ANNULUS & DUAL PKRS TO 2500 PSI. TESTED SSSV TO 1500 PSI. SET BPV. ND BOPE. NU TREE & TESTED TO 5000 PSI. DISPLACED WELL WITH DIESEL. PRESSURED ANNULUS TO 3500 PSI. TESTED ORIFICE VALVE TO 1000 PSI. CLEANED PITS. SECURED WELL & RELEASED RIG @ 2100 HRS, 2/7/88. DAILY:S89,477 CUM:$392,978 ETD:S621,409 EFC:$151,569 Old TD New TD PB Depth Released rig Date Kind of rig Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Producing method Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day' Pump size, SPM X length Choke size T,P. C,P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature ¢ L/~/~,/~{,.' ,~ t(,~ ~.~,~?~..,~ [Date ITitle ~4~ -~, A~OCIA~ ENGINEER For form preparation ~1 distribution, see Procedures Manu~Section 10, Drilling, Pages 86 and 87. ' ' ~JiLSTATE OF ALASKA O(~'- ' ALASKA AND GAS CONSERVATION C ,MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-10 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 029-20706 4. Location of well at surface 9. Unit or Lease Name 1169' FSL, 493' F-WL, Sec. 5, TllN, R10E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1068' FSL, 1613' FEL, Sec. 5, TllN, R10E, UM lA-14 At Total Depth 11. Field and Pool 887' FSL, 1311' FEL, Sec. 5, TllN, 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 RKB 100'I ADL 25647 ALK 465 .. 12. Date Spudded 13. DateT.D. Reached 14. Date Comp., Susp. orAband. I15. Water Depth, ifoffshore '16. Nc. of Completions 01/26/82 02/06/82 02/11/82*IIN/A feet MSL 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey [ 20. Depth where SSSV set I 21. Thickness of Permafrost 8285'MD, 6933'TVD 8170'MD, 6838'TVD YES ~ NO [] 1806 feet MD 1650' (approx) 22. Type Electric or Other Logs Run D I L/SP/GR/SFL/FDC/CNL/Cal, Gyro/CCL, CBL/VDL/CCL/GR, CET, Spinner/Temp/GR/CCL, Magnal og, Verti 1 og 23. CASING, LINER AND CEMENTING RECORD ............... SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED lb" 65.0# H-40 Surf 80' 24- 200 sx PF 10-3/4" 45.5# K-55 SUrf 2391' 13'1/2" 950 sx Fondu & 250 sx AS II 7" 26.0# K-55 Surf 8263' 8-3/4" 1225 sx Class G & 250 sx AS II , , 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) Perforated w/4. spf 3-1/2"/2-7/8" 7488' 4~65'~4744'~7113' & 7463' 7280 ' -7334 'MD 6136 '-6177 'TVD 2-7/8" 4757 ' 4665 ' 4744 ' 7339'-7347'MD 6180 ' -6186 'TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7353 '-7359'MD 6191 ' -6195 'TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7379 ' -7402 'MD 6210 ' -6227 'TVD Leak ~ 4705 ' 250 sx C1 ass G , , 7572 ' -7584 'MD 6357 '-6367 'T~VD 7594 ' -7626~ MD 6374 ' -6399' TVD 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-M'CF W'ATER-BBL cHOKE SIZE I GAS-OIL RATIO TEST PERIOD e I OIL-BBL ,. GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Flow Tubing Casing Pressure CALCULATED Press. 24-HOUR RATE e 28. CORE DATA r) i~ r i~ I ~ ! r__ r,, ... Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Su~l~iL~(~,e ~J~il~s.V II- L~I None Naska Oil & Gas Cons. Commission A~ch0rage *Note: Tubing was pulled & well recompleted 12/9/85. Workovers performed 10/30/87 & 2/7/88. c-.-- ~n ~n~ WC~/67 :DAN I (~llJ~mit in Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top upper 5and 7680' 6~1' N/A Base Kuparuk .. 7696' 6~5~, 3t. LIST OF ATTACHMENTS Addendum (dated 12/29/87) , 3:2. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~,¢,//~~ .~..~ Title Associate Engineer Date //] INSTRUCTIONS General' This form is designed for submitting a complete and correct welt completion report and Icg on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injec.tionj air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item '5: Indicate which elevation is used as reference (where not Otherwise shown) for depth measurements given in other spaces on this form and in any attachments. , Item 16 and: 24: If this well is completed for separate production from more 'than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interVal to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (G L) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- 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. Form 10-407 ADDENDUM WELL: 1A-14 10/31/87 MIRU Schlumberger. Tested lubricator to 2000 psi. RIH w/FBS/ temp/GR/CCL. Tie into Schlumberger CET Dated 10/29/81; correlated to CET dated 12/5/85; correlated to CBL dated 2/8/82. Made one pass f/_+4800' to 4600' at 80 fpm and one pass f/+4800'- +4600' at 120 fpm to estimated base line without pump. Located casing patch at 4693' to 4713' Made one pass from _+4800' to · +4600' at 80 fpm while injecti'n§ 1/2 bpm at 1800 psi and one pass from +4800' to +4600' at 120 fpm while injecting 1/2 bpm. Pressure increased to 2000 psi. Spinner and temp surveys show all fluid movement at very bottom of patch. Injected total of 12 bbls 10.2 ppg brine. POH w/spinner. RD. Freeze protected well w/lO bbls diesel. Secured well and moved off. RECEIVED Oil & Gas Cons. Commission o I'-- --..... O] o -%. ~ ~ ~ CSG CSG Anchorage RECEIVED- ~o ,.,ac 25.~( ) 20 ,a,AC: 25.412(c)~ 2O AAC 25.252(d)-'~ FEB O 8 1988 0 ~ ~T ~ em~. BommLddotl: ' ~-t.9 ?~v '" STATE OF ALASKA .,, _,SION A ,5 OIL AND GAS CONSERVATION C k~. REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate [] Plugging ~ Perforate L~ Pull tubing Alter Casing ~ Other [~ WORKOVER 2. Name of Operator ARCO Alaska, inc. 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1169' FSL, 493' FWL, Sec. 5, TllN, R10E, UM At top of productive interval 1068' FSL, 1613' FEL, Sec. 5, T11N, RIOE, UM At effective depth 922' FSL, 1365' FEL, Sec. 5, TllN, R10E, UM At total depth 887' FSL~ 1311' FEL~ Sec. 5~ TllN~ R10E~ UM 11. Present well condition summary Total depth: measured 8285 'MD true vertical 6933 'TVD Effective depth: measu red 8170 ' MD true vertical 6838 'TVD 5. Datum elevation (DF or KB) RKB 100' 6. U. nit or.Pr..operty, pa..me r~uparuK ~lver unl~; 7. Well number 1A-14 8. Approval number 7-780 9. APl number 50-- 029-20706 10. PoOl Kuparuk River 0ii Pool feet Plugs (measured) None feet feet Junk (measured) Fill (~ 7729' feet Casing Length Size Cemented Measured depth Conductor 80' ' 16" 200 sx PF 80 'MD Surface 2360' 10-3/4" 950 sx Fondu & 2391 'MD 250 sx AS II Producti on 8234' 7" 1225 sx C1 ass G & 8263'MD 250 sx AS II Feet True Vertical depth 80 'TVD 2391 'TVD 6922 ' TVD Perforation depth: measured 7280 ' -7334 'MD, 7339 ~-7347 'MD, 7353 ' -7359 'MD, 7379 ' -7402 ' MD, 7572 ' -7584 'MD, 7594 ' -7626 'MD true vertical 6136'-6177'TVD, 6180 '-6186 'TVD, 6191'-6195 'TVD, 6210'-6227'TVD, 6357'-6367'TVD, 6374'-6399'TVD Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) Otis WD pkr @ 7463', Baker DB pkr ~ 7113', Camco TRDP-1A SSSV (~ 1966' DEC .]. 4 J~7 12. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure ~,laska 0il & Gas Cons, C0mmissi0r~ ~ch0rage 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Workover Wel 1 History) Daily Report of Well Operations~ Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge . Signed (~)~ ~/.,~~ Title Associate Engineer Form 10-404 Rev. 12-1-85 ~ (Dani) 5W03/11 Date Submit in Duplicate 10129187 7" @ 8263':: 7729' Fill, RII{ w/cs8 patch 10.2 ppg NaC1/NaBr Tst csg; leak @ 4685', leak bet 4707' & 4712', POOH. RIH w/JB & scrpr to 7473', stab into WD, circ, POOH. RIH w/S/L to 7200', POOH. PU csg patch & RIH. 7" @ 8263' 7729' Fill, P~ep to tst ann 10.2 ppg NaCI/NaBr RIH w/cs.g pat.ch& set same w/center @ 4709', POH. TIH w/compl assy, set pkr. Tst tbg; OK. Wait on csg patch to set prior to ts~'g amm. 7" @ 8263" 7729' Filf,'~IH w/DP 10.2 pp$ NaCl/NaBr Agt: to tat patch; no tst, POH. RU Schi, rn CET f/4985'-4550', RD Schl. RIH w/inflatable pkr, set @ 4802', tst csg below 4800-!-¥to 250_0.~si; OK. DEC; I 0ii & Gas Cons. Anchorage ARCO Oil and Gas Company Daily Well History-Final Report IflltlllCli~el: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Flail Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Flail Report" form may be used for reporting the entire operation if sPaCe is available. District ICounty or Parish I Field ILease or Unit K. upatmk River I'Title Auth. or W.O. no. I AFE AK2793 North Slope Borough IAccounting coat center code State Alaska I Well no. ADL 25646 lA-14 Recompletion AP1 50-029-20706 Operator IA.R.Co. W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun IDate Workover I 10/25/87 Date and depth Complete record for each day reported as of 8:00 a.m. Iotal number of wells (active or inactive) on this. est center prior to plugging and / bandonment of this well our IPrior status if a W.O. I 0200 hrs. 7" @ 8263' 7729' Fill, RE 10.2 ppg NaC1/NaBr RU & rn 146 its, 3½" BTC tbg & ind. 7463'. ND BOPE. NU & tst tree to 5000 psi. RE@ 2300 hfs, 10/30/87. DB pkr @ 7113', WD pkr @ Freeze protect well. New TD Old TD Released rig 2300 hrs. Date PB Depth 7729' Fill K nd of rig Rotary :1.0/31/87 10/30/87 Classifications (o11, gas, etc.) Oil Producing method Flowing Type completion (single, dual, etc.) single Official reservoir name(s) Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day . Pump size, SPM X length Choke size T.P. C.P. Water % GOR ~ravity Allowable Effective date corrected ... The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent ARCO Alaska, I Post Office BOx 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: November 16, 1987 Transmittal # 7010 RE~JRN 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. lA-14 Cement Evaluation Log 10-29-87 4550-5000 Receipt Acknowledged: DISTRIBUTION: 0il & Gas Cons. C0mmissior~ Anchorage NSK Drilling State of Alaska(+sepia~ Vault(film) ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany 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 D I~rforate~ ~ Other~.~ 2. Name of Operator 5. Datum elevation(DF or KB) ARCO Alaska, inc. RKB 100' feet 3. Address 6. UnitorProperty name P. O. Box 100360 Anchorage, AK 99510-0360 Kuparuk River Unit 4. Location of well at surface 1169' FSL, 493' FWL, Sec. 5, TllN, RIOE, UM At top of productive interval 1068' FSL, 1613' FEL, Sec. 5, TllN, RIOE, UM At effective depth 922' FSL, 1365' FEL, Sec. 5, TllN, RIOE, UM At total depth 887' FSL, 1311' FEL, Sec. 5, TllN, RIOE, UN 11. Present well condition summary Total depth: measured true vertical 7. Well number 1A-14 8. Permit number 82-10 9. APl number 50m 029-20706 10. Pool Kuparuk River 0il 8285 'MD feet Plugs (measured) None 6933 'TVD feet Pool Effective depth: measured 81 70 'MD feet Junk (measured) None true vertical 6838 'TVD feet Casing Length Size Cemented Measured depth True Vertical depth Conductor 80' 16" 200 sx PF 80 'MD 80'TVD Surface 2360' 10-3/4" 950 sx Fondu & 2391'MD 2391 'TVD 250 sx AS II Production 8234' 7" 1225 sx Class G & 8263'MD 6922'TVD 250 sx AS. II See attached sheet Perforation depth: measured R [ [ E I V E D true vertical OCT 0 8 1987 Tubing (size, grade and measured depth) 3 - 1 / 2" 9 2 Cf / f t J - 55 B T C t u b i n g w / t a i 1 ~ 7~~t Oil & Gas Cons. C0mmissi0ri ' ' ' ' Anchorage Packers and SSSV fCy~P6e3a~n~d _measured depth) tis WD pkr ~ Otis RRH pkr ~ 7214', Camco TRDP-1A SSSV ~ 1966' 12.Attachments Description summary of proposal ~ Detailed operations program [] BOP sketch 13. Estimated date for commencing operation October 18, 1987 14. If proposal was verbally approved Name of appr°ver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed &~k~.~jtt).CA., TitleAssoci ate Enqin¢¢r ~ Commission Use Only (JG) 5A2/117 Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearance I Approved by i~!'i;(:~ ;'~:,"i~ ~!¢~[~ ..... , / 0,~.,~_.,.?_:,.:,,~:."~ by order of ~:~,~[ ~., Commissioner commission Date /~ -~ .~ ~ Form 10-403 Rev 12-1-85 Submit in triplicate 1A-14 APPLICATION FOR SUNDRY APPROVALS Item 11. Perforation Intervals MD TVD 7280 -7334 7339 -7347 7353 -7359 7379 -7402 7572 -7584 7594 -7626 6136 -6177 6180 -6186 6191 -6195 6210 -6227 6357 -6367 6374 -6399 RECEIVEI) OCT o ~ 1:.~.~ 7 Alaska Oil & Gas Cons. Commission Anchorage SA2/117a lA-14 W/O Procedure Pre-Rig Operations 1. RU slickline. Set blanking plug in 'D' nipple. 2. Make sure all 1" GLM's have dt~mmy set and AVA nipple is blanked off. Pull the valve from the 1½" GLM above retrievable packer. 3. Set BPV. Rig Operations 1. MIRU Nordic Rig il. 2. Pull BPV. 3. Circulate kill weight fluid down tubing taking returns through annulus. 4. Set BPV. 5. ND tree. NU and test BOPE. 6.. ~ull_tubi~ string and stand back. 7. RIH with packer retrieving tool and release packer. CBU. POOH and LD packer. 8. Pinpoint hole in 7" casing and run c~across hole. Wait 24 hrs and pressure test patch. 9. Run steel blast joints and 3 - 2-7/8" x 1" GLMs below a Baker 'DB' packer in hole on DP. Stab into bottom packer and set 'DB' packer. LDDP. Run 3½" completion from 'DB' packer to surface. 10. ND BOPE. NU and test tree. 11. Displace well to diesel. 12. Set BPV. Secure well. 13. PR. APAD/1A-14e ih 7- 1 / 16" 5000 PSI BOP STACK ANNULAR PREVENTER § PIPE RAHS 4 BLIND RAHS 5 TUBIN6 HEAD 2 1. 16" CONDUCTOR SWAGED TO 10-3/4" 2. 11"-3000 PSI STARTING HEAD 3. 11 "-3000 PSI X 7-1 / 16"-5000 PSI TUBING HEAD 4. 7-1/16" - 5000 PSI PIPE RAMS 5. 7-1 / 16" - $000 PSI BLIND RAMS 6. 7-1 / 16" - 5000 PSI ANNULAR ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS $000 PSI WITH 1500 PSi DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL.SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSi AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 1800 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE PIPE RAMS. 7. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH ~5000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. g, OPEN PIPE RAMS. BACKOFF RUNNING dOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. JG dULY 26,'1986 (NORDIC RIG 10-3/4") ARCO Alaska, In~ Post Offic~ -,ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 6, 1987 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99501 Commission Dear Mr. Chatterton' Attached in triplicate is an intent notice on Kuparuk Well 1A-14 listed below: Well Action 1A-14 Failed MIT Anticipated Start Date June 29, 1987 as If you have any questions, please Sincerely, Senior Operations Engineer GBS:pg:O094 Attachments cc:~ File KOE1.4-9 call me at 265-6840. RECEIVED,, JUL 0 ? ]987 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ALA ., OIL AND GAS CONSERVATION CO .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. Anchoraae. AK 99510 4. Location of well at surface 1169' FSL. 493' FWL, Sec, 5 T11N R10E UM At top of procluctive interval ' ' ' 1197' FSL, 1862' FEL, Sec, 5, T11N, RIOE, UM At effective depth 887' FSL, 1311' FEL, Sec, 5, T11N, RIOE, UM At total depth 887' FSL, 1311' FEL. Sec. 5. T11N. RIOE. UM 11. Present well condition summary Total depth: measured 8285' MD feet true vertical 6933' TVD feet 5. Datum elevation (DF or KB) RKB 93 6. Unit or Property name Kuparuk River llnit 7. Well number 1A-14 8. Permit number Permit #82-10 9. APl number 50-- 029-20706 10. Pool Kunar~k Riw~ (lil Pnnl ! Plugs (measured)8170' R E [ E i V E D Effective depth: measured 8170' MD feet true vertical 6839' TVD feet Casing Length Size Structural Conductor 80' 16" Surface 2391' 10-3/4" XXX~]~q~e~te Production 8263 ' 7" xxxk- xxxx Perforation depth: measured Junk (measured) None Cemented Measured depth feet JUL 0 ? 1987 Alaska 0il & Gas Cons. Commission Anl3~{~rtical depth 80' TVD 2391' TVD 200 SX PF 80' MD 950 SX FONDN & 2391' MD 250 SX ASII 1225 SX Class G 8263' MD 6915' TVD 7280'-7334' 7339'-7347' 7353'-7359' 7379'-7402' MD 7572' -7584' 7594 '-7626' true vertical6137,_6176, 6181 6358'-6367' 6375 Tubing (size, grade and measured depth) 3½", J-55, ~3 7488' MD Packers and SSSV (type and measured depth) '-6186' 6192'-6196' 6210'-6228' TVD '-6400' CAMCO TRDP-1A S.~SV ra lqE7' MD; Otis ~RH Packer m 79n~, Mn. n+~ hm D~,.~,.,.. r~ -~m==, ~n 12.Attachments Description summary of proposal [] De~'ail;9~ ....operahons"'' ........ program I~'"~'~15 s~et'c~"'~ "'" ~)~t~ot4¢~.~ Sand-only water injection with C. Sand~ ~hut-~n flue tn_ ~eak in 7" casing above 13. i~'ti~,ted date for commencing operation June 29, 1987 14. If proposal was verbally approved Subsequent Work Re]L3o~ted on Name of approver Date approved 15. I hereby certify that the foregoing is true and~orrect to the best of my knowledge Signed ./~ ~ /~ ~~~~ Title Sr. Operations Engineer ~/ Commission Use Only Conditions of approval Approved by Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearanceI , .~,. !~ · by order of Date 7/1/87 Form 10-403 Rev 12-1-85 Commissioner the commission Date 7~--~ ARCO Alaska, Inc.~ [~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 27, 1987 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Attached in triplicate is an intent notice on Kuparuk Well 1A-14 as 1 i s ted bel ow: Well Action 1A-14 Failed MIT Anticipated Start Date April 15, 1987 If you have any questions, please call me at 265-6840. Sincerely, G. B. ~Smal lwood Senior Operations Engineer GBS-pg-O087 Attachments cc' File KOE1.4-9 E E VED Alaska Oil & Gas ~'~.."-",,u~,o. 6cram[ss[on ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ALAS OIL AND GAS CONSERVATION COM .~ION 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 /~1 asKa, znc 3. Address PO Box 100360, Anchorage, AK 99510 4. Location of well at surface 1169' FSL, 493' FNL, Sec. 5, T11N, R10E, UM At top of productive interval 1197' FSL, 1862' FEL, Sec. 5, T11N, RIOE, UM A~qctr§L~,ep][~11,__,,_ :___ ~_ .L FEL, Sec. 5, T11N, R10E, LIN At total depth 887' FSL, 1311' FEL, Sec. 5, T11N, RIOE, UN 11. Present well condition summary Total depth: measured 8285' MD feet true vertical 6933' TVD feet Effective depth: measured 8170' MD feet true vertical 6839' TVD feet Casing Length Size Structural Conductor 80' 16" Surface 2391' 10-3/4" Production 8263 ' 7" xxxkk'wxxxxx Plugs (measured)8170 ' R~,~D~jum elevation (DF or KB) feet 6. Unit or Property name Kuparuk River Unit 7. Well number 1A-14 8. Permit number Permit #82-10 9. APl number 50-- 029-20706 10. Pool Kuparuk River Oil Pool Junk (measured) None Cemented Measured depth True Vertical depth 80' TVD 2391' TVD 200 SX PF 80' MD 950 SX FONDN & 2391' MD 250 SX ASII 1225 SX Class G 8263' MD 6915' TVD Perforation depth: measured 7280'-7334' 7339'-7347' 7353'-7359' 7379'-7402' MD 7572'-7584' 7594'-7626' true vertical6137,_6176, 6181'-6186' 6192'-6196' 6210'-6228' TVD 6358'-6367' 6375'-6400' Tubing (size, grade and measured depth) 3½" 0-55 @ 7488' MD Packers and SSSV (type and measured depth) CAMCO TRDP-1A SSSV @ 1957' MD; Otis RRH Packer @ 7205' MD: Oti5 WD packer @ 7455' 12.Attachments Description summary of proposal ~ Detailed operations program [] BOP sketch [] Continue A & C Sand Water Injection with Restricted Casing Pressure 13. Estimated date for commencing operation April 15, 1987 MD 14. If proposal was verbally approved Subsequent Work Report:ecl on Name of approver Lonnie Smith Date approved 4/15/87 15. I hereby certify that the foregoing is true~nd correct to the best of my knowledge .... Signed ./<~',~u,v,t~ ,~ ~'~.'~.~~ Title Sr. Operat. ions Engineer (/ Commission Use Only Date 4/21/87 Conditions of approval Notify commission so representative may witnes.s I Approval No. [] Plug integrity [] BOP Test [] Location clearance I Approved Approved by Commissioner 'i:orm 10-403 Rev 12-1-85 -'"'-' (" 7 ~ ,/ the commission Dat ~ tr~pl~ate ATTACHMENT FOR SUNDRY APPROVAL APPLICATION WATER INJECTION WELL 1A-14 CONTINUE A&C SAND INJECTION WITH RESTRICTED CASING PRESSURE (Follow-up to Sundry Approval No. 7-207, given 4/01/87) SUMMARY AND PROPOSAL A pressure test of the 7" casing of water injection well 1A-14 during the week of April 12, 1987, successfully determined that the casing maintained pressure integrity through the duration of the test. Maximum pressures and rates during the test were as follows: Surface Casing Pressure' 2245 psi Surface Tubing Injection Pressure' 1730 psi Injection Rate at Max. Pressure' 1475 BWIPD Due to the communication across the packer above the C Sands, injection into the C Sands was discontinued until this pressure test of the casing could be performed and approval to continue C Sand injection was received from the AOGCC. AFTER THE COMPLETION OF THE PRESSURE TEST, VERBAL APPROVAL WAS GIVEN BY LONNIE SMITH, AOGCC, ON 4/15/87, TO INJECT INTO THE C SANDS SUBJECT TO THE FOLLOWING PROPOSED GUIDELINES: **** 1. SURFACE CASING PRESSURE LIMITED TO 210fl psi. **** **** THIS CORRESPONDS TO A WHIP OF 1575 psi. **** 2. PRESSURE TEST COMPARISONS REQUIRED EVERY SIX MONTHS TO **** ENSURE-THAT CASING INTEGRITY IS MAINTAINED. WITH THE **** C SANDS OPEN, PRESSURE COMMUNICATION EXISTS BETWEEN THE **** TUBING AND CASING BECAUSE OF COMMUNICATION ACROSS THE **** TOP PACKER, THEREFORE, A TUBING AND CASING PRESSURE **** DIFFERENCE OF 520 psi INDICATES THAT THE CASING DOES **** NOT LEAK AND THE INTEGRITY OF THE CASING IS YERI.-~IED. **** **** 3. IF THE TUBING AND CASING PRESSURE DIFFERENCE FALLS **** **** BELOW 520 psi, THE CASING HAS STARTED LEAKING AND THE **** **** C SANDS MUST BE SHUT IN AND THE AOGCC NOTIFIED. **** BACKGROUND INFORMATION /.",:~i::'::; '> ? !9o7 Anchorag~ The pressure test of 1A-14 was necessary to determine if C Sand injection could continue safely without the need for a well workover, and to obtain AOGCC approval to continue C Sand injection. In February, 1987, it was determined that the packer above the C Sands was leaking and causing pressure communication between the C Sands and the 7" casing. A leak in the casing was found during the December, 1985, conversion of the well to a selective single completion. The casing leak, at 4255' TVD (4705' MD), was cement squeezed twice. During pressure tests.after cementing, the 7" casing pressure bled off each time to an equivalent pressure of 3690 psi at the depth of the leak. The surface pressure associated with 3690 psi at 42551TVD was 1500 psi. Since the casing was full of 9.9 lb/gal mud, the pressure at the depth of the top packer at 6094' TVD was 4630 psi. To comply with Area Injection Order No. 2 - Rule 6, the pressure at the packer depth must be at least 4357 psi (Rule 6 requires that the casing test pressure must impose a pressure difference across the casing of psi/ft at the vertical depth of the packer; assume a ~e~~w~-I J~ O.25 gradient of 0.465 psi/ft), thus, the well complied with Rule 6. Because of the existence of the packer leak and the possibility of a casing leak at high pressures, the C Sands were shut in until this pressure test was performed to establish casing integrity. TEST PROCEDURES 1. To begin the test, the C Sands were opened, the A Sands were isolated by placing a standing valve in the 'D' nipple, and a dummy valve was pulled from the GLM above the top packer, establishing full communication between the tubing, casing, and C Sands. 2. The initial pressure difference of 400 psi between the tubing and casing was used to calculate a water/diesel interface in the casing annulus of 4598'TVD (5175' MD). It should be noted that this depth is below the depth of the suspected casing leak, indicating that it is not likely that any large amount of fluid had leaked from the casing. At least 30 barrels of the 52 barrels of diesel that had been displaced from the casing was bled at the surface to control the casing pressure. o Diesel was pumped into the casing annulus to completely fill i~, with diesel. The pressure difference between the tubing and casing stabilized at about 525 psi, indicating that the casing was, indeed, full of diesel to the depth of the open mandrel 6041' TVD while the tubing was full of water. The stabilized surface tubing and casing pressures were 1310 and 1835 respectively. 4. Injection into the C Sands was initiated at 1350 psi and 350 BWIPD, then was increased in increments of 25-50 psi while the casing and tubing pressures were monitored. The pressures were stepped up slowly over the next thirty-six hours until tubing and casing surface pressures of 1730 psi and 2245 psi were recorded. The pressure difference of 515 psi plus a tubing friction correction of 10 psi indicates that the casing annulus was still full of diesel and, therefore, maintained pressure integrity. For the week after the test was completed, injection continued at tubing and casing pressures of about 1550 and 2070 psi, respectively, INDICATING THAT THE CASING PRESSURE INTEGRITY HAS HELD. i P0$5'IBLE' "7"' ~' C.$~,-LEAK ~ - c SA' D ~e= % ~0 ?s ; L~V~L l/~ · OLr~l = DIESEL D I E'~ t~ L.. · 'T[I S IflL ~ Pt~131o I~LL1/D I~ 0, ~ ~,.0' SlOE /::'c= I$i~5 CSO, FLtl LO IS DI6$~L 1=Io. lC'T1 o ~ Lo~ D6E, .re I,N,J~ 6Lmm. ?u '~ 37q7 .355 DID NOT LEA14, A SAND ARCO Alaska, Inc. /~ Post Office Bt~ .00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 24, 1987 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 · Dear Mr. Chatterton' Attached in triplicate are intent notices on Kuparuk Wells 1A-14, 3N-3, 3N-12 and 3N-13: Well Action ~ Fa i 1 ed Test 3N-3 Conversion 3N-12 Conversion 3N-13 Conversion Anticipated Start Date March 30, 1987 April 1, 1987 April 1, 1987 April 1, 1987 If you have any questions, please call me at 265-6840. Sincerely, ,.r -x,. G B. Smallwood Senior Operations Engineer GBS: pg' 0081 Attachments cc' File KOE1.4-9 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfleldCompany ALA~ ,OIL AND GAS CONSERVATION CO ..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 J~ 2. Name of Operator ARCO Alaska, Inc 3. Address PO Box 100360. Anchoraae. AK 99510 4. Location of well at surface 1169' FSL, 493' FWL. Sec, 5 T11&I R10E UM At top of prorductive interv,~l ' ' ' 5. Datum elevation (DF or KB) RKB 93 6. Unit or Property name Kuparuk RivP_r Unit 7. Well number 1A-14 8. Permit number 1197' FSL, 1862' At effective depth 887' FSL, 1311' FEL, Sec. 5, T11N, RIOE, UM FEL, Sec. 5, T11N, RIOE, UM At total depth 887' FSL. 1311' 11. Present well condition summary Total depth: measured 8285' MD true vertical6933, TVD FEL. Sec. 5. T11N. RIOE. UM feet feet Permit #82-10 9. APl number 50-- 029-20706 10. Pool Kunaruk River Oil Pnnl Plugs (measured8170, ~ Effective depth: Casing Structural Conductor Surface XXXX~(~ex00~i~te Production xxx~'xxxx Perforation depth: measured 8170 ' feet true vertica168~9 MD ' TVD feet Length Size Junk (measured)None Cemented Measured depth feet · True.Vertical depth 80' 16" 200 SX PF 80' MD 80' TVD 2391' 10-3/4" 950 SX FONDN & 2391' MD 2391' TVD 250 SX AS II 8263' 7" 1225 SX Class G 8263' MD 6915' TVD measured 7280'-7334', 7339'-7347', 7353'-7359', 7379'-7402' MD 7572'-7584', 7594'-7626' true vertical6137,_6176, , 6181'-6186', 6192'-6196', 6210'-6228' TVD 6358'-6367', 6375'-6400' Tubing (size, grade and measured depth) 3½" J-55 @ 7488' MD Packers and SSSV (type and measured depth) CAMCO TRDP-1A .(:;~.(;;V ra lqE7' MI3-_ 13~--~c RPI-I p=~-t,,,~, ra 79n~;, Mn. n+4,. un D~,b~,v, t~ -//I!::;:~1 Mn 12.Attachments Description surnr~a~y- ~- p~l~)s~l-J~'-'De~ailed ...... operahons~ ..... I~r~r~ IZl'~"l~ s~eic~h" ~ Continue A Sand Water In.iection and Prncmpd w~fh ~q~nn 13. Estimated date for commencing operation March 30, 1987 14. If proposal was verbally approved Name of approver Lonnie Smi-th Subsequent Work Reported on Form No. ~ Dated ff_~_~7~' Date approved 3/9/87 15. I hereby certi!y that the..×/ ,- .-f°r,-eg°ing is true and correct to the best of my knowledge ~ :, ~ Sr. Operations Engineer Si-ned Title Date 3/24/8,7 Conditions of approval Approved b~l .,,, , r ,,~, .... ,,~ Form 10-403 Re~?12!1t!~![ [~' ,~,,m' ; Commission Use Only Notify commission so representative may witness I Approval No. · [] Plug integrity [] BOP Test [] Location clearance or ero, Submit in triplicate ATTACHMENT FOR SUNDRY APPROVAL APPLICATION WELL 1A-14 DESCRIPTION SUMMARY OF PROPOSAL Injection Well 1A-14 was an A Sand only injector from the time of its workover conversion in December, 1985, until January 20, 1987, when the C Sands were shut-in on February 22, 1987. The well is currently injecting in the A Sand only per the verbal approval of Lonnie Smith, AOGCC. At the time the well was worked over in December, 1985, a leak was isolated at 4705' MD in the 7" casing. Because of this leak, ARCO maintained a casing pressure well below the pressure at which the casing tested per Rule 6. However, due to the recent discovery of the packer leak, ARCO intends to determine whether the casing leak at 4705' MD can still maintain pressure integrity. This determination will be done hydraulically with full communication between tubing and casing while injecting into the A Sands only. At the completion of the test, ARCO may solicit AOGCC approval to open the C Sands under certain restrictions warranted by the results of the test. JAS:pg:O019 (MF) ARCO Alaska. I~ Post Office Box 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 Transmitted herewith are the following items. return one signed copy of this transmittal. Final Prints: Schl: CET or CBL Logs: lA-7 12-03.85 Run #3 7585-8532 lA-14 .12-05-85 Run #1 4550-4850 1H-4 12-26-85 Run #2 6893-7466 1H-8 12-08-86 Run #3 7875-8368 1H-8 12-09-86 Run #4 7850-8450 lQ-9 01-28.85 Run #1 4898-6534 lQ-13 06-02-85 Run #1 5300-7621 2C-16 02-19-85 Run #1 7200-8294 2E-9 01-14-85. Run #1 6780-8052 2E-15 01-12-85 Run #1 3350-6874 2E-16 01-12-85 Run #1 4840-7578 2H-10 12-05-85 Run #1 6500-7863 3A-7 11-04-85 Run #1 5726-7164 3A-11 12-15-85 Run #1 5796-7206 3A-12 12-16-85 Run #1 6426-7768 3A-13 12-29-85 Run #2 5644-7482 3A-14 12-29-85 Run #2 5462-7744 3C-13' 10-30-85 Run #1 7075-9474 3F-5 11-13-85 Run #1 6947-8647 3F-6 11-13-85 Run #1 4600-7570 3F-9 12-19-85 Run #1 6188-7490 3J-5 12-22-85 Run #1 7000-8636 DATE 09-15-86 TRANSMITTAL ~ 5761 Please acknowledge receipt and One * of each Receipt Acknowledged: s~o' o~ AK*~ Vault*films ~ NSK Files*bl ARCO Alaska. Inc. ,$ · Sul~s,climry of AtilrtticRichfieldComl=afly Mr. C..V. Chat*~rton May 27, 1986 Page 2 KUPARUK ,,,v ~ f RIVER UNIT INJECTION'LOGS INJECTION Well Number Date of Initial Injection Date of Injection Profile lA-7 lA-9 lA-11 lA-12 1A-13 lA-15 lA-16 3/21/83 3/25/83 3/1/83 3/22/83 3/7/83 3/21/83 3/1/83 3/6/83 2/4/83 10/17/83 2/22/83 4/11/83 3/1/83 3/18/83 3/1/83 3/24/83 Well Number Date of Initial InjectiOn Date of Injection Profile 1E-lA 1E-4 -. 1E-9 IE-13 1E-14 1E-I6 · 1E- 19. 1E-21 1E-23 1E.27 1 E- 30 Wel 1 Number tF-10 1F-',ll 1F-13 IF-15 -Well NUmber ~ 1G-3 1G-6 1G-9 1G-14 1G-16 Date 5/8/83 5/17/83 4/17/83 5/19/83 2/16/83 10/4/83 2/8/83 3/7/83 2/10/83 8/2/83 2/11/83 3/15/83 4/29/83 5/11/83 5/2/83 10/4/83 5/3/83 4/5/84 2/11/83 10/7/83 2/14/83 10/7/83 Of Initial Injection Date of Injection Profile 8/13/84 10/30/84 8/12/84 9/24/84 8/I6/84 9/25/84 8/16/84 9/26/84 Date of Initial Injection Date of Injeotion Profile 10/25/85 12/20/85 7/28/84 9/23/84 9/15/84 9/23/84 8/24/84 9/22/84 8/24/84 9/22/84 OF ALASKA ALASKA OIL AND GAS CONSERVATION C MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL I-1 COMPLETED WELL E3X OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 82-10 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20706 1169' FSL, 493' FWL, Sec.5, TllN, RIOE, UM 4. Location of Well Surface: 5. Elevation in feet (indicate KB, DF, etc.) RKB 100' 6. Lease Designation and Serial No. ADL 25647 ALK 265 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1A-14 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) 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.) (Submit in Duplicate) [] Altering Casing [] [] Abandonment [] 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 @ 2030 hfs, 11/29/85. Killed well. ND tree. NU BOPE & tstd - ok. Pulled 3-1/2" tubing. Milled and recovered pkr. Tagged top of Vann gun fish (~ 7739'. Ran CET, Set bridge plug (~ 7200'. Tested csg to 3200 psi - ok. Staged in hole looking for leak. RIH and set pkr @ 7170' (above bridge plug). Found leak ~ 4705'DPM. Retrieved bridge plug. Ran CET f/4850' - 4550'. Set cmt retainer (~ 4760'. Pumped and squeezed 150 sx Class G cmt. Left 5 bbls cmt in csg (est. T0C (~ 4575'). Drld cmt to 4760' (top of retainer Tstd csg to 2000 psi - started pumping away ~ 1/2 BPM, 1700 psi. Set Champ pkr ~ 4450'; pumped & squeezed 1 sx Class G cmt. Drld to 4705'; tstd csg to 1500 psi - ok. Drld cmt to retainer. Tstd csg to 1500 psi - ok Drld cmt retainer. Set "WD" pkr ~ 7455'WLM. Ran 3-1/2" completion assembly w/tail ~ 7488', pkrs ~ 7463' & 7214' & SSSV ~ 1966'. Set BPV. ND BOPE. NU tree & tstd to 5000 psi - ok. Disp well w/diesel. Secured we1 & released rig ~ 2230 hrs, 12/09/85. RECEIVED Alaska Oil & Gas C~,s. Commission 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. .gl The space belo~or Commission use Date Conditions of APproval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 (JG) SN/146 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ATTACHMENT I I KUPARUK RIVER UNIT Production Logs FEBRUARY 19, 1986 Dril 1 Site Well No. Log Date 1A-4 7/6/83 IA-5 10/29/83 1A-7 2/8/82 5/7/82 1A-9 1/25/82 3/23/83 1A-11 1/19/83 3/21/83 1A-12 3/8/82 '~l~:14"~ 4/1 / 82 1A-15 6/5/82 1A-16A 5/11/82 6/8/82 lA Drill Site Well No. Log Date lB 1B-1 12/26/81 1B,2 6/25/81 1B-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 Dri 11 Si te 1C Well No. Log Date lC-1 5/9/81 lC-2 5/8/81 lC-3 7/13/81 1C-4 11/8/81 3/9/81 IC-5 2/26/81 1C-6 :' 11/30/81 1C-7 5/19/81 1C-8 ' 5/21/8t Drill Site 10 Well No. Log Date 1D-1 · 1/80 5/23/83 ID-3 8/5/80 ID-4 7/3'0/80 8/13/80 1D-5 6/11/81 1D-6 6/9/81 1D-7 6/8/81 (WS-S) 511017':8 Attachment Page 2 Drill Site 1H Well No. Log Date 1H-3 8/16/82 1H-4 8/13/82 1H-6 6/21/82 1H-7 7/20/82 1H-8 7/22/82 Drill Site Well No. Log Date lQ ~ Q t2/1785! Drill Site Well No. Log 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 8/4/8O 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 Well No. Log Date 1G 1G-1 1G-2 1G-3 1G-4 1G-5 1G-7 1G-8 Drill Site Well No. Log Date 9/7/82 9/25/82 9/28/82 12/8/84 10/13/82 11/12/82 3/!2/83 1F Alaska Oil & Gas Cons. Anchorage 1F-1 2/19/83 1F-2 2/3/83 1F-3 1/31/83 1F-4 5/29/83 1F-5 10/25/82 1F-6 !0/28/82 1F-7 11/19/82 5/7/83 Attachment · Page 3 Drill Site 1Y Wel 1 NO._ Log Date. _ 1Y-1 6/6/83 10/21/83 1Y-2 6/10/83 3/4/84 6/18/83 1Y-5 6/29/83 1Y-6 6/27/83 1Y-8 6/22/83 1Y-9 6/20/83 ~It'~"1~ 5/10/83 'f~. 11/21/83 1Y-12 5/25/83 1Y-13 5/27/83 1Y-14 5/13/83 5/18/83 1Y-15 5/29/83 1Y-16 5/30/83 10/23/83 Drill Site 2C Well No. Log Date_ _ 2C-4 2/19/85 2/28/85 2C-7 10/15/84 Drill Site _ 2Z' Well No. Log Dat_e /10/83 2Z-2 ': 6124/83 7119/83 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 Oil & Gas Oons. A,qchomge RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 04-03-86 TRANSMITTAL # 5622 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Final Prints: Schl: CET's or CBL's: One * of each "~iA- 14 12-03-85 '~ 1E-24 02-21-85 ~ 1E-24 02-23-85 ~'° lQ-1 04-16-85 '~IQ-10 01-28-85 ~2E-10 01-14-85 '~ 2E-11 01-13-85 '~' 2E-12 01-13-85 '~ 2H-9 12-06-85 ~2W-15 02-11-85 ~3A-5 11-03-85 ~ 3A-6 11-03-85 '~3A-8 11-04-85 '~ 3F-8 11-14-85 R~dn #2 7050-7732 Run #1 6390-6964 Run #2 6400-7000 Run #1 0695-4476 Run #1 5346-7359 Run #i 4710-6500 Run #1 6050-8250 Run #1 5390-7522 Run #1 6000-8016 Run #2 6488-8062 Run #1 6771-8518 Run #1 6086-7545 Run #1 5186-7006 Run #1 5410-6885 Receipt Acknowledged: state of AK*bl/se Vault*films Drilling*bi ARCO Alaska. Inc. ~$ · Sul~s~diary of Atl·nticRlchfiel4Com~)lrty Date: NSK Clerk*bl il & Gas Con~. Commissior ARCO Alaska, Inc. Post OfficeE}ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 19, 1986 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi ss ion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Well Completion Reports Dear Mr. Chatterton- Enclosed are the Well 1H-4 3A-2 Completion Reports for the following wells' If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU13/L147 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany , ~, STATE OF ALASKA O(,¥ ALASKA LAND GAS CONSERVATION C ' ~MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL []XX GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc, 82-10 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50- 029-20706 4. Location of well at surface 9. Unit or Lease Name 1169' FSL, 493' FWL, Sec.5, TllN, R10E, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 1068' FSL, 1613' FEL, Sec.5, TllN, R10E, UM 1A-14 At Total Depth 11. Field and Pool 887' FSL, 1311' FEL, Sec.5, TllN, R10E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 100' RKB ADL 25647 ALK 465 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Connptetions 01/26/82 02/06/82 02/11/82*I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth(MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 8285'MD,6933'TVD 8170'MD,6838'TVD YES ~ NO []I 1966 feet MD 1650' (approx) 22. Type Electric or Other Logs Run D IL/SP/GR/SFL/FDC/CNL/Cal, Gyro/CCL, CBL/VDL/CCL/GR, CET 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED . 16" 65.0# H-40 Surf 80' 24" 200 sx PF 10-3/4" 45.5# K-55 Surf 2391' 13-1/2" 950 sx Fondu & 250 sx AS II 7" 26.0# K-55 Surf 8045' 8-3/4" 1225 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7280' - 7334' 3-1/2" 7488' 7214' & 7463' 7339' - 7347' 7353' - 7359' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7379' - 7402' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7572' - 7584' Leak (~ 4705' 250 sx Class G 7594' - 7626' 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD II~ I Flow Tubing Casing Pressure CALCULATEDi~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (Cor'r) 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. NoneP ECEIV D !':::' i::' ~'~ ~, 0 ~ e Form 10-407 * NOTE: Tubing was pulled & well recompleted 12/9/85. DAM/WCl4 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME Top Upper Sand Base Kuparuk GEOLOGIC MARKERS MEAS. DEPTH 7680' 7696' TRUE VERT. DEPTH 6441 ' 6454 ' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and graviw, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS Well Hi story (workover) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ) ~ Asso¢i ate Engineer 2'/~-8L~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ,.. Item 16 and 24' If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Prepare and ~ubmlt the "l.illal Rel~' on ~ fl~ Wedne~ay a~ a well is s~dded or wooer o~mtlon. Daily wow p~or to ~ddlng ~ould ~ ~mmM ~ ~ ~ givi~ inclusi~ dates only. District Alaska Field Kuparuk River Au~. or W.O, ab AEE 603121: ' 12/03/85, ~2/04/85 Operator 12/05/85 Well History- Initial Report'- Daillp~,:-:: North Slope Borough Lease orUnit AI)L25646 Recompletiov~. ~! 50.~4)29~2070'~ PP~ Alaska Prior statul if a W.O. dn tb~ sq~..acro'a~:~ pp$? br~ne~..; ~; t=ee~,~ ~r~-~':'~~ ts~ pull 3]S!t tb$'~;:,,. RD to ~. DF¥ PU: fSh~: ore= slick stiCk, POai~ rec'd fab., RIE. w/~l}:~-t~::~:li:'P~; 7" @ 8263' 7759~ PBTD, RnCET 9.9 ppg NaCl/NaBr RIH, mill on pkr, CBU, POH w/fsh,.i' RIH-w/Scrprs & boot bskt' to PBTD, CBU,~POHi RU Schl,~ rn 7" @ 8263' 7759' PBTD, Stage in hole 9.9 ppg NaCi/NaBr POH w/CET, RD SchI'; RIR w/Bkr BP, set.@ 7200! & ts~, POH, ~D BOPE, chg ou~ wellhead& tsp. NU & tst BOPE~ At= to tst 7" to 3500 psi, broke dn @ 3000 psi, held 1700 psi. PU Bkr R-3 pkr, stage in hole, lk'g f/leaks. 7" @ 8263' 7759' PBTD, RIH w/cmt retnr 9.9 ppg: NaC1/NaB= RIH w/pkr, isolate leak in cs$@ 4705' DPM, POOH. RIH w/retrv'g ti, pull BP. RU Schl, rn CST, log 4850'-4550' cmt retnr & RIH. · PU lA-14 7" @ 8263' 7759' PBTD, Drlg cmt 9.9 ppg NaCl/NaBr RIH w/cmO retainer, set @ 4760', POOH, RD Schl. RIH w/RAH, set @'4450'. Est IR, sqz w/150 sx C1 "G' w/l% CaC1, .5.% D-28, .2% CD-31 & 1 gal/100 sx defoamer. Displ w/brine; Rev out, POOH, LD RAH'. RIH, WOC, DO cmt. 5'6.24% 12/06/85 The above is co rrect Signature //~ _ For form preparatio~and distribution, see Procedures Man'~al, Section 10, Drilling, Pages 86 and 87, Data I ITitle Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned or So d "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of t me. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District ICounty or Parish I M. aska Field ~Lease or Unit Kuparuk River Auth. or W.O. no. ]Title AF~. 603t2! I Operator North Slope Borough ADL 25646 Recompletion Accounting State cost center code Alaska Well no. lA-14 AP1 50-029-20706 A.R.Co. W.I. 56.24% IOate 11/29/85 ARCO Alaska, Inc. Spudded or W.O. begun I otal number of wells (active or inactive) on this est center prior to plugging and bandonment of this well I our _ _ ~Prlor status if e W.O. 2030 hrs. ' I I Workover Date and depth as of 8:00 a.m. [2/07/85 thru 12/09/85 12/10/85 Old TD Released rig 2230 hrs. Classifications (oil, gas, etc.) Oil Producing method Potential test data Flowing Complete record for each day reported 7" @ 8263' 7759' PBTD, Rn'g 3½" CA 9.9 ppg NaCl/NaBr DO cmt to 4760', press tst csg; no tst, POOH. RIH w/Champ pkr, set @ 4450', circ. Sqz w/100 sx Cl "G" w/1.0% CaC1, .3% FL-28, .2% D-31 & 1 gal/100 sx FPgL. Rev out, POH, WOC. RIH, tag top cmt@ 4510', drl cmt to 4750', tst csg to 1500 psi. Drl retnr, circ, POOH. RIH w/scrpr, circ& filter brine, circ, POOH, LD DP. RU Schl, make gage ring/JB run to 7500', POOH. RIH, set WD pkr @ 7455', RD Schl. Begin rn'g 3½" CA. 7" @ 8263' 7759' PBTD, RR Diesel in tbg & ann Rn 234 its, 3½", 9.2#, J-55 AB Mod BTC tbg. Set top pkr @ 7214', SSSV @ 1966', 7214' WD Pkr @ 7463', TT @ 7488'. Set BPV. ND BOPE, NU & tst tree. Displ well f/7160' w/diesel. BPV. RR @ 2230 hfs, 12/9/85; Set New TD Date I PB Depth '- 7759' PBTD Kind of rig 12/9/85 Rotary Type-completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands Well no. Date Reservoir' Producing Interval Oil or gas Test time Production Oil on test Gas per day - _ Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date - corrected _ Th¢~ ¢lh,,,~,,~ ;~ ~..~ _ Signature ~ Fo r fo~m~p ~ e~ar~~' see Procedures Manual, Sectfon 10, Drilling, Pages 86 and 87. Drilling Superintendent Drill S~te lA Well No. "1A-4 -N,1A.5 '~lA-7 ~1A-9 ~1A-11 '~1A-12 '~IA- 14 "~ 1A-15 ~.lA-16A ATTACHMENT II KUPARUK RIVER UNIT Production. Logs Log 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~ ~ 6/8/82/2 Drill Site Well No. 18 Log Date __ '"'18-1 12/26/81 ~18-2 6/25/81 '"'1B-3 11/16-18/81"--~ '~ 3/12/82/ "'lB-6 11/18/81> '~ 9/10/82 ~ '~1B-7 11/23/81 ~18-8 12/28/81'-~ "~ 8/4/82/ 6/24/82-- ~18-9 'x~___8/3/84 Drill Site 1C Wel 1 No. '~c-~ '"~1C-2 "1C-3 '-J1C-4 "~1¢-6 'X,l¢.7 1¢-8 ..Log'Date 5/9/8'1 5/8/81 7/13/81 3/9/81/ 2/26/81 11/30/81 5/19/81 5/21/81 Drill Site 1D Well No. Log Date "%lD-1 1/80~ ~' 5/23/83/' '"~lD-3 8/5/80 1D-4 ~7/30/80~ ~ 8/13/80/ ~lD-5 6/11/81 ~1D-6 6/9/81 '~1D-7 6/8/81 X.~lD-8 (WS-8) 5/10/78 · RECEIVED FEB ~ ! Lq86 Anchorage :iCO Alaska, Inc.( Post Office~ ,~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 26, 1987 Mr. C. V. Chatterton Alaska Oil and Gas Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Subject: Kuparuk River Field Water Injection Surveys In compliance with Rule 4 COnservation Order Number 198, Kuparuk River Field Waterflood Rules, we are hereby submitting injectivity surveys for Kuparuk Water Injection Wells for the fourth quarter of 1986. The data is provided in the form of spinner logs or separate zone surveys as listed in Attachment I. The spinner logs will be sent separately. Injection rates determined by separate zone surveys are also listed in Attachment I. If you have any questions concerning the information reported, please contact me at (907) 263-4386. Sinc~ (~~. Roberts, Jr. Operations Engineer JWR/SPT- -pg:O052 Attachments Commission .. ~ :. '2: ?.2 ARCO Alaska, Inc. is a Subsidiary o! AtlanticRichlieldCompany .!~ ATTACHMENT 1 KUPARUK RIVER FIELD CONSERVATION ORDER 198 RULE h - INJECTIVITY PROFILES FOURTit QUARTER 1986 SUBHITTAL WELL APl NUMBER NUMBER 50-029 DATE OF DATE OF DATA TYPE REASON FOR WELL INITIAL PROFILE/ PROFILE/ PROFILE/ COMPLETION INJECTION SURVEY SURVEY SURVEY 20706 02/22/83 12/86 SURVEY FOLLOWUP A&C SS 20711 03/01/83 12/17/86 SPINNER FOLLOWUP A&C SS 20713 03/O1/83 12/26/86 SPINNER FOLLONUP A&C SS 2123~ 11/16/85 11/22/86 SPINNER INITIAL A&C SS 21210 10/28/85 11/23/86 SPINNER INITIAL A&C SS 21307 10/28/85 11/2h/86 SPINNER INITIAL A&C SS 20950 11/01/85 11/25/86 SPINNER INITIAL A&C SS 21281 11/11/86 12/86 SURVEY INITIAL A&C SS 21055 11/27/86 12/86 SURVEY INITIAL A&C SS ZONES I NJ ECT I ON TAK I NG BWPD WATER _ A 13~7 A&C A&C A&C A&C A q000 A 974 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 14, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Dear Mr. State Reports Chatterton' Enclosed are the December monthly reports for the following wells- 1A-7 2H-6 3A-13 3F-12 3J-11 4-29 L2-29 1A-13 2H-7 3A-14 3F-13 3J-12 16-15 L3-5 1A-14 2H-8 3A-15 3F-14 4-23 16-19 L3-19 1H-4 2H-9 3A-16 3F-15 4-24 16-20 LS-l~ 1H-8 2X-8 3F-11 3J-10 4-27 L2-21 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU13/L05 Enclosures RECEIVED JAN 1 4 ] SG 011 & Gas ~s. ~ommjs.~on ,' ALASKA AND GAS CONSERVATION CO ISSION ONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS Drilling well [] Workover operation)(D~ 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 82-10 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20706 Location of Well at surface 1169' FSL, 493' FWL, Sec.5, TllN, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 100' RKB ADL 25646 ALK 465 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 1A-14 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool For the Month of. December ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Accepted rig ~ 2030 hrs, 11/29/85. Killed well. ND tree· NU BOPE & tstd. Pulled tubing· Fished and recovered pkr. Ran CRT log. While tstg 7" csg, discovered leak ~ 4705'WLM. Ran CET. Repaired leak by squeezing w/250 sx Class G. Drld out cmt. Set "WD" pkr, tailpipe, & completion assy. ND BOPE. NU tree & tstd. Displaced well w/diesel. Secured well & RR @ 2230 hfs, 12/09/85. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 3-1/2" tbg, SSSV ~ 1966' RRH pkr ~ 7214', W-D pkr ~ 7463' TT ~ 7488' , , · 14. Coring resume and brief description None 15. Logs run and depth where run CRT f/4850' - 4550' 16. DST data, perforating data, shows of H2S, miscellaneous data None RECEIVED ~aska Oki & (.~as Cons. Commi~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED ~ ~ .~Z/-'1~ TITLE Associate Engineer DATE NOTE--Report on is form is required for each calendar month, re§ardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 TEHP3/NR18 Rev. 7-1-80 Submit in duplicate ARCO Alaska, Inc. { Post Office BOX 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 7, 1985 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commi ss ion 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT- 1A-14 Dear Mr. Chatterton' Enclosed is a Sundry Notice for the subject well. We propose to convert 1A-14 to a selective single completion. If you have any questions, please call me at 263-4944 or Jeff Quintana at 263-4620. Sincerely, J. Gruber Associate Engineer JG/tw SN/L069 Enclosure RECEIVED Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASK IL AND GAS CONSERVATION C MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELLxI~] OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well Surface: 1169' FSL, 493' FWL, Sec.5~ T11N~ R10E~ UN 5. Elevation in feet (indicate KB, DF, etc.) RKB 100' I 6. Lease Designation and Serial No. AnL 25646 ~LK ~.65 7. Permit No. 82-10 8. APl Number 50- 9. Unit or Lease Name ''-r ....... ;'e. t 10. Well Number !A-!~. 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: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate ~ Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing ~i~ 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 Fl 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). ARCO Alaska, Inc., proposes to convert well 1A-14 to a selective single completion. The procedure will be as follows: 1. Well will be killed with brine. 2. Current completion assembly will be pulled. 3. A retrievable packer will be run to test casing. 4. The well will be completed as a selective single. 5. After the rig is released, an acid and/or frac job will be done. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. BOP equipment will be tested weekly and operationally ~ested 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: November 25, 1985 RECEIVED NOV 2 Alaska 0ii & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed r(~~ ~.~ Title Associ ate Encji near c~' ' The space bel for Commission use Date / I'~'~--~ Conditions of Approval, if any: ~pproved Copy ~T L~l[ ~. ~TII By Order of Approved by. COMMISSIONER the Commission Date Form 10-403 (JLQ) SN/102 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate TO- DATE: KUPARUK ENGINEERING Transmitted herewith are the following: D. W. Bose/Lorie L. Johns'on PLEASE NOTE: BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE RECEIVED' ~ ~ - JUL :~ o ]982 r(1[1' ~/.~C(,C:} Alaska Oil & Gas Cons. Commissi( PLEASE RETURN RECEIPT 'TO: ~/v ARCO ALASKA, INC.- v , Anchorage - - ATTN: LORIE L. JOHNSON AFA/311 P. O. BOX 360 ANCHORAGE, AK 99510 ARCO Alaska, Inc .... Post Office B{ 60 Anchorage, Alaska 99510 Telephone 907 277 5637 July 6, 1982 C. V. Chatterton State of Alaska 'Oil and Gas Conservation Com~. 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Mr. Chatterton: Enclosed are well completion rePOrts~for Kuparuk Wells lA-10 through 1A-16A. Very ~.truly yours, JSD/er cc: L. K. Blacker -AFA 330 w/o Attachment L. M. Sellers -ANO 332w/Attachment E. A. Simonsen -AFA 311 w/Attachment H. C. Vickers -AFA326 w/o Attachment ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany' ~ ~I ~: ~ STATE OF ALASKA O~] · ALASKA AND GAS CONSERVATION C MISSION 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, ]:nc. 82-10 3. Address 8. APl Number P.0.Box 3{50, Anchorage, AK 99510 50- 029-20706 4. Location of well at surface 1169'FEL, /493'FWL. Eec 5~ ]llN; ~lUl-; UN 9. Unit or Lease Name Kuparuk River Unit At Top Producing lnterval 1197'FSL, 1862'FEL; Sec 5, T11N, R10E, UN lO. WellNumber 1A-lZ~ At Total Depth 887'FSL, 1311'FEL, Sec 5; T11N, R10E, UM 11. Field and Pool Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 100'RKBI ADL 25647 ALK 465 Kuparuk River 0il Pool 12. Date Spudded 13. Dal;e T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore I 16. No. of Completions 1/26/82 2/6/82 2/11/82 -- feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+l-VD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 8285' 6¢33' 8170' 6838~ YES[~ NOF-1 1992' feetMDI 1650' (approx) 22. Type Electric or Other Logs Run DIL/SP/GR/SFL/FDC/CNL/Cal Gyro/CCL, CBL/VDL/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" 65# H-40 Surf 80 ' 24" 200sx Permafrost 10 3/4" 45.5~ K-55 Surf 2391' 13 1/2" 950 sx Fondu & 250 sx AS II 7" 26# K-55 ' Surf 8263' 8 3/4" 625sx Class G lead ' and 600 sx Class G tai1 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) ., 7280-733~ ' 3 1/2" 7204 ' 7119 ' 7339-73/47 ' 7353-7359' w/b SPF 26. ' ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7379-7~02 ' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7572-7584' ' ~' ' N/A "' '- 759/4-7626 ' - · . 27. ' PRoDucTION 'TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) · · ' ' 3/4/82' ~:'' ':'" ' ' Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MC~ WATER-BBL C'HOKESIZE IGAS-OILRATIo · . 4/5/82 16,9 TESTPERIOD I~ 1533 . ~.707 . 0 ~176/64"I . 461 . Flow Tubing C'asing Pressure CALCULATEb OIL-BBL .' GAS_MCF WATER-BBL OIL GRAVITY-APl (corr) ' :Press.":95' __ 24-HOUR RATE I~ ' ]224'/4 1034 0 . ' 2/4.1 ° 28. '"' ' ' ' r ' 'CORE DATA ~ Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core Chips. ' · · ' ' ' ' :' ' ' JUL 1 ' ' ' - · · . Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 3'0. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk 7248' 6145 ' River Form. Base Kuparuk 7693 ' 6485' River Form. -- 31. LIS'i OF ATTACHMENTS /A 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed_ ~ ,~, ~~~{____~t-~ Title Reg±on 0ps. Engr.Date _7////~7_, --- A '/ 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. lter~ 27' Method of Operation' Flowing~ Gas Li{t, Rod P,.,~mr~... Hvdr.aulic P~.,.~mp, ~..,bmersib!e,, Water In-. Form 10-407 KUPARUK ENGINEERING TO: TRANSMITTAL D. W. Bose/Ann Simonsen DATE: ~/~/~ WELL NAME: /~ w/~ Transmitted herewith are the following: PLEASE NOTE: BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE RECEIVEI) · *' /' , '.: JUN101982 RECEIPT ACKNOWLEDG DATE: '" A~ska Oil & GaS%~d-d~-C~missio. PLEASE RETURN RECEIPT TO: ARCO'A~ASKA, ~NC. ~chorage .: ATTN: ANN SIMONSEN - AFA/311 P. O. BOX 360 ..' ANCHORAGE, AK 99510 ... F P,C :.1: j. J. Pawelek/Ann Simonsen Tra:-,smi~t~d here,.,;ith are the following' ~',C~ ItOTE' BL BLUEL~ilE PL--.~,- - ' ' S - SEPIA, F - FILi'l, T - TAPE ?,ECE ~ PT -,:Cr,,,O,,L ED ~,!~*.sI<a Oil & 8as Cons CommiSsion ARCO ALAS~¢, I~4C. Anc~orag~ .... ~,,,n, "' AFA/31i P.O. BOX 360 TRAilSHI=T~' TS' ~J~ U//~ /~'~J FROM: J. J. Pawelek/Ann Simonsen DATE- /-7/` ~- ~$ WELL "'":=',,,-,,.,,_ · Transmitted here:.:ith are the following' ?L~.%2 HOTE' BL BLUEL!!iE, S - SEPi~,, F FILM, T TA: b .S£ ,SE-dR:; P, ECF_i?T TO' ARCO ALAS!iA, INC. ATTO]: Ar.;~; SIHO~ISE~! = AFA/311 P.O. BOX 360 ,,,~C~:On' ~- ~lO RECEIVED APR 0 8 1982 Al~ka 0ii & Gas Cons. Co~rni~;iOi1 Anchoraoo NORTIi ~LOPE E~IGI~.IEERIi;G ( J. J. Pawelek/Ann Simonsen Transmitted herev:ith are the following' PLEASE ,~01E' BL BLUEL!i~, /'/'? -"z y S - SEPIA, F - FILH, T - TAPE REC'2 ! PT AC~,,,~,.';L[:-i)GEJ~f" ~""-' pI~ :,-.3 ~- ' "r :.,~' ETURr; I":ECE ~ PT' TO' R£CEIVED ~'t~ 0 81982 ARCO ALAS~tA, I~'~ l '1 t., · A tT~, A~,i~i SI . ~E~I P.O. BO:,; 360 ~'"r;':np, AC',F :" aa~l 0 · Alaska Oil & Gas Cons. Commis$io~ A FA~ 311 Anchorage . ARCO 'Alaska, Inc. f Post Office Bt {60 Anchorage. Alaska 99510 Telephone 907 277 5637 March 22, 1982 Mr. C. V. Chatterton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 · ~ SUBJECT: 'State Reports Dear Sir' Enclosed are Well Completion Reports for the following drill sites' 13-20 15-1 1A-14 1A-15 WS 23 Also enclosed are monthly reports for February on these drill sites' 11-7 13-23A 14-29 14-30 15 -2 Eileen No. 1 Ol.iktok Pt. No. 1 Copies of the DS 13-20 gyroscopic survey were sent to you under separate cover. Si ncerely,~ P. A. Van Dusen District Drilling' Engineer PAV' JG/hrl RECEIVED Enc 1 os ures GRU2/B14 MAR 2 3 AJaska Oil & Gas Cons. Comn~is$ior~ t~nch0ra§~ ARCO Alaska, Inc. ;s a Subsi,'iiar}' of AHaniicRtcrd;eldCompany ~ t(r~''''~ STATE OF ALASKA (~i ..,.VIISSION ALASKA ,,~kND GAS CONSERVATION C WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well Oil [~ GAS [] SUSPENDED [] ABANDONED []. SERVICE [] :2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-10 3. Address 8. APl Number P. O. Box 360, Anchorage, AK 99510 so-029-20706 4. Location of well at surface - 9. Unit or Lease Name 1169' FSL, 493' FWL, Sec 5, T11N, RiOE, UM !LOC^T~O,~S · Kuparuk River Field At Top Producing Interval ; VERIFIED ! 10. Well Number 1068' FSL, 1613' FEL, Sec. 5, T11N, RIOE, UN iSurf. E . 1A-14 At Total Deptht 13. H.~'~i t 11. Field and Pool 887' FSL, 1311' FEL, Sec. 5, T11N, RiOE, UM Kuparuk River Fi-eld 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk Ri ver 0i 1 Pool 100' RKBI ADL 25647 ALK 465 ' I 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 01-26-82 02-06-82 02-11-82 N/A feet MSL 1 17. Total Depth,MD+TVD) 18. PIug Back Depth (MD+TVD)19. DirectionalSurvey I 20. Depth where SSSV set I21.Thickness°fPermafr°'t 8285'MD, 6933'TVD 8170'MD, 6838'TVD YESJ~] NO[]] 2003' feetMg 1650' (approx.) 22. Type Electric or Other Logs Run DIL/SP/GR/SFL/FDC/CNL/Cal Gyro/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" '65# H-40 Surf 80' 24" 2(lOsx Permafrn_~t r. mt 10-3/4" 45.5# K-55 Surf 2391' 13-1/2" 950sx Fondu &:250sx Arctics~t '7. 26.0# K-55 surf 8-3/4" 625sx .ClaSs G (lead) 600sx Class G ~tail) 24. Perforations open to Prqduction (MD+TVD of Top an d 25. TUBING RECORD in~erval,rsize and number) sIZE DEPTH SET (MD) PACKER SET (MD) ~2~ .~-1/?" 77n4' 7126' 7280' 7334' 7339' 7347' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ,~ ~ 7353'-7359' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7379'-7402' N/A · , 7572'-7584' . 759:4,.7626, 27. PRODUCTION TEST , Date~J:irs,t PFoduction~ i · . .: ,~.tMethod of Operation (Flgwing, gas lift, etc.)' I ., · Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO. . TEST PERIOD ;I~ ..... ]... . Flow~.Tubing ,CasingP[essure CALCULATED. _ .k OIL-BBL GAS-MCF. ' W/~TER-BBL OILGRAVITY-API (corr) Press: '.'1 · 24-HOUR RATE"~' · ·., .., , ~,: ,', ., . ~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. '..' · "'., . · .:, ';..h' ' '.' "~'~:S4fa Oil ~,~- , Form 10-407 CONTINUED ON REVERSE SIDE Rev. 7-1-80 ·_ ~ubmit in duplicate 29. NAME Top Upper Sand Base Kuparuk GEOLOGIC MARKERS MEAS. DEPTH 7680' 7696' TRUE VERT. DEPTH 6441' 6454' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A. 31, LIST OF ATTACHMENTS Drilling History, Gyro Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~-'~.~. ~'r~,~,z~, Tree Sr. Drlg En,gineero.te INSTRUCTIONS General: This form is designed for submittihg a complete and correct well completion report and log on all types of lands and leases, in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injeCtion for in-situ combustion. · Item 5: Indicate which elevation is.used as reference (where not otherWise shown) for depth measurements given in other spaces on this form and in any attachments. "' Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. . Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hvdraulic Pt.,,mp, S~.bmprsible. Water WELL A~ ¥ = 5,971,~67.2~ X = 540,~178.17 LAT = 7~°19'58.741'~ ~ ' ~ ~ ., , LONG =_ 14~°40'26.679'' ~ ~ ~~,~'t~ ~ ~ .5,97134682 ~ (+)~, WELL A2 = , - % ~ --v~ ,-i , X = 540,17832 ~ _ L I ~ LAT = 70°19'57.557" ~l't~3~'~ LONG = 1~9°~0'26.693'' 231~ WELL A3 Y = 5,971,227,31 · ~~ 'l I ~ X = 5~0,178.51 'i.~~t~..] ~ ,,~'l ~ LAT = 70°19'56.381" --~ ~~(~~/ = 149°40'26.707" .~' ~ ~~ I '~ XLONG I ~1- -I ~ WELL A~' Y = 5,971,~106.8378 I ~[~~1~ X= 540,1 ,52 ~~~(+).~' LAT = 70°19'55 196" LONG = 1~9°~0'26.725'' q i ~ WELL A5 Y = 5,970,986.86 - X --- ~,-- ~; = ~40,178.61 ..... ~ .... ~ ,'r/ ' LAT = 70o19'54.0~6'' ~il AS~. - . ~ ' 'LONG = 149o40'26.741'' ~ ~ LONG = 149040'26.757' ~' A~ ~, ~ ~ LL'A7 Y 5,970,746-73 ~ ~~ "~ X 540,~78.5~ ~ ~ LAT 70o19'51654' --~- ~r-- ~[~)~x~ .... A LONG 149o40'26781" ~ ~ · ~.. ~ WELL A8 Y · 5,9'70,626.78 X = 540,178.59 ) ~~ LONG = '149°40'26.798'' · ~f ~..., I HEREBY CERTIFY THAT I AM ..~, ;, .,. -"" ~ ,. · ..~'~;,.. PROPERLY REGISTERED AND LICENSED ., -.y -' ' ' "C,' ' TO PRACTICE LAND SURVEYING IN ..... ' " ~ ' " THE 'STATE OF ALASKA AND THAT ' ' ' -'" '~' ~ /: ' ". .////~~ ............ . THIS PLAT REPRESENTS AN AS- ~ ~. ,, ~ ..... ;,,.~,. ~ .¢. THAT ALL DIMENSIONS AND OTHE~ ~ .~ . ,' . - ,. · · ',' .', . .,. -~., .'.,; DETAILS ARE CORRECT, ~S OF: ,...,. ,,, ,.. ~(';..~ . i[~ .... .. .... i ii I i ~_/~ . . i ii i i i i ii AllanticRichfieidCompany O DATE: DRAWIN~ No' NORTH AMERICAN PRODUCIN~ DIVISION ALASKA DISTriCT- KUPARUK Il I Il I . m u, I Kuparuk 1A-14 Drilling Hi story NU Hydril and diverter. Spudded well @ 1600 hrs, 01/26/82. Drld 13-1/2" hole to 2410'. Ran 58 jts 10-3/4", 45.5#, K-55 casing, w/shoe @ 2391'. Cmtd w/950 sx Fondu (lead slurry) & 250 sx AS II (tail slurry). 'ND Hydril & diverter: Installed 10-3/4"'packoff & tested to 3000 psi. NU BOPE & tested to 2000 psi - ok. Tstd csg to 2000 psi - ok. Drld. FC & cmt. Tstd csg to 2000 psi. Drld FS & 10' new formation. Tstd formation to 12.5 ppg EMW--bled off 290 psi in 5 min. Drld to 2520'. Tstd form to 12.5 ppg EMW--bled off 110 psi in i min. Continued drlg to 2668' Tstd'form--bled off 300 psi in .5 min. Drld to 2902'. Pumped 70 bbl LCM ~alanced plug. Tstd form - ok. Drilled 8-3/4" hole to 8045'. Run DIL/SP/GR/SFL/FDC/CNL/Cal. Continued drlg 8-3/4" hole to 8285'. Ran 201 its 7", 26#, K-55, BTC csg to 8263'. Cmtd 7" csg w/625 sx Class G cmt (lead slurry) & 600 sx Class G (tail slurry). Set 7" packoff and tstd to 3000 psi. Tstd 7" csg to 2000 psi. Drld FC & cmt to 8170'. Arctic packed 7" x 10-3/4" annulus. Tstd 7" csg to 2000 psi. Run gyro/CCL f/8170' to surf. Run CBL/VDL/CCL/GR f/8170'-2000'. Ran 3-1/2" completion assembly w/tail @ 7204' & pkr @ 7126'. Tst tbg hanger & packoff to 3000 psi. Displ brine w/diesel. Tstd 3-1/2" x 7" annulus ,to 2000 psi. Set pkr. Tstd tbg to 2000 psi. ND BOPE. NU tree & tst to 3000 psi. Secured well & released rig @ 1200 hrs., 02/11/82. JG:hrl 03/18/82 GRU2/B22 March 16, 1982 Bob Hines ~gO Alaska, Inc. O, Box 360 AncPor~e, Alaska 99510 Re: OUr Boss GyrOscopic surVey Job No. Boss-16968 Well: /A-14 (SEC5 TllN R10E) Kuparuk Field North Slope, Alaska Survey Date: February 8, 1982 Operator: Blaine Baertsch Dear ~_r. Hines: Please find enclosed the "Original" and one (1) copy of our Eoss Gyroscopic Multishot Directional Survey on the above well. Thank you~ for giving us this opportunity to be of service. Sincerely, NL SPERRY-SUN, INC. Kirk Afflerbach District Supervisor =_~c!osures cc: Dave Rees - BP Alaska Exploration Company Steve Lambert - Union Oil Company ,Donald James - Sohio Petroleum Company RECEiYEI) MAR 2 ~ ]982 Alaska 011 & Gas Cons. Commission Anchorage RE,, 'EiVED VISI:RT :[ CAL, ~:~:[ECT Z ON: C:AI..,CLIL. 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DEPTH DEF'TH DEPTH NOR'FH/SOUTH EAST/klEST MARKER : " .. ...... -. -. -'. .-: "..':: · :.: · - .- · : :. :. ::!:-.: :..:'... -~-. ::.: ~:' 7'..::-': ---:.:?::.:~':;::.4... .... -' l ' ,. ..... . . ':, ,::, · :' · ' ' '.',.-~ i':~---:::.~ ..:...L. ::,-,'- -.~ ':-~" ' ' ?::.' ;t..~'~':: :-:~-~'.": ::-::. :.' ' ' ;:,' :~ .... , ~, i:~ ::i~, ....... 'ii:i:.:; ~;' ~ :'F~;~:i: i.~'.~ :: .' 4 .: .... ' ' [. :-. ' '. "::f:'..':':: :,=, ~ - ::.:: ~.':." .~..::' ,%, %, .~ .~, .' '.: .[:; F.:..- ~.~ ' '..~.U~ ' : ':'~ :';.:~:":" :: .-~ "-' -:" :. ~: ';.~. '~.;;.:~:j3'.'['::':..: :. ;--, :." ': '.% :!: ~. ~'~--' ~."' :[::::[;':fE::'~ :::~: ]'i ~:::::;~ ', ' . ~:-';~ '~, j'~ ' ' .::;~:i:~i~i::~:~::~:~.[:.~:~::.~.~.~:~:.i~.::~[:~L~:~::~.:;:..i~iF:~:~:~;:.:: ;;: ~ ~: ' '" 81 70 ~,837. SO ~,737.'::30 24.~,. 79 S 34.22. '.3'F¢ E F'[{TD E"-"-'~ 6,'P:33 02 /-'::":'":' 02 2:32.00 '-' 347A 40 E DRILLER TD ' ..... COORD :[ NA ]'E~:.'.'~ ....................... MARKER ......... --,.. .......... MEA~-RI IRED--DF'F~:¥H ........... ..'F-VD ..... .-,-.~t-':I-i~I-~7~NE-$'S; -~,,I:r-,T-M--P~F-~---.-]"C~ 14r:~ ~ ~."---~'i - . .. , .. :, : . _ .... : ~ .... . .- .'.:::'...:::.:~::' ~. :::.. ' . :. :' ' - ' :. ·; .-::' . :.'::. ' . . . ' ~ :: :.:: .'L:i. ~. "~.:':..:' '.F.:::'..': -.'..... - ... :: .: · .. ..:::.: :.:.:-':.h;..:.:.i::<;:.:":.L..::.':.>:::'::. TOP IIF'PER SAND 7680 A44 BASIS KUF'ARUK 7696 6454, 1'--',., /- '-":,,;,.:,4 .... . ~3 jF'-.x::,. :=:~%c.,:_. . 31 '--."-.',..,.:.,/..:,'~;¢E ; '-' I-' ..... " "', ~"' ...... - . - ..· .:. · · .:: .:: .'.. :.. 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U,~ :.- : ~.~ .:::,.,: :...::.:,:... ¥: ............. - .............. ::,:=,: ........... . .......... ..::.<,:~.::,:.=:¥,.,::?, ............... .,:.~ ................... .~o~"-,'.0<~=, ::'}4.76, 40E .................. ......... 1..) ... FROM...L. I NEAF¢.... EX. IRAF.:OLAT I.O N-..-BEI, OI4-. E E E F..-E.=,-T--.;=.,T-A.T-:[.~aN,,. "~ - - - . : '-' '-~ - · '-' - .: .... --" .. - : '- -.- : .:~ !~ ~.~.'::: 7 i:;::~':::::::::::::::::::::::~::!'i:ii::~:.::.;.~ ~t ' I-' I-' J ....... "' ' ' ~' .... ' ' ~ '-~' ' - ' ' .... "'"" ' : ' ": ' , - ::'":'>' :';; :?:::':: ::::::::::::::::::::::::::::::: :::'::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: "~:::i :::::::::::::::::::::::::::::::: ::'::::'.} ::: :: ' .. £ A r A -. A L, ... L L A 'l :l: U N. A N D: I. N ] E R F L IL ~-t ] ]: LI Iq.: :.: B ¥- R A [! I U.=, ..:: LI F .:.:: L. U R V A T U R E'<' :: :.;.:: ::: ::::::::::;: ::.========================================= :::::::::::::::::::::::::::: :: .::~::.~..::::.?i:~:::::::::::::::::::::::::: ..:::::::::::.'.:::::::::::; ':::::.:¥:'" ::".*'::',:::::::::":::.'.::::?:':': ::::: '::';:::':: ::" ". ".'.' :'.": . ' : '.' ...-:" . · :... ::' . .:. :;:.: :. -.:'.:. '.::-.:':':::: :--... ::.i' :::.. :..::: ,:,:. ':: ::':. '::.: :..:: :....:':...:.::::':: ::?.F: :;.::::::i: :?~;.::::::::::::::::::::::~::!?:i:~::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::;::?.~:::..` ,;: i:::::::::::::::::::::::::..':::"':,:i::::':::":i:i :'. :"::': ¢' :.. '- · . DATE OF .=,LRVEY FEBRLI~4RY :-% 17782 / -.C:O MPU:F.~ ]: I ON.-DA-]:E .: ..... : .:... :'.. :?;". O, .' ::::::::::::::::::::::::::::::::::::::::::::::::: ' ' TF~UE NOF~TH. · . Surface Location --500.00 HORIZONTFIL · :, :i~ ARCO All<-___as..a., Inc. .. ~:'""" i'"ii!!!',, i;i:[:i;i .~ii~"" - .;;. ~' . ':~.!, Our 'Boss' GyroscoPic Survey'- Job No. Boss-169'68 '!il Well: A-14 (SEC5' TllN:R10E) i];i:ii:;:i::ii::i:,!:.:: Kuparuk Field North _ _ ~ ~ on ¢_ ,_ _._ _ Alaska ': ::' , ..... :' Survey Date: February 8, 1982 :.~.:':::." Operator: Blaine Baertsch -':~ .:: , ,ii;st I -' :,;': i:..*!. ' ;; ;: ; f: - ' Scale: 1" = 500 ' i: i . .'.' "!f'i;' : ; ..- .., '1 : ' ,.. ., ;;; . . , , . .... ',. ., ,., '.;r :' ::! ': il;~ ';::~1'''' ': ~'',''' ' :' : ~ i ; :i;!'.~ : ": !!~:i'i'. .~': :., :' : , : · · ,' I';. ,~';' ~! ":" [' ' ' ' : .... : '..*;,( ::!:,:i!ii;~::!~!!';.':.;.;:iii~::if ..... : .... ' ~.' '-~: ,l:' ,.. , . . , , ...... ![ . . ... . :~ ~11 ''.....i", · . . : ,..r, ~ ,.'' .- ... ... . ., ~'" ~ ~"'~,,,.~.~ ." , 1~ . · ' '~ , I' : .; "-.;.' , ,~i:; , · i . , : .~ ,; .' i;· ;!i ,i ~,:!!!,:,it: :!: i,!~!i'; ;': :' · ',i:, . · ' . :; :; :';',,!;'¢.::.i!!.l;; '.,~!!~f!i:;ii'. "; ' ' ' ""'.;. ;,:'; !;' "!. ' !.i't {~ .::,': i[ i..;'' 'i ' ,:..::;,,.:t.. :i ,:. '." .!; ,: ',i ; ,;" ,~t ; .: P ~ ' i ' ' , ROJE C T I ON · :,, ;......... ,: . ., : , ' , '; '. : ~"',: :.': 'ii '";t: !' · i:.,~ · , :,;!" ;' , 8285 · ARCO Alaska, Inc. Our Boss Gyroscopic Survey Job.No. Boss-16968 Well: A-14 (SEC5 TllN. R10E) _. Kuparuk Field ..... .... -.~. --:- North Slope, Alaska · -- "- - - ~-" .......... - ..... Survey Date: -Februa -. . ~ .... . -..'..'L- . 3 2.'" .L: Y~','..-. ' ..:~L..iZ[L/;Z,f..':?'.'* . '_ . "- .2. ' --....- .... -?.,-:- '.[ .... [. '.[..'.'. [[-[.' .'[..:'[.[ ·.."[·-_-[[[[[[[[[[[-.-:';,.."::-.-:._... O~eratoz: ........ ; ....:.. -. · . _ -..;-,., - - :.. _1· -'--r -- .-. .~.- _- .................. ..... :' '~ ":' ':':"=~:: ~'-'" "" "-':":':=::'"-' ':': ...... '-"::'--: '" .... :::[?'~'& 1 e :': ..... 5 o o :~%>.. -:-..-~[..?.~.::..::'~:%: :.:-->-'.[--~ii:.'- ~:'-3--'-:'-':-~:.:-..:-. '..;7..'i.:d:j[~!::::2[[17,;.~.~.~::...:.-. ............ 1 ,, 1. :-'"-- ....................... '""": .... - ........ : ' "'" ......... :-~" ........... ':':"'"' ......... '""':=" L:::~ "i}'bf:' :':.":.':-.'.~'-'-['".:.- ' -.-".i::'-'.;'~ ':/-' ~.uoT;:.-~ :;:.:if ': ...... :".':"Cf:':':' ..... '=':'-'~= ..... '" ~" =--" -'." '..- ." - ~.'---.. ._~>::~-':- --:.:-:-.~-.q~:~..~x--'--:-:-:.-.-. ~....-:---_=:. ;.-:.:-~-..:':..':.::-..='~ ~:.~...'-'.:-:.:~--:-~ -. ~;i..4:"..,:---~.. >--::-.:--..~:_.-_ - ._...:.. ~:--" ::._::Z;: .:': 7':"-::.:-' -' :.::T.: ...... 1500. O0 ", ' : " -'-" .... '-:" .-.: :---.-.: : ' .... ....v.. - ...~:.:::..::.:...-....-.':.:.". %--':'::.:..._ ..........._ :: ..... :........-- : ..... -. -- . '.'..:~:. ~ ...... '-... .... ~.............-..... · .-. '_~ . :.... ':_ _ .. .. _ ..... .. · . _ . . 3000. O0 . . . .. 4500. O0 6000. O0 7500. O0 ~ · . . . . . - k 3487.82'. . ' ..... :'r.. · '" -:.'.'- '.: ..... ::~". '.--.'i: z'..- ....... :".~': -. ':'. · -' - :_:...¥.- .:.:---.:.-..i...-' ..-..k.-.'~' ..'_ :'__._ __~'.'- .... . · '-." :-'~. :.:, :: . ":':':.: t.: .:..'.'.: · ..: ....... :-: ._ .-- --:":--'-'.':-'-' . . .~ .... .......-.:.. ..... ..:&:-:.-.: ...... :::'::.: ._..-.. -:.-..-..- _ . . :. '.. ; _ . -..-.., :.. :~ .- ....... '.. -. .. · t ......... . ........ ? ...... ..- . -. . _ . . · . ..- · . . \. - . : - ..:,>...,..:. .:_:.. \ 'x \ - . . ~ 8285 -' t ~000. O0 4.500. O0 . ......... · .%. ;.; ~ .-- .. . __. .' -. ...... -- .[--.- .: ...... V ER T'ir CR L'-"PP,. 0 J E C T"i-'''': ' '''.-- · . .......... -.'-.~i .. : _-..:'. ' . . _ - .... -' ._ . . . _ ._ @ S85° 21'E x 15~30. CO --£%%- Suggested form to tm insertcd in each "Active" well folder to check for tingly compliance with our regulations. Operator, Well ~a~e' and Numbe~ ' Reports and Materials to be received by: Date Required Date Received Remarks Cc~pletion Report ~" Yes . . . Mud ..... L~ .-., FO --' Pt . . Core Registered Su~ey Plat ~~ /~/ I ncl ination Su~ey ~()' , Drill St~ Test Re~s _~/)~ ,,, .... ., ........ ....... ~s R~ Yes MC,-, i n ~I .... ri'G .... ,.OF~ E~GI,:E.~R,,, ._l co~ .... · I-cot~ ENG ENG J. J. Pawelek/Ann Simo,~~OL ~~ ~~~ ...... ! l STAT T~ I I s~~ CONFER: J FILF: PLEASE ,,n--. _ ' _ - _ ~ :,~:~ BI_ -. BLUELZ'~:,~, S SEPia, F FILM, I TAP~ · '.., ?T TO' DATE' ARCO ALAS~t'A, ATT~I: AN~i SIHOHSE[! '- AFA/3ll P.O. BO:< 380 ' ,.n-=:.. Cc=lO RECEIVED ,,. .... .,: .i:'i >. , ?i02TH ~LOPE EiIGI"HE:,,Ir:G~'a~ d. J. Pawelek/Ann Simonsen Transmizt-:d herewith are the follov,'ing: , c-c- ,, -- .;=' - " - TAPE PL-.S. iiO~' BL --BLUELT,,=, S SEP-'~,, F - FILi'I, I - RECE i PT ACK;:O'..:L Ei)GE' , , _E;:EE RETL'R;' F:ECEi?T TO' ARCO ALAS!iA, I ~ l~k~. ATT~I' ~.,,.~ P.O. BOX 360 RECEIVED ^TE- MAR A!nsl~ Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Post Office Br. 30 Anchorage. Alaska 995'10 Telephone 907 277 5637 February 22, 1982 Mr. C. V. Chatterton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject- State Reports Dear Sir' Enclosed please find Well Completion Reports for the following drill sites- 11-6, 12-4A, 13-19, 14-9A, 14.26, 15-15, lA-12, lA-13, and B-11GI. Also included are Monthly Reports for January on drill sites' 13-20, 13-23, 14-30, 15-1, an Sincerely, P. A', Yan~sen District Drilling Fmgineer Enclosures PAV/GLA: Sills : .., STATE OF ALASKA ALASKA~', AND GAS CONSERVATION MISSION ; MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well3~E Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 82-10 3. Address 8. APl Number P. O. Box 360, Anchorage, Alaska 99510 5o-029-20706 4. Location of Well at surface 1169' FSL, 493' FWL, Sec. 5, TllN, R10E, U.M. 6. Lease Designation and Serial No. ADL 25647 ALK 465 5. EleVation in feet (indicate KB, DF, etc.) 100' RKB, 61' GL 9. Unit or Lease Name Kupamk River Field 10. Well No. :LA-14 11. Field and Pool Kuparuk River Field Kuparuk Oil Pool For the Month of. January ,19 82 '12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 0600 hrs, 01/26/82· Ran & cmtd 10-3/4" csg w/shoe @ 2391'. 8-3/4" hole to 4240', as of 01/31/82. Drld See Drilling History 13. Casing or liner run and quantities of cement, results of pressure tests 16" 65# H-40 conductor to 80' Cmtd w/200 sx Permafrost cmt. 10-3/4" 45 5# K-55 casing to 2391'. Cmtd w/950 sx Fondu and 250 sx A.S. II. Formation leak-off test to 11.5 ppg, EMW @ 2668'. See Drilling History 14. Coring resume and brief description N/A 15. Logs run and depth where run None To Date. d 6. DST data, perforating data, shows of H2S, miscellaneous data N/A F E 5 2 l cq2 0il & Gas Cons. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge· :SIGNED TiTLEsenior Drilling ~ngineer ~. - y _ _ ~ ~ ~ DATE ~ N CT E__ R ep/rt-o~n ~h i~fo/ -- rm is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Ga~Conservation Commission by the 15th of the succeeding month, unless otherwise directed· Form 10-404 Submit in duplicate Rev. 7-1-80 ]Jk-14 Drilling History . , . ~,~ter ~uddea we~ ~ ~ cs~ w/shoe ~ 259~. ~td 10-3/4 g to 2410 % ..... ~ 2SOsx ~.o .... w/gS0sx eon~ m*~ psi._~kl ~ BOPB ~d tstd to 2000 psi - ok. packoff [ tstd to 2000 Tstd csg to 2000 psi. ~ld FS 0k. ~1~ P~ q ~t._ led o{f 290 psi in 2 min. ~ld to o 2000 psi - 5 ~ b si in 1 min.. Continued csg t_ std fern to !2. _ bled of{ 12~.P~ ~,, 500 s~ in 5 ~n. new {o~. ~ to 1Z.5 ~Pg T~" est ~5 - oleo u~ P ~ - ok one-0' ~d tmtd f~ ~=o~ed le~-O{{ t 12.0 PPg ' %or~in[ to 2668'. r=~ 10-5/4" shoe - tstd {om to ~ed 70 bbl L~. GIH to ~ld 8-3/4" hole to 4240', as of 01/31/82- ,RECEIVED FEB 2 t., 1982 Alaska Oil & Gas Cons. Commission Anchorage ALASKA OIL AND -GAS CONSERVATION COMMISSION THRU: Lonnie C. Smith Commissioner Harold R. Hawkins Petroleum Inspector January 29, 1982 Witness BOPE Test ARCO Kuparuk River Field Well No. Al-14 Sec. 5, TllN, R10E, UM Permit No. 82-10 January 27, 1.982 - I left Prudhoe Bay where I finished witnessing ~tes~s,~ subject of another report, to aRCO's Kuparuk River Field to witness a BOPE test on Al-14 well. Janua~ 28, 1982 - I witnessed the BOPE test on Al-14. Were n° failures. There I filled, out an A.O.G.C.C. report which is attached. In summary, I witnessed the BOPE test on Al-14 for ARCO. The BOPE tests were satisfactory. O&G #4 4ldO ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report · Inspector Operator Date_ Well Repr es on ts t ive~ _/~/~ Well .~. /- Y~ Location: 'Sec ~' T //~/R/~ FUll Drilling Contractor · l.~cation, General Well Sign ~/~ Gener~ Housekeeping ~/~ Reserve pit Rig BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Permit _ / ~ 3~Casing Rig # ~Fy Rep~esentativ~ ACCUMULATOR SYSTEM ~ Fu1.1 Charge'Pressure_ ipreSsure After Closure ~200 psig Above Precharge Attained: -- minyJ~sec Full Charge Pressure Attained: ~ min..,~ sec controls: Master .~ Remote , ~,, t Blinds switch , , , ' ......... , , Co,v, e r :?/'f .. Test Pressure Kelly and 'Floor Safety Valves Upper Kelly Lower Kelly Ball Type Ins ide BOP Choke Manifold No. Valves // NO. flanges,, ,,,~ Adjustable Chokes_ g//.,: .,/;:" Hydrauicaliy operated choke_· Test Results: Failures' .~?~.F_~.~.~: ,,,Test Time Repair or Replacement of failed equipment to be made within Inspector/Commission office notified. Remarks: ~ .~- .~.~. /~..c/~ _f/~ Test Pressure. ~ .> Test Pressure .,.~ ,,~/C,~ Test Pressure .~<,<:xr} TeSt Pressure~ Test PressUre .days and Distribution orig.- - AO&~CC cc - Operator cc - Supervisor Inspector January 13, 1982 Mr. D. S. Smiley Senior Dril ling Engineer ARCO Alaska, Inc. P. O. Box 360 Anchorage, Alaska 99510 Res l/uparuk River Field No. lA-14 ARCO Alaska, Inc, Permit No. 82-10 Sur. Loc,~ II69tFSL, 493'FWL, See 5, Till/, ttlOE, Bottorahole Loe,~ 1349'FSL, 9/t/t'FEL, Sec 5, TI1N, R10E, Dear Mr. Smileyz Enclosed is the approved application for permit to drill the above referenced wel 1. Wel 1 samples and a mud lo~ are not required. A continuous directional :survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized Io{~ information shall be submitted on all logs for copying except experimental logs, velocity surveys and dtprneter surveys. ~ny rivers in Alaska and their drainage systems have been ~elassified as important for the spawnin~ or migration of anadromous fish. Operations in these areas are subject to AS 16.§0,870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to c~encing operations you may be contacted by the Habitat Coordinator's office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46. Chapter 3, Article ? and the regulations ~ro~ulgated thereunder (Title 18, Alaska Administrative Code, Chapte~ ?0) and by the Federal Water Pollution Control Act, as amended. Prio~ to Mr. D. $. Smiley -2- ltuparuk River Field t~o. lA-14 January 15, 1982 commencing operations you may be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded. We would also like to be notified so that a repre- sentative of the Commission may be present to witness testing of blowout preventer equipment before surfaoe casing shoe is dril led. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness p~esent. Very truly yours, liar,'7 W, liut~l ef Commissioner of BY ORDER OF THE COMMIS$10N Alaska Oil a' Gas Conservation ~iesion ecl Department of Fish ~ Game, Habitat Section w/o encl. Departn'~nt of linviro~ntal Conser~ration w/o/enel. ARCO Alaska, Inc. (~ Post Office B~. 360 Anchorage, Alaska 99510 Telephone 907 277 5637 January 6, 1982 Mr. Hoyle Hamilton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject- Kuparuk lA-14 Dear Sir: Enclosed please find the following' · The application for Permit to Drill Kuparuk lA-14 and a $I00.00 check for the application fee. A diagram showing the proposed horizontal and vertical projections of the wellbore. An as-built drawing of "A" pad indicating the proposed surface loCation. A proximity map indicating the relative locations of Kuparuk wells lA-3, lA-4, and lA-13. A determination of maximum pressure to which BOP equip- .ment coUld be subjected. A diagram and description of the surface hole diverter system. A diagram and.description of the .BOP equipment. In addition, please note. that this well's bottom hole location will not require letters of Non-Objection from BP Alaska Exploration, Inc. and Sohio Alaska Petroleum Company. I~f you should have any questions, please do not hesitate to contact .me at 263,4272. Sincerely yours, D. S. Smiley Sr. Drilling Engineer DS S: TJB: 1 tc Enclosures JAN 1 1 198 0il & Gas Cons. Commission Anchorage ARCO Alaska, ~nc. is a subsid)ary of AtlanticRichfieldCompany /(., STATE OF ALASKA ALASK IL AND GAS CONSERVATION ,vIMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL [~ lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHIC [] REDRILL [] DEVELOPMENT OIL DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address P.O. Box 360, Anchorage, Alaska 99510 4. Location of well at surface ~I~ ~' ~, r' I V r, u 9. unit or lease name l169'FSL, 493'FWL, Sec. 5, TllN, RI0E, UM Kuparuk River Field At tOp of proposed producing interval J A N 1 1 198~: 10. Well number 1312'FSL, 1776'FEL, Sec. 5, TllN, RIOE, UM lA-14 At total depth U~J~cjk~[ 0JJ & GaS G0[IS. (~0D][I j~joFrlield and pool 1349'FSL, 986'FEL, Sec. 5, TllN, RIOE, A[ichorage Kuparuk River Field 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. Kuapruk Ri ver 0i 1 Pool 61'GL, 66'PD, 100'RKB ADL 25647 ALK 465 12. Bond information (see ~0 AAC 25.025) Type Statewide Suretvand/°rnumbeFed Ins Co. #8088-26-27 Amount $500~00 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 30 miles NW Deadhorse miles at TD 986' feet lA-13yen is 120' 0 surfacefeet . , 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 8425' HD/6858' TVD feet 2469 1 / 24 / 82 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures ~6Z~ psig@ 6005 Surface KICK OFF POINT 2500 feet. MAXIMUM HOLE ANGLE47' 2° J (see 20 AAC 25.035 (c) (2) 31 53 psig@~ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 24 16" 65# H-40 Welded 80' Pad ~ Pad 114' Ii 114' ~200 CF I 13~ 10-3/4" 45.5# K-55 BTC 2365' Pad i Pad 2400' 12400' 950sx Fondu + 250sx'A 8-3/4 7" 26# K-55 BTC 8390' Pad , Pad 8425' 16858' 1383sx Class "G" I i I I I ~ I 22, Describe proposed program: ARCO Alaska, Inc. proposes to drill a Kuparuk River Field, Kuparuk River Oil Pool devel- opment well to approximately 8425'MD, 6858'.TVD. Selected intervals will be logged~. 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 BOP 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. Expected maximum surface pressure will .be 2642 psig based on cooling of a bubble 'rising at constant volume. The well will be completed With 3½" 9.2# J-55 buttress tubi.ng. Non-freezing fluids will be left in uncemented annuli thru the permafrost interva Selected intervals 'will be perforated within the Kuparuk formation and reported on subsequent report. A downhole safety valve will be installed and tested upon conclusion of job. 23. I hereby certify that the foregoing is true and correct to the best of my knowledge SIGNED ~, TITLESr. Drilling Engineer DATE 1/7/82 The space below for CONDITIONS OF APPROVAL Samples required Mud Icg required Directional Survey required I APl number []YES ,~NO I--lYES ~JO J~YES []NOJ 50- Permit number Approval date O~'b~/0 SEE COVER LETTER FOR OTHER REQUIREMENTS 01/13/82 I / / by order of the Commission ~ _ II Form 10-401 Submit in triplicate Rev. 7-1-80 'TVD~6450 .+ · . % 2- · ' · >2: - a: -- RECEIVED & Gas Cons. CO~ieS;O~ Anchorage F[E~D,, I~ETH SL(~IPF... RI..I:ISI~t- ANTICIPATED PRESSURES Expected reservoir pressure in the Kuparuk interval has been determined to be 3153 psig from RFT & pressure buildup date. This pressure @ 6025' SS = 6125' TVD will be balanced by 9.9 ppg mud wt. Normal drilling practice calls for 10.4 ppg wt prior to penetration and during drilling of the Upper Kuparuk and remaining intervals. This will result in a 159 psi overbalance. It is anticipated the surface BOPE equipment could be subjected to a maximum of 2642 psi during drilling operations. Derivation assumes a gas kick at reservoir temperature and pressure (160OF, 3153 psi), gas migration to the surface w/o expansion, and cooling to 60OF cellar temperature. This is well below the 5000 psig BOPE working pressure and less than the 3000 psi weekly test pressure. Pi = pressure initial (reservoir) Ti TM temperature initial (reservoir) Vi = volume initial (reservoir) Pf = pressure final (surface) Tf = temperature final (surface) Vf = volume final (surface) Pi.Vi = PfV~ Ti Tf Since Vi = Vf ie no expansion Ti Tf Then Pf = PiTf = (3168 psia)(60°F + 460) Ti (160'OF + 460) Pf : 2657 psia = 2642 psig 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. 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 ans circumstances. 16" Conductor JAN 1 i 1982 AJaska 0i~ & Gas toss. Anchorage. .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. 3. Close annular preventer in the event £?~'3-5/8" 5000 PSI RSRRA BOP STAC~r PIPE RRMS 1. 16" Bradenhead 2. 16" 2000 PSI x 10" 3000 PSI casing head 3. 10" 3000 PSI tubing head 4. 10" 3000 PSI x 13-5/8" 5000 PSI adapter spool 5. 13-5/8" 5000 PSI 6. 13-5/8" 5000 PSI and kill lines 7. 13-5/8" 5000 PSI 8. 13-5/8" 5000 PSI 9. 13-5/8" 5000 PSI pipe rams drilling spool w/choke pipe rams bl i nd rams annular ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME THEN CLOSE ALL UNITS SIMULTANE- OUSLY AND RECORD THE TIME AND PRESSURE REMAIN- ING AFTER ALL UNITS ARE CLOSED WITH CHARGING PVMP OFF, 4. RECORD ON IADC REPORT. THE ACCEPTABLE LONER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. 13-5/8" BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RE- TRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. 5. INCREASE PRESSURE TO 1800 PSI AND HOLD FOR lO MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR l0 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST RBtAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. ~ 9. OPEN TOP SET OF PIPE RAMS AND CLOSE BOTTOM SET OF PIPE RAMS. lO. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR l0 MINUTES. BLEED TO ZERO PSI. ll. OPEN BOTTOM SET OF PIPE RAMS. BACK OFF RUN- NING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR lO MINUTES. BLEED TO ZERO PSI. 12. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN DRILLING POSITION. 13. TEST STANDPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOHEY PUMP. 15. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM SIGN AND SEND TO DRILLING SUPER- VISOR. 16. PERFORM C~PLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE Company Lease & Well No. YES NO REMARKS (2,/thru ~) (3) Admin ~./~, f '( (9/thru 11) (4) Casg ~~ //f~/~Z. ' [12 thru 20) (5) BOPE ~ [/IZ/[~ (21 thru' 24~) (6) Add: me 3. 4. 5. 6. 7. 8. e 10. 11. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. Is well located proper diStance from property line ...... Is well located proper distance from other wells ............ Is sufficient undedicated acreage available in this pool .... Is well to be deviated and is well bore plat included ....... Is operator the only affected party ............. ............ Can permit be approved before ten-day wait .................. e e · · · · · · e e e e e e · · · e · · · · · · e e e e · · e e e · e · · · · · 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 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 ....... ~. Does BOPE have sufficient pressure rating - Test to .~O psig ..~ Does the choke manifold comply w/API RP-53 (Feb.78) .................. Additional requirements Additional Remarks: Geology: Engin~$ing: HWK ~. LCS%/C~BEW~, WVA~ JKT ~'- RAD ~ JAL ,, rev: 03/10/81 INIT IAL I GEO. UNIT ON/OFF POOL CLASS STATUS[ AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file, To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIXi .. No 'special'effort has been made to chronologically organize this category of information. ~ .... SCHLUMBERGER----~ bis TAPE VERIFICATION LISTING LVP OlO,HO! VERIFICATION LISTING PAGE ! ** REEL HEADER ~* SERVICE NAME :SERVIC DATE :82t04/12 ORIGIN : REEL NAME :REEL ID CONTINUATION # :O1 PREVIOUS REEL : COMMENTS :REEL COMMENTS ** TAPE HEADER SERVICE NAME :SERVIC DATE :82/04/12 ORIGIN :1070 TAPE NAME :62570 CONTINUATION ~ PREVIOUS TAPE COMMENTS :TAPE COMMENTS ** FILE HEADER FILE NAME :$ERVIC,00i SERVICE NAME VERSION # DATE : MAXIMUM LENGTH : 1024 FILE TYPE PREVIOUS FILE INFORMATION RECORDS ** MNEM CON~ENTS CN : WN FN ~G. RA~ · TOWN: SECT'. COUN: STAT: CTRY: MNEM ATbANTIC RICHFIELD CO, iA-14 KUPARUK lO E 5- N. SLOPE ALASKA USA CONTENTS RECORD TYPE 047 UNIT TYPE CATE SIZE CODE 000 000 022 V65 000 000 006 065 000 000 008 065 000 000 004 065 000 000 004 065 000 000 OOi 065 000 000 008 065 000 000 006 065 000 000 004 065 UNIT TYPE CATE SIZE CODE 000 000 007 065 LVP OlO,HO1 VERIFICATION LISTING PAGE 2 RECORD TYPE 047 ** RECORD TYPE 047 ~* COMMENTS ~* PACIFIC COAST COMPUTING CENTER COMPANY WELL FIELD COUNTY STATE ATLANTIC RICHFIELD CO. 1A-14 KUPARUK N. SLOPE ALASKA JOB # 10707,62570 DIL RUN NO. : ONE LOGGED DATE : 05-FEB-82 CASING DRILLER : 2390 BIT SIZE : 8.75 FLUID TYPE ~ LOW SOLIDS DENS. VISC. : 40 PH ~ 9.0 FLUID LOSS RM ~ MEA$. TEMP. : 3.62 ~ 75 F LVP 010.HOl VERIFICATION LISTING PAGE RMF ~ ~IEAS. TEMP. : 3,84 @ 69 R~4C 9 ,EA$. TE,P. ~ 2.68 @ 61 RM @ BHT ,1'832 9155 ,ATRIX : SANDSTONE F F F ** DATA FORMAT RECORD ENTRY BLOCKS TYPE SIZE 4 l 9 4 0 1 DATUM SPECIFICATION BLOCKS MNEM SERVICE SERVICE UNIT APl ID ORDER # LOG DEPT SFLU OIL IL~ ILD SP DIL GR DIL NPHX NUC RHOB NUC GR NUC CALI NUC DRHO NUC NRAT NUC NCNL NUC FCNL NUC REPR CODE 66 65 66 DATA DEPT GR NCNL 8077.5000 -53 2813 8:7656 228,2500 API APl API FILE TYPE CLASS MOD NO. FT 0 0 0 0 0 OH~ 7 0 0 0 0 OHM~ 7 0 0 0 0 OHMM 7 12 46 0 0 MV 7 1 0 0 0 GAPI 7 31 32 0 0 PU 0 68 2 0 0 G/C3 0 35 I 0 0 GAPI 0 31 32 0 0 I.N 0 28 3 0 0 G/C3 0 44 0 0 0 0 42 I 0 O 0 34 92 0 0 0 34 93 0 0 DEPT SP GR NCNL SFLU 2. GR CAbI 8 FCNL 83, DEPT SP 8000.0000 SFbU 2. 0.3867 GR 11!. 11i.7500 CkbI 9, 2370'0000 FCNL 647. 0547 IbM 656 NPHI 500 DRHO 0000 7900.0000 SFLU -28.2656 GR 106.6875 CALX 1758 Ib~ 7500 NPHI 0938 DRHO 0000 2 ~355 106:875 NPHI 8,9766 DRHO ENTRY 6O ,lin 0 SIZE PROCESS SAMPLE LEVEL 4 0 4 0 4 0 4 0 I 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 2 996~ 2734 RHOB NRAT 2.10!6 41.1133 0.0884 RHOB NRAT 2.8965 305,7422 .0806 IbP RHOB NRAT REPR CODE 68 68 68 68 68 68 68 68 68 68 68 68 68 68 2 4590 -4!2031 2 5234 2 0195 2:4883 3.4160 2 8262 2i4023 3 1094 OlO.HOl VERIFfCATfON [aISTING PAGE 4 NCNb GR NCNb DEPT SP GR NCNb DEPT SP NCN[a DEPT SP NCNb DEPT SP GR NCNb DEPT SP GR NCNb DEPT SP GR NCN[a DEPT SP NCNb DEPT SP GR DEPT SP GR NCNb DEPT $P 2400,0000 FCNL 7800.0000 SFLU -8.4531 GR i03.7500 CALI 2318.0000 FCNL 7700.0000 SFbU '-13.2031 GR 98.0000 CA[al 2398,0000 FCN[a 76.00 0000 SfbU 39:8750 GR 62.2813 CA[al 2688,0000 FCN[a 7500.0000 SF[aU 8 4219 GR 2900.0000 FCN[a 7400.0000 SFLU -38.1875 GR 76.8i25 CALI 2820.0000 FCN[a 7300.0000 SF[aU -37.4063 GR 37,2813 CALI 3478.0000 FCNb 7200.0000 SF[aU 1 . 125 CAbI 1932.0000 FCNL 7100.0000 SFbU -26.3750 GR 122.8750 CA[aI 2078.0000 FCN[a 7000 0000 SFbU 8i2891 GR 149 2500 CA[aI 2070.0000 FCNL 6900.0000 SFDU -88.i875 GR -.999.9000 CA[al 999.9000 FCN[a 6800.0000 SFLU -103.7500 GR 711.0000 1 5O0 9.7734 496.7500 2.5469 98'0000 10.4453 708.0000 36.5313 62.28t3 9.0703 1089.0000 6.3125 70.8125 10.4063 977.5000 7 . 25 9.4844 863.0000 32.9687 37.2813 9.4453 1260.0000 1.9053 i 5000 406.7500 2,3398 122.8750 10.~563 468. 500 3.0215 149.2500 11,2578 621.0000 4 2070 222:7500 -999.9000 -999'9000 3.4121 158.1250 IbM NPHI DRHO IbM NPHI DRHO IbM NPH! DRHO IbM NPHI DRHO NPHI DRHO IbM NPHI DRBO IbM NPHI DRHO IbM NPHI DRHO NPHI DRHO IbM NPHI DRHO NPHI 1.8818 46,7773 RBOB 0.0835 NRAT 2,6855 IbP 36'0352 RHOB -0.0020 NRAT I4.1328 25,7324 0.0244 NRAT 5.6055 I.L~B 28.7109 RH 0.0020 NRAT 7.2070 ILD 30.4688 RHDB 0.0493 NRAT .4688 ILD '8789 RHOB 0.0918 NRAT 1,7402 ILD 4~.5352 RHOB .0405 NRAT 2.2695 IbP: 51,5137 RHOS 0.0522 NRAT 2.7480 7I NRAT 9000 HOB =999,9000 NRAT 3.I777 -999,9000 RHOB 9014 4238 7891 18 3.2461 14 3438 5020 i3828 3633 2 8105 0703 8516 323 3750 2,5430 1,7109 2,3574 3.9453 .2578 .3516 4.1211 2 6836 .4316 3.2129 2999.9000 999,9000 3 1621 -999:9000 LVP 010.H01 VERIFICATION LISTING OR -999.9000 CAb! -999. NCNb '999,9000 FCNb -999. ozP 7oo oooo sruu sP -133:25oo OR il : NCNL -999; 9000 FCNb 99. DEPT 6600.0000 SFDU 3. SP -105.7500 GR 110, GR -999.9000 CAbI -999. NCNb -999.9000 FCNb -999, DEPT 6500.0000 SFbU 1. SP -57.0625 GR I64, GR -999.9000 CAbI -999, NCNb -999'9000 FCNb -999. DEPT 6_300.0000 SFLU 3 $P -49'1250 GR 126: NCNb -999.9000 FCNb '9 9;9 DEP~ ,~200.0000 SrbU 3. SP 106.4375 GR .12~ GR -999 9000 CAbI 99 : NCNb -999:9000 FCNb -999, DEPT 6100.0000 SFLU 1. SP -91.2500 GR 158' GR -999,9000 CAbI -999, NCNb -999.9000 FCNL -999. DEPT 6000 0000 SFLU 4 $P -56:3125 GR 195: GR -999.9000 CALI -999 NCNb -999. 9000 FCNb -999 DEPT 5800. 0000 $FLU 2. $P -72.6250 GR 130. GR -999. 9000 CAGI -999: NCNb -999. 9000 FCNh -999. DEPT 5700.0000 SFLO 2. 9000 9000 211 875 9000 9000 9355 1250 9000 9000 7754 5000 9000 90OO 3984 7500 9OO0 9000 2832 7500 9000 9000 5156 3750 9000 9000 4014 7500 9000 90O0 3477 7500 9000 9000 324 750 9000 900O 8379 0000 9000 9000 8184 DRHO IbM NPHI DRHO IbM NPHI DRHO IbM NPHI DRHO IbM NPHI DRHO IbM NPHI DRHO IbM NPHI DRHO IbM NPHI DRHO IbM NPHI DRHO NPHI DRHO IbM NPHI DRHO IbM -999,9000 NRAT · ,6 1 ..9993o,~0~6 RHOB 999.9000 NRAT 3.9277 -999.~000 RHOB -999.9000 NRAT 1.9854 :999,9000 RHOB 999,9000 NRAT 2.2422 IbP :999o9000 RHOB 999.9000 NRAT 1426 IbD . 3.2734 IbD 999.9000 RHOB -999.9000 NRAT 1.3877 -999.9000 RHOB -999.9000 NRAT 2 8105 ILD -999i9000 RHOB -999 9000 NRAT I 5850 IUD -999:90,00 RHOB -999.9000 NRAT 2.,1113 IbD -999,9000 RHOB -999.9000 NRAT 2.7344 IUD PAGE -999.9000 3 1602 :999i9000 999 9OO0 4.0508 -999.9000 -999.9000 ! 9463 999.9000 2 1953 999i9000 :999 9000 3 1328 :999i9000 999 9O0O 3.2910 -999.9000 -999.9000 I 4092 -999i9000 -999 9000 2 7578 =999:9000 -999.9000 1 5146 -999:9000 -999.9000 2.1719 999 9000 2.9746 LYP OlO,HOi VERfFfCATfON LISTfNG PAGE 6 SP -33.8437 GR GR -999.9000 CALl NCNb -999.9000 FCNL DEPT 5600.0000 SFLU SP -63.1562 GR GR ~999,9000 CALf NCNL 999.9000 FCNL DEPT 5500.0000 SFLU ' 86.~375 GR SP ;99 000 CALf GR - · NCNL -999.9000 FCNL DEPT 5400.0000 SFLU Sp -88.6250 GR GR -999 9000 CALl NCNL -999:9000 FCNL DEPT 5~00.0000 SFLU Sp 99,3750 GR GR -999,9000 CALf NCNL -999.9000 FCNL DEPT 52.00 0000 SFLU Sp 79".3750 GR GR -999 9ooo CALf NCNL -999:9000 FCNL DEPT 5100,0000 SFLU 9000 CALf NCNL -999 9000 FCNL DEPT 5000.0000 SFLU 09 2500 Ga NCNL -999.9000 FCNL DEPT 4900.0000 SFLU Sp t124 8i25 GR GR -999:9000 CALf NCNL -999.9000 FCNL DEPT 48.00 0000 SFLU Sp 41:9687 GR GR -999.9000 CALl NCNL -999.9000 FCNL DEPT 4700.0000 SFLU SP -44.6563 GR GR ~999.9000 CALI NCNL 999,9000 FCNL 159.2500 -999.9000 -999.9000 2.4727 90.2500 -999.9000 -999.9000 2.1094 132.5000 -999.9000 -999.9000 2.0527 96.3750 -999.9000 -999.9000 2.4063 77.8750 -999 9000 3.0840 70.0000 -999.9000 -999.9000 2.7168 80.2500 -999.9000 -999.9000 2.4082 102.4375 -999.9000 -999.9000 2.6855 97 0625 -999i9000 -999 9000 2.6055 89.8i25 -999.9000 -999.9000 2.1367 102 8750 -999:9000 -999.9000 NPHI DRHO NPHI DRHO IL~ NPHI DRHO NPHI DRHO ILM NPHI DRHO NPHI DRHO NPHI DRHO IbM NPHI DRHO IbM NPHI DRHO IbM NPHI DRHO NPHZ DRHO -999.9000 RHOB -999.9000 NRAT 2.5254 IbD -999.9000 RHOB -999.9000 NRAT 2.2109 -999,9000 RHOB -999.9000 NRAT 2.3457 ZLD -999.9000 RHOB -999.9000 NRAT 9~' 6504 -9 .9000 RHOB -999.9000 NRAT 3.0605 -.999,9000 RHOB 999.9000 NRAT 8828 IGD -9992!9000 RHOB -999 9000 NRAT . 2.5703 ILP 999.9000 RHOB -999.9000 NRAT 2,7871. -999,9000 RHOB -999.9000 NRAT 2 ,7480 -.999i9000 RHOB 999 9000 NRAT 2.5488 -999.9000 RHOB '999.9000 -999 9000 -9 9: ooo 2 5508 -999:9000 -999.9000 .99~ ,2715 .9000 -999.9000 2 3730 -999!9000 -999 9000 2 7i88 -999!900O -999 9000 3 1074 -999i9000 -999 9000 9375 -9929!9000 -999 9000 2 6465 -999.9000 . 2i8711 999 9000 -999 9000 2 8945 -999:9000 -999.9000 2.6602 '999,9000 -999,9000 LYP DEPT SP GR NCNb DEPT SP NCNb DEPT SP GR NCNb DEPT SP NCNb DEPT SP NCNb DEPT SP GR NCNb DEPT SP GR NCNb DEPT GR NCNb DEPT SP GR NCNb DEPT SP GR NCNb DEPT SP GR NCNb OlO.HOl VERIFICATION 4600.0000 SFLU -45,2500 GR -999,9000 CAbI -999,9000 FCNb ! io!oooo 7 1562 GR -99~ 9000 CALl 9000 FCNL 4400,0000 SFLU -b2,1250 GR -999.9000 CAbI -999.9000 FCNb 4300 0000 SFbU 2187 --39 GR 999 9000 CALI -999 9000 FCNb 4200,0000 SFLU .-24,9219 GR ooo F¢ 4100 0000 SFbU -53:4063 GR -999,9000 CALl -999,9000 FCNb 4000.0000 SFbO ;17,8906 GR 00.i250 CADI 2194,0000 FCNb 3.904~.0000 SFLU - ,1562 GR 76 5625 CALI 2394:0000 FCNL 3800.0000 SFLU -43 4063 GR 71:3125 CAbI 2396,0000 FCNL 3700 -55 89 2356 0000 SFLU 6563 GR 000 FCNL 3600.0000 -b3.4137§ 67. 875 2498,0000 SFbU CAI~I FCNb 3,8906 - . O0 -999,9000 2,6699 64,~875 -999, 000 -999,~000 2.4238 103.9375 -999,9000 -999,9000 2,8516 98,7500 -999 ~000 -999; 000 2.1719 110.1250 -999 90OO -999,"9000 3,~727 I02. 625 -999,9000 '999.9000 3 2441 1oo:12so i4,2578 565,0000 4,4570 75,5625 12.5078 592,5000 3.7051 5~ 3.32 B,5000 4,1055 89.1875 12.8516 591,0000 6, 33 7.1 75 12.7734 633.0000 IbM NPHI DRHO NPHI DRHO IbM NPHI DRHO IbM NPHI DRHO IbM NPHI DRHO NPHI DRHO NPHI DRHO NPHI DRHO ibm NPHI DRHO IbM NPHI DRHO ~PHI DRHO 4,2500 -999,9000 ~HOB -999,9000 RAT 2.8848 IbD -999,9000 RHOB -999,9000 NRAT 2,746I IbP -999 9000 RHOB -999',9000 NRAT 3,4063 IbD '999,9000 RHOB '999,9000 NRAT . . 2,4141 IbP 999,9000 RHDB -999'9'000 NRAT 4 -999 -999 g469 IbD :000 RHOB 9.000 NRAT 3.5840 36.5723 RHOB 0.0352 NRAT 4 7617 ILD 41:4063 RHOB 0,0112 NRAT 3,8730 ILD 42 ? 246 RHOB 0:0151 NRAT 4 6289 IbP 43:0664 RHOB 0,0093 NRAT 6.5742 41,6504 RHOB -0,0044 NRAT PAGE 4.7227. 999.9ooo 999,9000 3 0586 -999:9000 -999,9000 2 9O23 -999:9000 -999.9000 3.6035 -999,9000 -999.9000 2.6484 -999 9000 -999:9000 4.2539 ooo :9ooo 3 7637 2!2734 3 3887 4.9961 2.2480 3.6113 4.3008 2,1934 3.7070 4,8867 2.1660 3,7148 .8320 1582 3 ' 6309 . DEPT 3500.0000 SFLU SP --80.5000 GR GR 63.8437 CALI NCNb 2364.0000 FCNL DEPT 3400.0000 SFLU Sp -i05.8750 GR GR 63.3438 CALf NCNL 2178.0000 FCNL DEPT 3300 0000 SFLU Sp -64:6875 GR GR 81.9375 CALL NCNb 2344.0000 FCNL DEPT 3200,0000 SFLU Sp -88 ~875 ~R G~ 372 562 CAL~ NCNb 2422,0000 FCNL DEPT 3~00 0000 SFLU Sp 99:4375 GR GR 57.3438 CALf NCNb 2500.0000 FCNL DEPT 3000.0000 SFLU SP -86 9375 GR GR 50:5000 CALf NCNb 2386.0000 FCNL DEPT 29. OO 0000 SFbU Sp 72',6875 GR GR 34,2187 CALf NCNb 2626.0000 FCNL DEPT 2800.0000 SFLU SP -89 3750 GR GR 37:8125 CALf NCNb 2043.0000 FCNL DEPT 2700.0000 SFLU Sp ~35.8750 GR GR b0.2500 CALf NCNb 2 29.0000 FCNL DEPT 2600.0000 SFLU Sp -65.6875 GR GR 45.6250 CALI NCNb 1810,0000 FCNL DEPT 2~00.0000 SFLU Sp 76.0000 GR GR 42.4688 CALL 5,9258 63.8437 12,1250 599,0000 9.9219 63 3438 604.0000 7,1328 81.9375 13.2187 610.5000 10.1875 37,1562 10,8906 619,5000 12 5859 10,0000 599.5000 ll.5938 50.5000 10.7734 621.5000 16,7813 34.2187 10,0938 730.500O 18,0469 37,8125 10,8906 451,2500 9.0938 60,2500 13 500 11,1953 45,6250 12.7344 515,0000 13.0625 42.4688 15.4219 IbM NPHI DRHQ IbM NPHI DRHO IbM NPHI DRHO IbM NPH! DRHO NPHI DRHO NPHI DRHO IbM NPHI DRHO IbM NPHI DRHO NPHI DRMO IbM NPHI DRHO IbM NPHI DRHO 8.5469 43.0176 RHOB -0.0137 NRAT 10.0078 ILL 37.3047 RHOB 0.0176 NRAT 8.0313 IL~B 39.7461 RH 0.0352 NRAT 9.8594 IbP 41 0645 RHOB -0:0063 NRAT !2.0469 ~1.5527 0.0034 NRAT 1~.~875 39.6484 RHOB -0.0073 NRAT 13,6641 IbD ~9.0137 RHOB ,0.0073 NRAT 20.5469 IbD 46.4844 RHOB 0.0024 NRAT 4570 RH -0.0039 NRAT 11,7344 37,4023 RHOB 0,0308 NRAT 1.3,8281 ILL 44.7754 RHOB 0.0425 NRAT 3,6914 10.8437 . 809 6563 3,5391 10 2187 2i0918 3 5508 1562 3,5156 6641 3.4668 1~,2109 0879 3,3828 2[.7344 ].9805 .8516 ,3203 ,I191 3,7402 i~.3125 .3047 3.3965 9219 3.8750 LVP OlO,MO1 YERIFICATiON LISTING NCNL 1515.0000 FCNL 384.5000 DEPT 2400,0000 SFLU SP -78,1875 GR GR 45.8750 CALI NCNL 1512,0000 FCNL 12.4297 45 8750 13:7578 336.7500 NPHI DRHO DEPT 2380,0000 SFLU SP -107.4375 GR GR 28.3438 CALf NCNL 1406,O000 FCNL 4.8789 28.3438 10.2734 328.0000 NPHI DRHO ** FILE TRA~ER ** FILE NAME :SERVIC.001 SERVICE NAME : VERSION # : DATE : MAXIMUM LENGTH : I024 FILE TYPE : NEXT FILE NAME : *$ TAPE TRAILER $* SERVICE NAME :$ER¥IC DATE :82/o4/12 ORIGIN :1070 TAPE NAME :62570 CONTINUATION ~ :0! NEXT TAPE NAME : COMMENTS :TAPE COMMENTS $$ REEL TRAILER $* SERVICE NAME :$ERVIC DATE 18~/04/12 ORIGIN : RE~L NAME oIREE5 SD CO TINUATI N # :01 NEXT REEL NAME : COMMENTS :REEL COMMENTS EOF EOF 13.0234 0088 8.7344 38.I348 -0,5776 RHO8 NRAT RHOB NRAT PAGE 19 1719 2i1250 4'2O7O 445 5000 li8809 3 3496