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Home My WebLink About184-106CAUTION: 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: AOGCC Notification: KRU 2G-10 (PTD 184-106) Date:Tuesday, July 1, 2025 11:22:56 AM Attachments:AnnComm Surveillance TIO for 2G-10.pdf From: Bronga, Jaime <Jaime.Bronga@conocophillips.com> Sent: Tuesday, July 1, 2025 11:20 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Automation, AK Wells <akwellsautomation@conocophillips.com>; Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: AOGCC Notification: KRU 2G-10 (PTD 184-106) Well Name: 2G-10 Facility: CFP2 PTD: 184-106 Well Type: Inj AA Number (if applicable): AIO 2B.030 Internal Waiver (Yes/No if applicable): Type of Issue: Plan Forward Maximum Pressure (if applicable): Date of Occurrence (if applicable): 5/25/25 Hi Chris, CPAI reported KRU 2G-10 (PTD 184-106) to the AOGCC on May 27, 2025 for a low IA fluid level. 2G-10 is a water injector currently on produce water injection and is a waivered well (AIO 2B.030) for TxIA on gas injection, water only. In 2024 a production casing leak was repaired with Seal-tite and CPAI has been monitoring the integrity of the IA using fluid level shots. The low fluid level reported on May 27, 2025 was an indication of an issue. CPAI started the diagnostics on the integrity of the IA by confirming the fluid level shot by bleeding pressure off the IA. Fluid was found at surface. CPAI discussed the results of the initial IA FL shot and determined those results were inaccurate. We confirmed the FL in the IA after 30 and confirmed it remains at surface. This concludes our monitoring of 2G-10 for this issue. Please, let me know if you have any questions or disagree with this plan. Warmest regards, Jaime Bronga Well Integrity – CPF2 – ConocoPhillips Alaska Cell: 907-229-8282 2G-10 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 2G-10 2025-05-18 720 1000 280 IA Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 6,744.0 2G-10 2/21/2016 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled plug 2G-10 9/4/2024 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 10/20/201 0 ninam NOTE: WAIVERED WELL T x IA COMMUNICATION, WI ONLY 5/8/2008 lmosbor 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 37.0 116.0 116.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 37.2 2,796.0 2,796.0 36.00 J-55 BTC PRODUCTION 7 6.28 34.6 6,864.3 6,303.6 26.00 J-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 32.0 Set Depth … 6,540.3 Set Depth … 6,060.5 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE8rd ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 32.0 32.0 0.03 HANGER 8.000 GRAY TUBING HANGER 3.500 1,900.6 1,900.6 0.23 SAFETY VLV 5.937 BAKER FVL SAFETY VALVE BAKER FVL 2.810 1,949.6 1,949.6 0.19 GAS LIFT 5.312 MMH/3.5 x 1 MMH FMHO 2.867 3,388.9 3,388.9 1.86 GAS LIFT 5.312 MMH/3.5 x 1 MMH FMHO 2.867 4,576.8 4,535.1 25.26 GAS LIFT 5.312 MMH/3.5 x 1 MMH FMHO 2.867 5,720.7 5,452.5 43.44 GAS LIFT 5.312 MMH/3.5 x 1 MMH FMHO 2.867 6,453.7 5,995.5 41.31 GAS LIFT 5.312 MMH/3.5 x 1 MMH FMHO 2.867 6,497.1 6,028.1 41.37 PBR 5.000 BAKER PBR BAKER 3.000 6,510.8 6,038.4 41.40 PACKER 5.968 BAKER FHL PACKER BAKER FHL 2.937 6,527.9 6,051.2 41.44 NIPPLE 4.540 CAMCO D NIPPLE NO GO CAMCO D 2.750 6,539.5 6,059.9 41.47 SOS 4.500 BAKER SHEAR OUT SUB, ELMD TTL @ 6538' during OTIS FLUID LD LOG on 01/14/85 BAKER 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 6,683.0 6,167.3 41.48 FISH 1" DMY w/ bent latch Lost in Rathole 11/6/1985 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on N o/Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 1,949.6 1,949.6 0.19 1 INJ DMY BK2 1 0.0 10/28/1984 0.000 3,388.9 3,388.9 1.86 2 INJ DMY BK2 1 0.0 11/6/1985 0.000 4,576.8 4,535.1 25.26 3 INJ DMY BK2 1 0.0 10/28/1984 0.000 5,720.7 5,452.5 43.44 4 INJ DMY BK 1 6/22/2024 6,453.7 5,995.5 41.31 5 INJ DMY BK 1 7/17/2024 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,612.0 6,629.0 6,114.1 6,126.9 A-5, 2G-10 10/28/1984 4.0 IPERF 90 deg. Ph; 4" Schlumberger Csg 6,646.0 6,684.0 6,139.6 6,168.0 A-4, 2G-10 10/28/1984 4.0 IPERF 90 deg. Ph; 4" Schlumberger Csg 2G-10, 9/6/2024 7:59:13 AM Vertical schematic (actual) PRODUCTION; 34.6-6,864.3 FLOAT SHOE; 6,862.4-6,864.3 FLOAT COLLAR; 6,781.8- 6,783.5 FISH; 6,683.0 IPERF; 6,646.0-6,684.0 IPERF; 6,612.0-6,629.0 SOS; 6,539.5 NIPPLE; 6,527.9 PACKER; 6,510.8 PBR; 6,497.1 GAS LIFT; 6,453.7 GAS LIFT; 5,720.7 GAS LIFT; 4,576.8 GAS LIFT; 3,388.9 SURFACE; 37.2-2,796.0 FLOAT SHOE; 2,794.0-2,796.0 FLOAT COLLAR; 2,715.5- 2,717.4 GAS LIFT; 1,949.6 SAFETY VLV; 1,900.6 CONDUCTOR; 37.0-116.0 HANGER; 37.2-41.4 HANGER; 32.0 KUP INJ KB-Grd (ft) 40.98 RR Date 9/9/1984 Other Elev… 2G-10 ... TD Act Btm (ftKB) 6,897.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292114000 Wellbore Status INJ Max Angle & MD Incl (°) 43.48 MD (ftKB) 5,700.00 WELLNAME WELLBORE2G-10 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: TRDP CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: AOGCC Notification: KRU 2G-10 (PTD 184-106) Date:Monday, June 2, 2025 2:32:49 PM Attachments:AnnComm Surveillance TIO for 2G-10.pdf From: Bronga, Jaime <Jaime.Bronga@conocophillips.com> Sent: Monday, June 2, 2025 1:11 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Automation, AK Wells <akwellsautomation@conocophillips.com>; Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: AOGCC Notification: KRU 2G-10 (PTD 184-106) Well Name: 2G-10 Facility: CFP2 PTD: 184-106 Well Type: Inj AA Number (if applicable): AIO 2B.030 Internal Waiver (Yes/No if applicable): Type of Issue: Plan Forward Maximum Pressure (if applicable): Date of Occurrence (if applicable): 5/25/25 Hi Chris, CPAI reported KRU 2G-10 (PTD 184-106) to the AOGCC on May 27, 2025 for a low IA fluid level. 2G-10 is a water injector currently on produce water injection and is a waivered well (AIO 2B.030) for TxIA on gas injection, water only. In 2024 a production casing leak was repaired with Seal-tite and CPAI has been monitoring the integrity of the IA using fluid level shots. The low fluid level reported on May 27, 2025 was an indication of an issue. CPAI started the diagnostics on the integrity of the IA by confirming the fluid level shot by bleeding pressure off the IA. Fluid was found at surface. CPAI discussed the results of the initial IA FL shot and determined those results were inaccurate. We will continue to monitor the FL in the IA and confirm it remains at surface in the next 30 days. Depending on results, proper notifications will be made as needed. Attached is the 90-day TIO plot and wellbore schematic. Please, let me know if you have any questions or disagree with this plan. Warmest regards, Jaime Bronga Well Integrity – CPF2 – ConocoPhillips Alaska Cell: 907-229-8282 2G-10 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 2G-10 2025-05-18 720 1000 280 IA Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 6,744.0 2G-10 2/21/2016 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled plug 2G-10 9/4/2024 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 10/20/201 0 ninam NOTE: WAIVERED WELL T x IA COMMUNICATION, WI ONLY 5/8/2008 lmosbor 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 37.0 116.0 116.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 37.2 2,796.0 2,796.0 36.00 J-55 BTC PRODUCTION 7 6.28 34.6 6,864.3 6,303.6 26.00 J-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 32.0 Set Depth … 6,540.3 Set Depth … 6,060.5 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE8rd ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 32.0 32.0 0.03 HANGER 8.000 GRAY TUBING HANGER 3.500 1,900.6 1,900.6 0.23 SAFETY VLV 5.937 BAKER FVL SAFETY VALVE BAKER FVL 2.810 1,949.6 1,949.6 0.19 GAS LIFT 5.312 MMH/3.5 x 1 MMH FMHO 2.867 3,388.9 3,388.9 1.86 GAS LIFT 5.312 MMH/3.5 x 1 MMH FMHO 2.867 4,576.8 4,535.1 25.26 GAS LIFT 5.312 MMH/3.5 x 1 MMH FMHO 2.867 5,720.7 5,452.5 43.44 GAS LIFT 5.312 MMH/3.5 x 1 MMH FMHO 2.867 6,453.7 5,995.5 41.31 GAS LIFT 5.312 MMH/3.5 x 1 MMH FMHO 2.867 6,497.1 6,028.1 41.37 PBR 5.000 BAKER PBR BAKER 3.000 6,510.8 6,038.4 41.40 PACKER 5.968 BAKER FHL PACKER BAKER FHL 2.937 6,527.9 6,051.2 41.44 NIPPLE 4.540 CAMCO D NIPPLE NO GO CAMCO D 2.750 6,539.5 6,059.9 41.47 SOS 4.500 BAKER SHEAR OUT SUB, ELMD TTL @ 6538' during OTIS FLUID LD LOG on 01/14/85 BAKER 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 6,683.0 6,167.3 41.48 FISH 1" DMY w/ bent latch Lost in Rathole 11/6/1985 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on N o/Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 1,949.6 1,949.6 0.19 1 INJ DMY BK2 1 0.0 10/28/1984 0.000 3,388.9 3,388.9 1.86 2 INJ DMY BK2 1 0.0 11/6/1985 0.000 4,576.8 4,535.1 25.26 3 INJ DMY BK2 1 0.0 10/28/1984 0.000 5,720.7 5,452.5 43.44 4 INJ DMY BK 1 6/22/2024 6,453.7 5,995.5 41.31 5 INJ DMY BK 1 7/17/2024 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,612.0 6,629.0 6,114.1 6,126.9 A-5, 2G-10 10/28/1984 4.0 IPERF 90 deg. Ph; 4" Schlumberger Csg 6,646.0 6,684.0 6,139.6 6,168.0 A-4, 2G-10 10/28/1984 4.0 IPERF 90 deg. Ph; 4" Schlumberger Csg 2G-10, 9/6/2024 7:59:13 AM Vertical schematic (actual) PRODUCTION; 34.6-6,864.3 FLOAT SHOE; 6,862.4-6,864.3 FLOAT COLLAR; 6,781.8- 6,783.5 FISH; 6,683.0 IPERF; 6,646.0-6,684.0 IPERF; 6,612.0-6,629.0 SOS; 6,539.5 NIPPLE; 6,527.9 PACKER; 6,510.8 PBR; 6,497.1 GAS LIFT; 6,453.7 GAS LIFT; 5,720.7 GAS LIFT; 4,576.8 GAS LIFT; 3,388.9 SURFACE; 37.2-2,796.0 FLOAT SHOE; 2,794.0-2,796.0 FLOAT COLLAR; 2,715.5- 2,717.4 GAS LIFT; 1,949.6 SAFETY VLV; 1,900.6 CONDUCTOR; 37.0-116.0 HANGER; 37.2-41.4 HANGER; 32.0 KUP INJ KB-Grd (ft) 40.98 RR Date 9/9/1984 Other Elev… 2G-10 ... TD Act Btm (ftKB) 6,897.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292114000 Wellbore Status INJ Max Angle & MD Incl (°) 43.48 MD (ftKB) 5,700.00 WELLNAME WELLBORE2G-10 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: TRDP CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: AOGCC Notification KRU 2G-10 (PTD 184-106) Date:Wednesday, May 28, 2025 12:00:20 PM Attachments:image001.png AnnComm Surveillance TIO for 2G-10.pdf From: Shulman, Mark <Mark.Shulman@conocophillips.com> Sent: Tuesday, May 27, 2025 4:46 PM To: Automation, AK Wells <akwellsautomation@conocophillips.com>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: NSK Wells Integrity Eng CPF2 <n2549@conocophillips.com>; Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; Conklin, Amy A <Amy.A.Conklin@conocophillips.com>; Taylor, Jenna <Jenna.L.Taylor@conocophillips.com> Subject: AOGCC Notification KRU 2G-10 (PTD 184-106) Well Name: 2G-10 Facility: CPF2 PTD: 184-106 Well Type: Injector AA Number (if applicable): AIO 2B.030 Internal Waiver (Yes/No if applicable): Type of Issue: IA fluid level drop. Maximum Pressure (if applicable): N/A Date of Occurrence (if applicable): 5/25/25 Chris, KRU 2G-10 (PTD 184-106) is a water injector currently on produce water injection and isa waivered well AIO 2B.030. On 5/25/25, DHD shot an IA fluid level and found that the IA dropped ~780’. 2G-10 was treated with Seal-tite on 7/19/24 and passed a SW MIT-IA to 3,300 psi on 10/7/24. CPAI plans on completing Initial diagnostics and putting the well on a 30-day monitor. Depending on results, proper notifications will be made as needed. Attached is the 90-day TIO plot and wellbore schematic. Please, let me know if you have any questions or disagree with this plan. Thanks, Mark Mark Shulman WNS Sr. Well Integrity Engineer ConocoPhillips Alaska Mark.Shulman@conocophillips.com Office (907) 263-3782 Mobile (602) 513-0775 2G-10 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 2G-10 2025-05-18 720 1000 280 IA Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 6,744.0 2G-10 2/21/2016 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled plug 2G-10 9/4/2024 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 10/20/201 0 ninam NOTE: WAIVERED WELL T x IA COMMUNICATION, WI ONLY 5/8/2008 lmosbor 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 37.0 116.0 116.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 37.2 2,796.0 2,796.0 36.00 J-55 BTC PRODUCTION 7 6.28 34.6 6,864.3 6,303.6 26.00 J-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 32.0 Set Depth … 6,540.3 Set Depth … 6,060.5 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE8rd ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 32.0 32.0 0.03 HANGER 8.000 GRAY TUBING HANGER 3.500 1,900.6 1,900.6 0.23 SAFETY VLV 5.937 BAKER FVL SAFETY VALVE BAKER FVL 2.810 1,949.6 1,949.6 0.19 GAS LIFT 5.312 MMH/3.5 x 1 MMH FMHO 2.867 3,388.9 3,388.9 1.86 GAS LIFT 5.312 MMH/3.5 x 1 MMH FMHO 2.867 4,576.8 4,535.1 25.26 GAS LIFT 5.312 MMH/3.5 x 1 MMH FMHO 2.867 5,720.7 5,452.5 43.44 GAS LIFT 5.312 MMH/3.5 x 1 MMH FMHO 2.867 6,453.7 5,995.5 41.31 GAS LIFT 5.312 MMH/3.5 x 1 MMH FMHO 2.867 6,497.1 6,028.1 41.37 PBR 5.000 BAKER PBR BAKER 3.000 6,510.8 6,038.4 41.40 PACKER 5.968 BAKER FHL PACKER BAKER FHL 2.937 6,527.9 6,051.2 41.44 NIPPLE 4.540 CAMCO D NIPPLE NO GO CAMCO D 2.750 6,539.5 6,059.9 41.47 SOS 4.500 BAKER SHEAR OUT SUB, ELMD TTL @ 6538' during OTIS FLUID LD LOG on 01/14/85 BAKER 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 6,683.0 6,167.3 41.48 FISH 1" DMY w/ bent latch Lost in Rathole 11/6/1985 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on N o/Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 1,949.6 1,949.6 0.19 1 INJ DMY BK2 1 0.0 10/28/1984 0.000 3,388.9 3,388.9 1.86 2 INJ DMY BK2 1 0.0 11/6/1985 0.000 4,576.8 4,535.1 25.26 3 INJ DMY BK2 1 0.0 10/28/1984 0.000 5,720.7 5,452.5 43.44 4 INJ DMY BK 1 6/22/2024 6,453.7 5,995.5 41.31 5 INJ DMY BK 1 7/17/2024 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,612.0 6,629.0 6,114.1 6,126.9 A-5, 2G-10 10/28/1984 4.0 IPERF 90 deg. Ph; 4" Schlumberger Csg 6,646.0 6,684.0 6,139.6 6,168.0 A-4, 2G-10 10/28/1984 4.0 IPERF 90 deg. Ph; 4" Schlumberger Csg 2G-10, 9/6/2024 7:59:13 AM Vertical schematic (actual) PRODUCTION; 34.6-6,864.3 FLOAT SHOE; 6,862.4-6,864.3 FLOAT COLLAR; 6,781.8- 6,783.5 FISH; 6,683.0 IPERF; 6,646.0-6,684.0 IPERF; 6,612.0-6,629.0 SOS; 6,539.5 NIPPLE; 6,527.9 PACKER; 6,510.8 PBR; 6,497.1 GAS LIFT; 6,453.7 GAS LIFT; 5,720.7 GAS LIFT; 4,576.8 GAS LIFT; 3,388.9 SURFACE; 37.2-2,796.0 FLOAT SHOE; 2,794.0-2,796.0 FLOAT COLLAR; 2,715.5- 2,717.4 GAS LIFT; 1,949.6 SAFETY VLV; 1,900.6 CONDUCTOR; 37.0-116.0 HANGER; 37.2-41.4 HANGER; 32.0 KUP INJ KB-Grd (ft) 40.98 RR Date 9/9/1984 Other Elev… 2G-10 ... TD Act Btm (ftKB) 6,897.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292114000 Wellbore Status INJ Max Angle & MD Incl (°) 43.48 MD (ftKB) 5,700.00 WELLNAME WELLBORE2G-10 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: TRDP MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, December 6, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2G-10 KUPARUK RIV UNIT 2G-10 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 12/06/2024 2G-10 50-029-21140-00-00 184-106-0 W SPT 6038 1841060 1510 2695 2705 2693 2705 645 872 857 842 OTHER P Sully Sullivan 10/7/2024 MIT-IA post seal tite repair per sundry #324-244, tested to 3300 psi for dp 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 2G-10 Inspection Date: Tubing OA Packer Depth 1150 3300 3190 3190IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS241009141548 BBL Pumped:1.5 BBL Returned:1.5 Friday, December 6, 2024 Page 1 of 1 9 9 9 9 9 9 9 99 999 99 9 9 9 sundry #324-244 James B. Regg Digitally signed by James B. Regg Date: 2024.12.06 11:32:19 -09'00' Originated: Delivered to:9ͲOctͲ24Halliburton Alaska Oil and Gas Conservation Comm.Wireline & PerforatingAttn.:Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska99501Anchorage, Alaska 99518Office: 907Ͳ275Ͳ2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#12AͲ04 50Ͳ103Ͳ20026Ͳ00 909593518 Kuparuk River Plug Setting Record FieldͲFinal 29ͲSepͲ24 0 122AͲ05 50Ͳ103Ͳ20030Ͳ00 909524907 Kuparuk River Plug Setting Record FieldͲFinal30ͲAugͲ24 0 132AͲ11 50Ͳ103Ͳ20057Ͳ00 909594128 Kuparuk River Multi Finger CaliperField & Processed 4ͲOctͲ24 0 142AͲ12 50Ͳ103Ͳ20058Ͳ00 909524545 Kuparuk River Multi Finger CaliperField & Processed 22ͲAugͲ24 0 152AͲ12 50Ͳ103Ͳ20058Ͳ00 909524545 Kuparuk River Packer Setting Record FieldͲFinal 24ͲAugͲ24 0 162GͲ10 50Ͳ029Ͳ21140Ͳ00 n/a Kuparuk River Multi Finger CaliperField & Processed 23ͲAugͲ24 0 172MͲ07 50Ͳ103Ͳ20178Ͳ00 ALSL765Ͳ008 Kuparuk River Multi Finger CaliperField & Processed 15ͲSepͲ24 0 182NͲ329 50Ͳ103Ͳ20257Ͳ00 909593520 Kuparuk River Packer Setting Record FieldͲFinal 20ͲSepͲ24 0 192ZͲ10 50Ͳ029Ͳ21378Ͳ00 909593519 Kuparuk River Multi Finger CaliperField & Processed 25ͲSepͲ24 0 110 3IͲ09 50Ͳ029Ͳ21561Ͳ00 909619414 Kuparuk River Leak Detect Log FieldͲFinal 5ͲOctͲ24 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:T39689T39690T39691T39692T39692T39693T39694T39695T39696184-053184-067186-003186-004184-106192-080198-067185-137186-055T3969710/21/2024Gavin GluyasDigitally signed by Gavin Gluyas Date: 2024.10.21 10:49:24 -08'00'2GͲ1050Ͳ029Ͳ21140Ͳ00 n/aKuparukRiverMultiFingerCaliperField&Processed23ͲAugͲ2401T39693186 004184-106192 080 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Seal-Tite Repair Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 6897' feet None feet true vertical 6328' feet 6683' feet Effective Depth measured 6744'feet 6511' feet true vertical 6213' feet 6038' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" J-55 6540' MD 6060' TVD Packers and SSSV (type, measured and true vertical depth) 6511' MD N/A 6038' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Kuparuk River Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 2796' 2796' Burst Collapse Production Liner 6830' Casing 6304'6864' 2759' 116'Conductor Surface Intermediate 16" 9-5/8" 79' measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 184-106 50-029-21140-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025667 Kuparuk River Field/ Kuparuk River Oil Pool KRU 2G-10 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) ~ Gas-Mcf MD ~ Size 116' ~ ~~ INJECTOR ~~ ~ 324-244 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG ~ Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: Baker FHL Packer SSSV: Baker FVL Sfty Vlv Jaime Bronga jaime.bronga@conocophillips.com (907) 265-1053Senior Well Interventions Engineer 6612-6629', 6646-6684' 6114-6127', 6140-6168' Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 4:18 pm, Sep 18, 2024 DTTMSTART JOBTYP SUMMARYOPS 7/13/2024 ACQUIRE DATA (MISC) INJECT SEAL-TITE PILL INTO IA FOLLOWED BY 64 BBL DIESEL (COMPLETE) PRESSURE CYCLES (IN PROGRESS) 7/14/2024 ACQUIRE DATA (MISC) MOVE SEAL-TITE PILL TO LOWER SUSPECTED LEAK (COMPLETE), SEAL-TITE PRESSURE CYCLES (IN PROGRESS) 7/15/2024 REPAIR WELL SET 1" DUMMY VALVE IN STA 5 @ 6453' RKB. ATTEMPT MIT-T TO 3000 PSI (FAILED), SET 3.5" D&D HOLE FINDER ON TOP OF 3.5" RBP @ 6523' RKB, PERFORM MITT TO 3000 PSI (PASSED) SET 3.5" D&D PLUG ON TOP OF 3.5" RBP @ 6523' RKB. PERFORM MIT-T TO 3000 PSI (PASSED), PERFORM MITxIA TO 2000 PSI (PASSED) , JOB IN PROGRESS 7/16/2024 ACQUIRE DATA (MISC) ATTEMPT TO MIT TUBING POST SLICKLINE SETTING SLIP STOPS ON PLUG (FAILED) ESTABLISHED TUBING LLR OF 0.14 GPM @ ~3000 PSI, PRESSURE IA UP IN STEPS OF 2000, 2500, 3000 & 3300 PSI (COMPLETE) 7/16/2024 REPAIR WELL SET 3.5" SLIPSTOP CATCHER ON TOP OF D&D PLUG @ 6523' RKB, TURN WELL OVER TO DHD FOR TESTING, JOB IN PROGRESS 7/17/2024 ACQUIRE DATA (MISC) MOVE SEAL-TITE PILL TO UPPER LEAK POINT (COMPLETE) IA PRESSURE UPS TO 3305 PSI (COMPLETE) PRESSURE IA TO 3302 PSI TO START 24-48 HR CURE PROCESS (IN PROGRESS) 7/17/2024 REPAIR WELL PULL 1" DUMMY VLV FROM STA 5 @ 6453' RKB, LRS TO PUMP DOWN TBG TO MOVE SEALTITE PILL UP IA, REPLACE DUMMY VALVE IN STA 5 @ 6453' RKB, GOOD PRESSURE TEST, TURN WELL OVER TO DHD & SEAL TITE TO CONTUNUE WITH JOB 7/19/2024 ACQUIRE DATA (MISC) SEALTITE TREATMENT. MIT IA TO 3300 PSI. INCONCLUSIVE. DDT TO 800 PSI. INCONCLUSIVE. 7/31/2024 ACQUIRE DATA (AC-EVAL) TDDT TO 500 PSI (FAIL) 8/11/2024 ACQUIRE DATA (AC EVAL) PRESSURE T X IA TO 3000 PSI FOR SEALTITE DIAGNOSTICS IN PROGRESS, SEE STORY FOR VOLUMES PUMPED AND LLRS. 8/12/2024 ACQUIRE DATA (MISC) BLEED T & IA TO 800 PSI (COMPLETE) 2G-10 SealTite Repair Summary of Operations 8/20/2024 REPAIR WELL PULLED 3-1/2" RBP @ 6523' RKB. READY FOR RELAY UNIT. 8/23/2024 REPAIR WELL LOG W/ CALIPER FROM 6540' RKB TO SURFACE, BRUSH N FLUSH TBG TO D-NIPPLE @ 6527' RKB, DISPLACE TBG W/ DIESEL, SET 2.75'' CA-2 PLUG IN D-NIPPLE @ 6527' RKB, MIT-T TO 2500 PSI, LDFN. JOB IN PROGRESS 8/24/2024 REPAIR WELL ATTEMPT MIT-T TO 2500, OBTAIN GOOD TEST W/ HOLEFINDER @ 6445' RKB, RDMO. NEED NEW PLAN FORWARD FOR ANN COMM AND SEAL-TITE TREATMENT. 8/28/2024 REPAIR WELL (AC EVAL) MIT T TO 2500 PSI. (FAILED) ESTABLISHED T LLR = 0.48 GPM @ 2500 PSI. MIT IA TO 2500 PSI. (PASSED) IA DDT TO 800 PSI (COMPLETE) MIT IA TO 3300 PSI (PASSED) 9/4/2024 REPAIR WELL PULL 2.75" CA-2 PLUG FROM D NIPPLE @ 6527' RKB, JOB COMPLETE. Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 6,744.0 2G-10 2/21/2016 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled plug 2G-10 9/4/2024 fergusp Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 10/20/2010 ninam NOTE: WAIVERED WELL T x IA COMMUNICATION, WI ONLY 5/8/2008 lmosbor 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 37.0 116.0 116.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 37.2 2,796.0 2,796.0 36.00 J-55 BTC PRODUCTION 7 6.28 34.6 6,864.3 6,303.6 26.00 J-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 32.0 Set Depth 6,540.3 Set Depth 6,060.5 String Max No 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE8rd ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 32.0 32.0 0.03 HANGER 8.000 GRAY TUBING HANGER 3.500 1,900.6 1,900.6 0.23 SAFETY VLV 5.937 BAKER FVL SAFETY VALVE BAKER FVL 2.810 1,949.6 1,949.6 0.19 GAS LIFT 5.312 MMH/3.5 x 1 MMH FMHO 2.867 3,388.9 3,388.9 1.86 GAS LIFT 5.312 MMH/3.5 x 1 MMH FMHO 2.867 4,576.8 4,535.1 25.26 GAS LIFT 5.312 MMH/3.5 x 1 MMH FMHO 2.867 5,720.7 5,452.5 43.44 GAS LIFT 5.312 MMH/3.5 x 1 MMH FMHO 2.867 6,453.7 5,995.5 41.31 GAS LIFT 5.312 MMH/3.5 x 1 MMH FMHO 2.867 6,497.1 6,028.1 41.37 PBR 5.000 BAKER PBR BAKER 3.000 6,510.8 6,038.4 41.40 PACKER 5.968 BAKER FHL PACKER BAKER FHL 2.937 6,527.9 6,051.2 41.44 NIPPLE 4.540 CAMCO D NIPPLE NO GO CAMCO D 2.750 6,539.5 6,059.9 41.47 SOS 4.500 BAKER SHEAR OUT SUB, ELMD TTL @ 6538' during OTIS FLUID LD LOG on 01/14/85 BAKER 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 6,683.0 6,167.3 41.48 FISH 1" DMY w/ bent latch Lost in Rathole 11/6/1985 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) 1,949.6 1,949.6 0.19 1 INJ DMY BK2 1 0.0 10/28/1984 0.000 3,388.9 3,388.9 1.86 2 INJ DMY BK2 1 0.0 11/6/1985 0.000 4,576.8 4,535.1 25.26 3 INJ DMY BK2 1 0.0 10/28/1984 0.000 5,720.7 5,452.5 43.44 4 INJ DMY BK 1 6/22/2024 6,453.7 5,995.5 41.31 5 INJ DMY BK 1 7/17/2024 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,612.0 6,629.0 6,114.1 6,126.9 A-5, 2G-10 10/28/1984 4.0 IPERF 90 deg. Ph; 4" Schlumberger Csg 6,646.0 6,684.0 6,139.6 6,168.0 A-4, 2G-10 10/28/1984 4.0 IPERF 90 deg. Ph; 4" Schlumberger Csg 2G-10, 9/18/2024 10:09:01 AM Vertical schematic (actual) PRODUCTION; 34.6-6,864.3 FISH; 6,683.0 IPERF; 6,646.0-6,684.0 IPERF; 6,612.0-6,629.0 PACKER; 6,510.8 GAS LIFT; 6,453.7 GAS LIFT; 5,720.7 GAS LIFT; 4,576.8 GAS LIFT; 3,388.9 SURFACE; 37.2-2,796.0 GAS LIFT; 1,949.6 SAFETY VLV; 1,900.6 CONDUCTOR; 37.0-116.0 KUP INJ KB-Grd (ft) 40.98 RR Date 9/9/1984 Other Elev 2G-10 ... TD Act Btm (ftKB) 6,897.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292114000 Wellbore Status INJ Max Angle & MD Incl (°) 43.48 MD (ftKB) 5,700.00 WELLNAME WELLBORE2G-10 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: TRDP 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Seal-Tite Repair 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 6897' 6683' Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng KRU 2G-10 6328' 6744' 6213' 6253' N/A Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: AOGCC USE ONLY Tubing Grade: Tubing MD (ft): 6511' MD and 6038' TVD 1901' MD and 1901' TVD Dusty Freeborn STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025667 184-106 P.O. Box 100360, Anchorage, AK 99510 50-029-21140-00-00 Kuparuk River Field Kuparuk River Oil Pool ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Kuparuk River Oil Pool TVD Burst 6540' MD 116' 2796' 116' 2796' 6304'6864' 16" 9-5/8" 79' 2759' 6612-6629, 6646-6684' 6830' 6114-6127', 6140-6168' 7" Perforation Depth TVD (ft): 5/6/2024 3-1/2" Packer: Baker FHL Packer SSV: Baker FVL Safety Valve Perforation Depth MD (ft): J-55 Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Contact Email: dusty.freeborn@conocophillips.com Contact Phone:(907) 830-9777 MPSP (psi): 1059 psi Staff Well Integrity Specialist By Grace Christianson at 11:03 am, Apr 24, 2024 Digitally signed by Dusty Freeborn DN: OU=Well Integrity, O=ConocoPhillips, CN=Dusty Freeborn, E=dusty.freeborn@conocophillips.com Reason: I am the author of this document Location: Anchorage, Alaska Date: 2024.04.24 10:53:11-08'00' Foxit PDF Editor Version: 13.0.0 Dusty Freeborn SFD 4/24/2024 DSR-4/29/24VTL 5/6/2024 X 10-404 X JLC 5/6/2024 Page 1 of 3 Proposed Procedure for ConocoPhillips Diagnostics and Repair of Casing Leak Prepared by Seal-Tite International Field: Kuparuk Well: 2G-10 Date: April 16th, 2024 Objectives 1. Determine leak rate. 2. Cure the leak using Seal-Tite sealants and procedures. Mechanical Considerations The subject water injection is completed with 3-1/2 tubing anchored to a production packer at 6510. The well failed an MIT-IA in 2023 and the well was secured in January 2023 with a tubing plug below the production packer followed by a successful MIT-T which suggested a casing leak. An acoustic leak detection log located a leak at 2640 MD in Feb 2023. Leak rate was measured at 0.06 GPM (225 ml/min) @ 3300 psi. The leak detection log shows evidence of another leak site at 3340 (low potential). The IC hanger void area was successfully tested in April 2024. MIT IA required test pressure is 3300 psi (3000 psi max injection pressure +10%). Maximum angle 44 degrees (5700) Joel requested inclination survey. Tubulars Tubing: 3-1/2 9.3# J-55 EUE 8RD 2.992 ID Production Casing: 7 26# J-55 Buttress 6.276 ID Capacities Tubing - 0.0097 bbls/ft x 6511 WLM = 63 bbls Annulus 0.0264 bbls/ft x 6511 WLM = 172 bbls Intended Diagnostic Procedure 1. Meet with field personnel; review field history and verify condition of well as matching information provided. 2. Perform Job Safety Analysis with all concerned personnel. 3. Record all tubing and casing pressures. Page 2 of 3 4. Locate the test port for subject casing hanger. The test port may access the void between primary and secondary seals for a conventional casing hanger, or between pack-off seals for a pack-off style casing hanger. Rig up pressure relief tool with gauge and bleeder valve to the test port fitting. Sting in to move check valve off seat, record pressure in the void, and compare with adjacent casing pressures. Bleed void pressure to zero. If possible, measure stable fluid flow rate from the test port. Shut in and monitor for pressure build up. 5. Bleed all well pressures to zero. Document return type and volume. 6. Rig up and pressure circulation manifold to tubing and annulus. 7. Pressure test tubing to 3500 psi and document results. 8. Pressure test annulus at three intervals (1000 psi, 2000 psi, and 3300 psi) and measure leak rate at each interval. Record the volume to pressure up and volume to maintain pressure. 9. Report leak rate data to office for evaluation and consent to proceed with the leak repair. Intended Repair Procedure 10. RIH and pull dummy GLV from SPM at 6454 MD. If necessary, install circulation orifice (no check) to reduce SPM washout. 11. Circulate 9.6 ppg NaCl down tubing taking annulus returns until all diesel has been removed and measured IA returns density = 9.6 ppg or heavier. 12. Load tubing with 30 bbls of diesel to create an underbalance that will be used to suck sealant into IA. 13. Rig up IA suction lines to Seal-Tite sealant drums/tank. 14. Using COP blending tank trailer, blend two 3 bbls batches of Flo-Seal pressure- activated sealant. 15. Slowly bleed and regulate diesel from the tubing until 6 bbls of sealant has been introduced to the IA. Sealant will be designed to float on the annulus fluid which equates to 225 sealant column. 16. Pump 64 bbls of diesel into the IA taking water returns from the tubing to spot the leading edge of sealant @ 2640 WLM. Close tubing bleed. Page 3 of 3 17. Pressurize annulus with diesel in 500 psi increments and hold for 30 minutes at each step until reaching 3300 psi to squeeze sealant through the leak site and seal the leak. Note- If leak persists it may be due to a leak deeper in the well suspected to be @ 3340 as shown on the leak detection log. Contact Seal-Tite to discuss moving sealant across deeper leak. 18. Slickine RIH and pull circulation valve from SPM @ 6554 MD. Reinstall dummy GLV in same. 19. Slickline RIH and pull RBP from nipple @ 6528. This will allow COP to bullhead diesel into the tubing for freeze protection. 20. Pump ~20 bbls diesel down tubing to freeze protect. 21. Set CA-2 plug into Camco D-nipple at 6528. 22. Shut in IA test pressure of 3300 psi for a minimum of 48 hours to allow the sealant to cure. 23. Record casing pressures regularly during the cure period. 24. Perform 3 pressure cycles from 0 psi to 3300 psi to verify the seal durability. Document fluid volume in and out. Note: Recommendation is to leave the sealant in the annulus across the leak site with 300 psi applied pressure for monitoring purposes. 25. Put well back on injection and monitor until at normal injection rate. 26. Rig down equipment and turn well over to COP. END Chris Anderson VTL 5/6/2024 State witnessed MIT-IA required after stabilized injection. Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Fished E-line Tools 2G-10 1/31/2023 zembaej Notes: General & Safety Annotation End Date Last Mod By NOTE: WAIVERED WELL T x IA COMMUNICATION, WI ONLY 5/8/2008 lmosbor 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 37.0 116.0 116.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 37.2 2,796.0 2,796.0 36.00 J-55 BTC PRODUCTION 7 6.28 34.6 6,864.3 6,303.6 26.00 J-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 32.0 Set Depth 6,540.3 Set Depth 6,060.5 String Max No 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE8rd ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 32.0 32.0 0.03 HANGER 8.000 GRAY TUBING HANGER 3.500 1,900.6 1,900.6 0.23 SAFETY VLV 5.937 BAKER FVL SAFETY VALVE BAKER FVL 2.810 1,949.6 1,949.6 0.19 GAS LIFT 5.312 MMH/3.5 x 1 MMH FMHO 2.867 3,388.9 3,388.9 1.86 GAS LIFT 5.312 MMH/3.5 x 1 MMH FMHO 2.867 4,576.8 4,535.1 25.26 GAS LIFT 5.312 MMH/3.5 x 1 MMH FMHO 2.867 5,720.7 5,452.5 43.44 GAS LIFT 5.312 MMH/3.5 x 1 MMH FMHO 2.867 6,453.7 5,995.5 41.31 GAS LIFT 5.312 MMH/3.5 x 1 MMH FMHO 2.867 6,497.1 6,028.1 41.37 PBR 5.000 BAKER PBR BAKER 3.000 6,510.8 6,038.4 41.40 PACKER 5.968 BAKER FHL PACKER BAKER FHL 2.937 6,527.9 6,051.2 41.44 NIPPLE 4.540 CAMCO D NIPPLE NO GO CAMCO D 2.750 6,539.5 6,059.9 41.47 SOS 4.500 BAKER SHEAR OUT SUB, ELMD TTL @ 6538' during OTIS FLUID LD LOG on 01/14/85 BAKER 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 6,523.5 6,047.9 41.43 PLUG 2.725" RBP w/ Mid Element set @ 6,526' RKB (6.97' OAL) Quadco TTS- RBP CPP 35325 /CPE Q3503 2 1/24/2023 0.000 6,683.0 6,167.3 41.48 FISH 1" DMY w/ bent latch Lost in Rathole 11/6/1985 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) 1,949.6 1,949.6 0.19 1 GAS LIFT DMY BK2 1 0.0 10/28/1984 0.000 3,388.9 3,388.9 1.86 2 GAS LIFT DMY BK2 1 0.0 11/6/1985 0.000 4,576.8 4,535.1 25.26 3 GAS LIFT DMY BK2 1 0.0 10/28/1984 0.000 5,720.7 5,452.5 43.44 4 GAS LIFT DMY BK2 1 0.0 11/6/1985 0.000 6,453.7 5,995.5 41.31 5 GAS LIFT DMY BK2 1 0.0 8/11/2018 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,612.0 6,629.0 6,114.1 6,126.9 A-5, 2G-10 10/28/1984 4.0 IPERF 90 deg. Ph; 4" Schlumberger Csg 6,646.0 6,684.0 6,139.6 6,168.0 A-4, 2G-10 10/28/1984 4.0 IPERF 90 deg. Ph; 4" Schlumberger Csg FISH; 6,683.0 IPERF; 6,646.0-6,684.0 IPERF; 6,612.0-6,629.0 PLUG; 6,523.5 PACKER; 6,510.8 GAS LIFT; 6,453.7 GAS LIFT; 5,720.7 GAS LIFT; 4,576.8 GAS LIFT; 3,388.9 SURFACE; 37.2-2,796.0 GAS LIFT; 1,949.6 SAFETY VLV; 1,900.6 CONDUCTOR; 37.0-116.0 C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2023-03-01_21125_KRU_2G-10_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well #API # Log Description Log Date 21125 KRU 2G-10 50-029-21140-00 Caliper Survey Log 01-Mar-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL :READ-Anchorage@readcasedhole.com WEBSITE :WWW.READCASEDHOLE.COM C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\023-02-28_21124_KRU_2G-10_ArcherVividAcousticLDL__Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well #API # Log Description Log Date 21124 KRU 2G-10 50-029-21140-00 Archer Vivid Acoustic LDL 28-Feb-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL :READ-Anchorage@readcasedhole.com WEBSITE :WWW.READCASEDHOLE.COM • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Saturday, February 24, 2018 9:22 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: KRU 2G-10 (PTD 184-106) Update Attachments: 2G-10 90 day TIO trend 2-24-18.JPG Chris, KRU Water injector 2G-10(PTD 184-106) (AIO 26.030)was most recently reported February 15, 2018 to extend the monitor period allowing additional time for IA pressure stabilization once service, rate&temperature were stable. Unfortunately the IA pressure has continued to increase. Operations has been notified to the shut in and freeze protect the well. Diagnostics will be performed in attempt to locate the leak to assess potential repair options. The proper paper work will be submitted for corrective action or continued injection once a plan forward has been developed. A 90 day TIO is attached. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne/Kelly Lyons Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7224 AWELLS TEAM SCMNNE ' • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Thursday, February 15, 2018 7:33 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler; NSK Well Integrity Supv CPF1 and 2 Subject: RE: KRU Injector 2G-10 (PTD 184-106 Update Attachments: MIT KRU 2G-10 diagnostic MITIA 1-16-18.xlsx; 2G-10 90 day TIO trend 2-15-18.JPG; SCADA 28 day TIO trend 2-15-18.JPG Chris, KRU Water injector 2G-10(PTD 184-106) (AIO 26.030)was reported January 15, 2018 for unexplained IA pressure increase. A passing MITIA and pack off tests were performed the following day and the IA was put on a monitor period after being degassed. Due to multiple injection service, rate&temperature changes it is difficult to make a determination as to whether the pressure increase is reactionary to the changes or there is annular communication. Post the last bleed performed by DHD on February 12, 2018 the IA pressure appears to be stabilizing. CPAI intends to extend the monitor period up to another 30 days. A request is being made to Operations to maintain a stable injection service, rate&temperature to facilitate the monitor period. If the well exhibits any additional signs of communication it will be shut in. Attached is a 10-426, 90 day TIO trend,and 28 day SCADA to better demonstrate the service, rate&temperature changes. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne/Kelly Lyons Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7224 AWELLS TEAM Co. Mups SCANNED 1 • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Monday,January 15, 2018 3:54 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler; NSK Well Integrity Supv CPF1 and 2 Subject: KRU Injector 2G-10(PTD 184-106) Report of suspect IA pressure increase Attachments: 2G-10.pdf;2G-10 90 day TIO 1 51 18.JPG Chris, KRU Water injector 2G-10(PTD 184-106) (AIO 26.030) is exhibiting an unexplained IA pressure increase. Operations has bled down the IA pressure multiple times since the well was BOI January 10,2018. DHD will be dispatched tomorrow to perform diagnostics to include an MIT-IA, pack off tests, and draw down test of the IA. If diagnostics pass the well will be put on a 30 day monitor period. If the MIT fails the well will be shut in and freeze protected until a plan forward has been developed. Attached is a wellbore schematic and 90 day TIO trend. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne/Kelly Lyons Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7224 &ELLS TEAM conocaPhi Ips SCAN 4 , 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 7 DATE: Tuesday,June 28,2016 YI I P.I.Supervisor 11 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2G-10 FROM: Johnnie Hill KUPARUK RIV UNIT 2G-10 Petroleum Inspector Src: Inspector Reviewed By::pp� P.I.Suprv;JB;IBC- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2G-10 API Well Number 50-029-21140-00-00 Inspector Name: Johnnie Hill Permit Number: 184-106-0 Inspection Date: 6/21/2016 Insp Num: mitJWH160626224135 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2G-10 Type Inj W•TVD r 6038 Tubing 2590 - 2591 2590 . 2591 . PTD 1841060 (Type Test EllTest psi 3000 = IA 1340 3400- 3310 - 3290 _ Interval REQVAR P/F P V OA 41 49 49 49 • Notes: MITIA to max Anticipated injection psi per AIO 2B.030 r . ,;:,.: NOV 222010 Tuesday,June 28,2016 Page 1 of 1 ,~ Ima act Well History File Covel~ge XHVZE This page identifieS those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ ~_.__~__~~- ~ ~ Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Other, No/Type [] Other items scannable by large scanner D Poor Quality Originals: ~ OVERSIZED (Non-Scannable) [] Other: , Logs of various kinds NOTES: [] Other BY: ~REN VINCENT SHERYL MARIA LOWELL Project Proofing BY: BEVERLY B~HERYL MARIA LOWELL Scanning Preparation x 30 = BY; BEVERLY BREN VINCENT~ARIA LOWELL Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: '/ ~' -,,'/ ' ~COUNT MATCHES NUMBER ,N SCANN,NG PREPARA'r,ON: ~YES NO Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: ~ YES NO BY~ I~EVERLY BREN VINCENT{~ MARIA LOWELL (SCANNING I$ cOMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) RESCANNEDBY; BEVERLY BREN VINCENT SNERYL MARIA LOWELL DATE: /si General Notes or Comments about this file: QUality Checked MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ,--_-) DATE: egg DATE:Thursday,May 24,2012 P.I.Supervisor I\e(z qzcitz, SUBJECT:Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2G-10 FROM: John Crisp KUPARUK RIV UNIT 2G-10 Petroleum Inspector Src: Inspector Reviewed By: C, P.I.Supry�1 -- NON-CONFIDENTIAL Comm r Well Name KUPARUK RIV UNIT 2G-10 API Well Number 50-029-21140-00-00 Inspector Name: John Crisp Permit Number: 184-106-0 Inspection Date: 5/1/2012 Insp Num: mitJCr120503090711 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 6038 1100 1 3350 ' 3210 3210 ' Well 2G-10 Type Inj I w�TVD 1 IA PTD 1841060 Type Test SPT Test psi 1509 - OA 320 453 465 467 ' Interval RQVAR 1P/F I P iTubing i 2575 2575 1 2575 2625 Notes: 4.7 bbls pumped for test. SCANNED MAR 1 3 2014 Thursday,May 24,2012 Page 1 of 1 • • `-Gt Regg, James B (DOA) P;- t 4 lobo From: NSK Problem Well Supv En1617 @conocophillips.com] Sent: Sunday, April 08, 2012 7:36 PM 'ff ¢l`(( y To: Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv; DOA AOGCC Prudhoe Bay; NSK DHD Field Supervisor Subject: 2G -10 (PTD 184 -106) Report of returning to injection Jim, Guy Kuparuk injector 2G -10 (PTD 184 -106) is planned to be brought back on injection later this week. The well has been SI since 09/28/11 for non - mechanical reasons. The well is currently operating under AIO 2B.030 and was due for it's MITIA by 02/26/12 but was not performed since the well was SI. Once the well has been brought on injection and thermally stabilized, a witnessed MITIA will be scheduled and performed. The well is already currently on the monthly report. Please let me know if you have any questions. Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7224 �, + n. Pager (907) 659 -7000 pgr. 909 APR 2 '4.02 1 MEMORANDUM To: Jim Rpgg ~~ ~ ~ ~I~~ f la P.I. Su ervisor 6 FROM: John Crisp Petroleum Inspector • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, March O1, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2G-10 KUPARUK RIV iJNIT 2G-10 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~'`Y'~ Comm Well Name: KUPARUK RIV UNIT 2G-10 API Well Number: 50-029-21140-00-00 Inspector Name: John Crisp Insp Num: mitJCr100227173630 Permit Number: 184-106-0 Inspection Date: 2/26/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ 2G~Type Inj. N Z'~7D _ 6038 ~ I,~~ 1050 3000 _ f_ 2880 ~~ 2860 t 1841060 SPT P.T.D TypeTest Test psi 1509 / QA 20 20 20 20 Interval REQVAR ~ p~F P .i Tubing 2375 2375 2500 2525 - - - Notes: Well was shut in. They were rigged up & pressure tested to the well when I arrived. 3 bbl's pumped for test. /~~M,n ~~sz;VG~ ~} ~ X30 ~'ll::a""Cl~~ ~ P t{ ~ ~a G ~ ~ C~ Monday, March 01, 2010 Page 1 of 1 2G-10 (PTD 1841060) Report of~pected TxIA communication • Page 1 of 3 Regg, James B (DOA} From: NSK Well Integrity Proj [N1878@conocophillips.com] ~ ~~ ~~ Sent: Tuesday, March 18, 2008 3:37 PM ~ G~ -~~ To: Regg, James B (DOA); NSK Problem Well Supv; Maunder, Thomas E (DOA) Cc: NSK Well Integrity Proj Subject: RE: 2G-10 (PTD 1841060) Report of suspected TxIA communication Jim, The rational behind the 30 days was to see if the TxIA communication was present on water. If it was not and we could keep the IA pressure below 1600 psi our AA request would state the reduced IA pressure as a preferred requirement over installation of the OA SVS system. The original draw down test was masked with the thermal influence from the WAG swapped. I will ask operations to SI the well ASAP and write the AA request with an either 1 or option far IA less than 1600 psi or a SVS on the OA. MJ I~oveland Well Integrity Project Supervisor ConocoPhillips Alaska, Ino. Office (907) 659-7043 Cell (307) 943-1687 ~~~t1HV~ APR 0 9 2008 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Tuesday, March 18, 2008 8:51 AM To: NSK Problem Well Supv; Maunder, Thomas E (DOA) Cc: NSK Well Integrity Proj Subject: RE: 2G-10 (PTD 1841060) Report of suspected TxIA communication I don't understand the need or rationale for your request to inject for 30 more days. You indicate the well was swapped to water on 2l16; has the well been shut in during the diagnostics performed since swapping to water? What is the basis for 30 days? Appears to me that you have sufficient information to request administrative approval now for continued water injection only; we will not approve gas injection at this time. Jim Regg 0 AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: ,NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Friday, March 14, 2008 3:47 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: RE: 2G-10 (PTD 1841060) Report of suspected TxIA communication Jim, Currently the well is tan Water injection. The initial diagnostics were done on 02f24108 after the well was WAG'd to water 3/28/2008 2G-10 (PTD 1841060) Report of ected TxIA communication Page 2 of 3 on 02I16f08. The diagnostics inclu~ubing packoff testing that passed the dr~wn test but failed the positive pressure test. The MITIA to 3000 psi and MITC}A to 1800 psi both passed and the test data is included in the attached MIT form. Following the ktliT`s, the IA was bled down for a Drawdown test: Initial TIO=2275l2560f300 Start lA DD test TI0=2275I1540f300 30 min T1O=227511600/300 60 min TI0=227511650/300 On 03103108 the TIO were 2250}20001300. Further diagnostics were performed on 03113 and 03114 that included passing IC packoff testing, Another IA DD test was also performed to evaluate if the previous buildup was thermal related with the following results: Initial TI0=2275120001320 Start lA DD test TI0=227519801310 15 min TI0=227519801310 30 min TI0=227519901310 45 min TI0=22751995!310 60 min TIO=22751100011310 12 hours later TI0=230011 1 55131 0. ConocoPhillips requests permission to leave the well on water injection for 30 days while trending the TIO plot to evaluate if the communication is only on gas injection, which may contribute to the stipulations placed on the AA. Following the 30 day test; CPAI intends to apply for an AA for continued water injection based an the results from the test. Also attached is a current 90 day TIO plot. Please let me knew if you have any questions. Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907} 659-7224 Cell Phone {907) 943-1999 Pager (907} 659-7000 pgr. 909 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Thursday, March 13, 2008 2:57 PM To: NSK Problem Well Supv; Maunder, Thomas E (DOA) Cc: NSK Well Integrity Proj Subject: RE: 2G-10 (PTD 1841060) Report of suspected TxIA communication What is status of this well and diagnosties? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Friday, February 15, 2008 7:21 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: 2G-10 (PTD 1841060) Report of suspected TxIA communication 3/28/2008 2G-10 (PTD 1841060) Report of~pected TxIA communication Page 3 of 3 Tom & Jim, Kuparuk MI injector 2G-10 (PTD 1841060) was reported to have suspect TxIA communication. The IA was bled down and repressures in 2 days. The TIO prior to the recent IA bleed was 3750/3100/300. Immediate action taken will be to WAG the well to water for a minimum of seven days and then perform the initial diagnostics which will include tubing packoff testing, a MITIA, and an IA DD test if the MITIA passes. Pending the outcome of the diagnostics, it will be ConocoPhillips intention to submit an AA to continue water injection (with interim approval to keep the well online) or a 10-403 Sundry application for repair, whichever may be appropriate. Attached is a schematic and a 90 day TIO p{ot. Please note on the TIO plot, there are 2 typing errors that were entered in December regarding the OA pressure. The high OA pressures were actually the IA pressures misentered by the operator. Please let me know if you have any questions. «2G-10 schematic.pdf» «2G-10 90 day TIO plot.jpg» Brent Rogers Problem We11s Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Cell Phone (907) 943-1999 Pager (907) 659-7000 pgr. 909 3/28/2008 ~ ~~- r~~, T/110 Plot - ~G-'1 +d X000 v~ 2000 a 1000 0 200 150 Q. 100 a 50 0 01-Oct-07 01-~Jov-07 01-Dec-07 01-Jan-08 01-Feb-08 01-Mar-08 Date ~ • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk/ KRU/ 2G-10 02/24/08 Greenwood -AES ~~ ~~~I ~ti~ l ~~~ Packer De t Pretest Initial 15 Min. 30 Min. Well 2G-10 T e In'. W TVD 6,039' Tubin 2,275 2 275 2,275 2,275 Interval O P.T.D. 1841060 Type test P Test si 510 Casing 2,100 ,000 3,000 3,000 P/F P Notes: Diagnostic MITIA pre-AA OA 310 325 325 325 Well 2G-10 T e lnj. W TVD ,039' Tubing 2,275 2,275 2,275 2,275 Interval O P.T.D. 1841060 Ty e test P Test si 510 Casing 2,560 2,560 2,560 2,560 P/F P Notes: Diagnostic MITOA pre-AA OA 325 v1$00 1780 1780 Well T pe Inj. TVD Tubing Interval P.T.D. T e test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. T e test Test psi Casing P/F Notes: OA Well Ty e In'. TVD Tubing Interval P.T.D. T e test Test si Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W = Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT KRU 2G-10 02-24-08.x1s 2G-10 (PTD 1841060) Report ofy~spected TxIA communication • Page 1 of 1 Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com) Sent: Friday, February 15, 2008 7:21 AM n ~)13~ 0~ To: Maunder, Thomas E (DOA); Regg, James B (DOA) ~~ ~~ ` Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: 2G-10 (PTD 1841060) Report of suspected TxIA communication Attachments: 2G-10 schematic.pdf; 2G-10 90 day TIO plot.jpg ~.~- Tom & Jim, Kuparuk MI injector 2G-10 (PTD 1841060) was reported to have suspect TxIA communication. The IA was bled down and repressures in 2 days. The TIO prior to the recent IA bleed was 3750/3100/300. Immediate action taken will be to WAG the well to water for a minimum of seven days and then perform the initial diagnostics which will include tubing packoff testing, a MITIA, and an IA DD test if the MITIA passes. Pending the outcome of the diagnostics, it will be ConocoPhillips intention to submit an AA to continue water injection with interim a royal to kee the well online or a 10-403 Sund a lication for re air, whichever ma be a ro riate. `~ ( pP p ) rY PP ~ p Y pp p Attached is a schematic and a 90 day TIO plot. Please note on the TIO plot, there are 2 typing errors that were entered in December regarding the OA pressure. The high OA pressures were actually the lA pressures misentered by the operator. ~ Please let me know if you have any questions. «2G-10 schematic.pdf» «2G-10 90 day TIO plot.jpg» Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Cell Phone (907) 943-1999 Pager (907} 659-7000 pgr. 909 3/13/2008 KRU 2G-10 PTD 184-106 T/l/O Plat - 2G-10 3000 us 2000 cY. 1000 '!.. Ii ~. 0 200 150 a E a~ 100 0 s 5a 0 • o1-Dec-o~ 01-Jan-08 Date 01-Feb-08 • ~ ~ ~~, Conocca~hill~ps Atas~c~, #nc. • KRU 2G-10 API: 500292114000 Well T e: INJ An le TS: 41 de 6521 I SSSV T e: TRDP Ori Com letion: 9/971984 An le TD: 41 de 6897 SSSV i ~ Annular Fluid: Last W/O: Rev Reason: FORMAT UPDATE (1901-1902, ~ Reference Lo Ref Lo Date: Last U d ate: 7!31!2004 OD:3.5o0) Last Ta : 6706 TD: 6897 ftKB Last Ta Date: 2/15/1998 Max Hole Anale: 43 deq (c~ 5.700 ~ ~ _ Gasin Strin -ALL STRINGS _ ~ _ Descri lion ~ Size To Bottom TVD Wt _ Grade Thread Gas Lift CONDUCTOR 16.000 0 116 116 62.50 H-40 idrel/Dummy II ~ SUR. CASING 9.625 0 2796 2796 36.00 J-55 valve 1 F ,.. ~ ' 7 Ono _ PROD. CASING n saga 63n7 2.6 n_n - I-55 1950-1951 ~ _ T_u bing Strinq - TU61NG T _ - ) _ _ Size To Botto Grade ~ m i TV ~ Wt D _ - Thread s ~ _~ ~-65 ~ E~ ~FC Perforations Summa _ Gas Lin __ __ _ __ ,dreltDummy 4 - ~ Interva l TVD Zone Status Ft SPF D ate T Comment Valve 2 ` t '~ 6612 - 6629 6114 - 6127 A-5 17 4 10/28/1984 IPERF 90 deg. Ph; 4" Schlumberger (3389-3390, CS OD:5.313) { 6646 - 6684 6140 - 6168 A-4 38 4 10/28/1984 IPERF 90 deg. Ph; 4" Schlumberger I __ Cs - Gas Lift MandrelsNalves '" - - - - Gas Lift _ _ _ D n f . , St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO ate Ru Vlv idrel/Dummy Valve 3 € I Cmnt (4577-4578 1 1950 1950 MMH 3.5 x 1 DMY 1.0 BK-2 0.000 0 10/28/1984 , OD:5.313) 2 3389 3389 MMH 3.5x1 DMY 1.0 BK-2 0.000 0 11/6!1985 3 4577 4535 MMH 3.5 x 1 DMY 1.0 BK-2 0.000 0 10/28/1984 4 5721 5453 MMH 3.5x1 DMY 1.0 BK-2 0.000 0 11/6/1985 Gas Lift 5 6454 5996 MMH 3.5 x 1 DMY 1 0 BK-2 0.000 ~ 0 10/?x/1984 idrel/D 4 f ' ~ Other lu s e ui .etc. -JEWELRY alve ~ _ De th TVD T _ _ _ Descri lion _ ID (5721-5722, OD:5 313) 1901 1901 SSSV Baker'FVL' 2.810 . 6497 6028 PBR Baker 2.810 ~ 6511 6039 PKR Baker'FHL' 3.000 Gas Lift i 6528 6051 NIP Camco'D' Ni Ie NO GO 2.750 idrel/Dummy _ ~ 6539 6059 SOS Baker 2.992 Valve 5 . - - ' 6540 6060 TTL -_ -- - _ 2.992 (6454-6455, Flsh -FISH` OD:5.313) De th Descri tlOn COm meat 6683 1" DMY w/ bent latch Lost in Rathole PBR (6497-6498, OD:3.500) PKR (6511-6512, ~ ' ~ i / OD:6.151) . t NIP (6528-6529, OD:3.500) TUBING (0-6540, OD:3.500, -- ID:2.992) SOS ~ L (6539-6540, - OD:3.500) Pert (6612-6629) Pert (6646-6684) MEMORANDUM State of Alaska Alaska Oil and Gas Consen'ation Commission . ...-: TO: JIm Regg \<-. (~(¡1 I P.I. Suprrvisor (7 1~/C4 DATE: Wednesday. June 3O. 2004 SlIBJECT: !\ 1echaOlcallntegrlty Tests CONOCOPHlLLlPS A1..A,51\.....\ fNC FROM: John Crisp Petroleum Inspector 2G-l0 hUPARill: RIV UNIT 2G-IO Src: Inspector Reviewed By: P.I. Supr\' 3"f;L- Comm NON-CONFIDENTIAL Well Name: KUPARUK RJV UNIT 2G-IO Insp Num: mitJCr040628 1 85743 Rellnsp Num: API Well Number: 50-029-21140-00-00 Permit Number: 184-106-0 Inspector Name: John Cnsp Inspection Date: 6/27/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 1\1 in. Well 2G-10 Type Inj. G j TVD 6328 IA 2700 1600 1620 1640 1650 1650 P.T. 1841060 TypeTest SAM I Test psi 1509.75 OA 180 180 180 180 180 180 Inten'al 4YRTST PIF p Tubing 3600 3600 3600 3600 3600 3600 Notes: !\lonitored annulus pressure for 1 hour. Returned 5 hours later & witnessed 1:\ Ig' 1700 psi. Wednesday. June 30. 2004 Page 1 of I ARCO Alaska, Inc;.,.,... Posl Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 28, 1987 Ms..Fran Jones Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Miscellaneous GCT Surveys Dear Fran: Enclosed are additional copies of the following 1L-6 2A-2 1L-15 2A-3 1L-16 2A-4 L1-1 2D-11 L2-28 2D-12 2G-8 2G-10 2G-13 If you have any questions, Sincerely, L1. Gruber Associate Engineer please call me at JG:pk JG/78 Enclosures GCT surveys: 263-4944. R£C£1v£ JUL iJJaeka 0il & Gas Cons. Comn?issloj~ Anchorage AIICO Alanka. Inc. I! a Subsidiary of allartllcrllchlleldCompany ARCO Alaska, Inc. Post Office B;;~',~100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 16, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton- Attached in duplicate are subsequent notices following wells at the Kuparuk River Field- on the Well Action Date Performed 1L-1 Convers 1L-7 Convers lQ-2 Convers lQ-7 Convers 1Q-11 Convers 1Q-13 Convers 2B-5 Convers 2B-9 Convers 2C-1 Convers 2C-3 Convers 2C-6 Convers 2C-8 Convers 2D-2 Convers 2D-7 Convers 2D-11 Convers 2D-1 4 Convers 2F-1 Convers 2F-2 Convers 2F-13 Convers 2F-14 Convers 2G-3 Convers 2G-3 Convers 2G-5 Convers 2G-7 Convers 2G-10 Convers 2~-12 Convers 2G-16 Convers 2U-3 Convers 2U-4 Convers 2U-7 Convers 2U-16 Convers 2W-2 Convers 2W-4 Convers on on on on on on on on on on on on on on on on 11/18/85 11/18/85 11/17/85 11/17/85 11/17/85 11/17/85 11/23/85 11/23/85 11/19/85 11/19185 11/19/85 11/19/85 11/20/85 11/20/85 11120185 11/20/85 11/21/85 11/21/85 11/2i/85 11/21/85 11/14/85 11/14/85 11114185 11/lU,/85 11/14/85 11/14/85 11114185 RECEIVED 11/16/85 11/16/85 JAN.8~ ~ 11116185 11/15/~0it & ~as ~n~ I 1 / 22 / 85 ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany STATE Of ALASKA ALASKA 0~EAND GAS CONSERVATION COI~Ir~IlSSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 84-106 3. Address 8. APl Number P. O. BOX 100360, ANCHORAGE, ALASKA 99510 50- 029-211q0 4. Location of Well SURFACE LOCATION- 183' FNL, 272' FWL, SEC. 5, T10N, RgE, UM 5. Elevation in feet (indicate KB, DF, etc.) 1 40' (RKB) 12. I 6 . Lease Designation and Serial No. ADL 25667 ALK 2588 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 2G-10 11. Field and Pool KUPARUK RIVER FI ELD KUPARUK RIVER OIL POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stim u late [] Abandon [] Stim u lat ion [] Aba ndonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On November 14, 1985 Kuparuk well 2G-10 was converted from a producer to a water iniector well as part of the full field waterflood conversion effort. Water is being injected into "A"sand. the 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ;~,/~'~ ~_~~ Title KUPARUK The space below for Commission use OPERAT ! ONS COORD I NATOR Date ! 2 / ! 8/ R~5 Conditions of Approval, if any: By Order of Approved by. COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office ~,,,..x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 20, 1985 Mr. L. C. smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Street Anchorage, AK 99501 Dear L. C. Smith: Per our conversation on September 4, 1985, ARCO Alaska, Inc. proposes to convert 110 production wells t° water injection to implement fullfield waterflood of the Kuparuk River Unit. As discussed a single "blanket" sundry notice (form 10-403) has been completed for all well proposed to be converted to water injection. Individual subsequent sundry notices will be filed when the actual well conversions occur. As stated in form 10-403, well conversion to water injection will occur in two primary stages. The first stage will convert approximately four wells per drillsite to achieve a nine-spot pattern. First stage conversions are expected to be completed by approximately 10/15/85, prior to waterflood startup. The second stage of conversions will convert approximately four additional wells per drillsite to achieve a line drive pattern. Second stage conversions are expected to be completed mid-December to January 1986. I would like to express my thanks and appreciation to the Commission in working with ARCO Alaska, Inc. in this area. If you have any questions please call me at 263-4212. Sincerely, T. M. Drumm Kuparuk Operations Coordinator cc: J.F. Beall TMD:ps:013 ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompany STATE OF ALASKA ALASKA 'L AND GAS CONSERVATION C~ 'MISSION SUNDRY N' OTICES AND REPORT ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~ OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well N/A 7. Permit No. see attached 8. APl Number 50- see attached 9. Unit or Lease Name Kuparuk River Unit 10. Well Number see attached 11. Field and Pool KUparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk Ri ver 0i 1 Pool N/A I see attached 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [-I Perforations [] Altering Casing r-} Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other X~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.} 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). !o Pursuant to form 10-403, it is proposed that the attached list otW/~producing wells in the Kuparuk River Field be converted to water injection. The conversion will occur in two stages. The first conversion: to a nine-spot pattern will occur approximate]~v 10/15/85. The second conversion to a line drive pattern will occur approximately 12/15/85. Injection will be into the A and C sands. SEF' 2 0 19 5 AtasY, a 0il & Gas Cons. G0rnmission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~, /~'~"~ ~~ Title Kuparuk Operations Coordinator Date The space below for Commission use 9/18/85 Conditions of Approval, if any: Form 10-403 Rev. 7-1-80 Approved Copy __,eturned / By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate - 6 - 7 - 8 2D- 2 - 4 - 5 - 7 -10 -11 -14 -16 2E-10 -12 -13 -14 2F- 1 ' 2 - 3 - 4 -13 -14 -15 -16 2G- 1 - 3 - 5 - 7 -10 -12 -16 2U- 3 - 4 - 7 -11 -14 -16 2V- 2 - 4 - 5 - 6 - 7 - 8 2W- 2 - 4 - 5 - 8 - 9 MARK: 0092 100 96 95 84-152 151 126 143 101 99 159 161 84-230 211 196 197 83-183 188 187 190 156 159 172 177 84-118 139 80 85 106 128 132 85- 6 7 20 40 84-247 249 83-161 165 176 179 180 186 85- 16 12 84-191 212 219 20979 20970 20974 029-21177 21176 21157 21169 21135 21134 21183 21185 029-21246 21227 21213 21214 029-21058 21063 21062 21065 21032 21035 21048 21052 029-21150 21165 21119 21124 21140 21159 21163 029-21269 21270 21283 21303 21262 21264 25653 25658 25658 2580 12 10 12 /15 /15 /15 /85 /85 /85 2579 2584 12/15/85 10/15/85 10/15/85 12/15/85 10/15/85 i2/i5/85 i2/i5/85 i0/i5/85 2584 12/15/85 " 12/15/85 " 12/15/85 " 12/15/85 25657 2583 12'/15/85 " " 12/15/85 " " 10/15/85 ,, " i0/i5/85 " " 12/15/85 " " 12/15/85 ,, " 10/15/85 ,, " 10/15/85 25656 2582 12/15/85 " " 10/15/85 " " 10/15/85 " " 12/15/85 " " 10/15/85 " " 12/15/85 "' " 10/15/85 25644 !! I! 25643 2575 10/15/85 " 12/15/85 " 10/15/85 2574 10/15/85 " 10/15/85 " 12/15/85 029-21037 25655 2581 10/15/85 21041 25644 2575 10/15/85 21051 " " 10/15/85 21054 " " 12/15/85 21055 25655 2581 10/15/85 21061 " " 12/15/85 029-21279 25642 2573 10/15/85 21275 " " 12/15/85 21208 " " 12/15/85 21228 '" " ,.]rQ/15/85 21235 ~ E C E iV ~/15/85 sE? 2 o STATE OF ALASKA ALASKA,~._.L AND GAS CONSERVATION C(~._;MlSSlON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL C~x GAS [-] SUSPENDED [] ABANDONED [] SERVICE [] _ 2. Name of Operator 7. Permit Number ARCO Maska, Inc. 84-106 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21140 4. Location of well at surface 9. Unit or Lease Name 183' FNL, 272' FWL, Sec.5, T10N, RgE, UN Kuparuk River Unit At Top Producing Interval 10. Well Number. 1484' FNL, 1283' FWL, Sec.5, T10N, RgE, UM 26-10 At Total Depth 11. Field and Pool 1552' FNL, 1340' FWL, Sec.5, T10N, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 140' RKBI ADL 25667 ALK 2588 12. Date Spudded09/02/84 13. Date T.D. Reached09/08/84 14' Date C°mp" Susp' °r Aband' I 1§' Water Depth' if °ffsh°re [ 16' N°' °f C°mpleti°nSl 0/28/84 N/A feet MSL 1 17. Total Depth (MD+T'VD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where sSsv set [ 21. Thickness of Permafrost 6897'MD,6328'TVD 6787'ND,6245'TVD YES I~X NO [] 1901 feet MDI 1500' (Approx) 22. Type Electric or Other Logs Run D IL/SFL/GR/SP/FDC/CNL/Cal, RFT, Gyro, CBL, CCL/Temp. 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 116' 24" 202 sx Co]d Set I I 9-5/8" 36.0# J-55 Surf 2796' 12-1/4" 740 sx Permafrost E & ~70 sx Permafrost C 7" 26.0# J-55 Surf 6869' 8-1/2" 300 sx Class G & 250 s~ Permafrost; C 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) 6612' - 6629' 6646' - 6684' w/4 spf, 90° phasing 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED See attached Adde ~dum, dated 4/2/85. 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR el L-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED=1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr)' Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE RECEIVED Alaska 0~i & ~as Cons, ¢0mmiss/0n : ... Form 10-407 (]RU6/WC23 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE .... ......... ' ? ~'-' ........ -- "-.'.,..,; %;:: ;: "'::-" i~ t. ,¢ :'?:';" ? '.:,,f, :t. :~s~-O:~i~Ti~)NC;i:.E~.:i.~."-~ · ' ." ' 'GEOLOGIC-MARKERS ': '"--_ --- - - . . · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk B 6521'-'. 6046' See RFT results included with the Well .... ' Top Lower Sand 6593' 6100' Completion Report, dated 3/20/85. Base Lower Sand 6763' 6227' ': ' : ' .' " · . · . . ~ . '' · · _. · 31: LIST OF ATTACHMENTS . ... Ad de.n_d,_,m · 32. I hereby certify that the forego!ng is true and correct to the best of my knowledge Signed & (/~/~J~ ~~ Title Associate Engineer Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". I=n,m I n_~n'7 ;' ARCO Alaska, I~ Pos~ Office Box 360 ' · Anchorage. Alaska 99510 Tele. phone 907 277 5637 - 'I. i.... I.;. f I""1 -.. f. i'-.! '-" f: t.-.'l...I'--'''''''',... r',,, ARCO Al&si(& Ir~¢ .s ] ~ub$1dlary o: B".~rll'Cgllcnhel~JComp~nY ARCO Alaska, Inc~ Post Office : 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 22, 1985 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation -Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Well Completion Reports Dear Mr. Chatterton' Enclosed are Well Completion Reports for the following wells' 2G-9 .2G-10 2G-13 2G-14 If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU5/L51 Enclosures -,'.,, ? 6 190,5 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary o! AllanticRichfieldCompany STATE OF ALASKA ALASKA ~,.~,. AND GAS CONSERVATION C~MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL I~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska,. Inc. 84-106 3. Address 8. APl Number P. 0. Box 100:~60, Anchorage, AK 99510 50- 029-21140 4. Location of well at surface 9. Unit or Lease Name - .. 183' FNL, 272' FWL, Sec.5, T10N, R9E, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 1484' FNL, 1283' FWL, Sec.5, T10N, RgE, UM 2G-10 At Total Depth 11. Field and Pool 1552' FNL, 1340' FWL, Sec.5, T10N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River Oi 1 Pool 140' RKBI ADL 25667 ALK 2588 .12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 09/02/84 09/08/84 10/28/84i N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+I'VD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 6897'MD,6328'TVD 6787'MD,6245'TVD YES ~X NO []I 1901 feet MD 1500' (Approx) 22. Type Electric or Other Logs Run DIL/SFL/GR/SP/FDC/CNL/Cal, RFT~ Gyro, CBL 23. CASING, LINER AND CEMENTING RECORD ,L SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 116' 24" 202 sx Cold Set II 9-5/8" 36.0# J-55 Surf 2796' 12-1/4" 740 sx Permafrost E & '.';70 sx Permafrost C 7" 26.0# J-55 Surf 6869' 8-1/2" 300 sx Class G & 250 sD Permafrost C 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) 6612' - 6629' 3-1/2" 6540' 6511' 6646' - 6684' w/4 spf, 90° phasing 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A - 27. N/A PRODUCTION TEST Date First Production J Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATEDi~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APt (corr) Press. 24-HOUR RATE i~ ~8. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE ,.~ .... Ai~!-,'.~.; Oil ?, ~'~ "' ..... r~:;,- Form 10-407 GRUS/WC16 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. ~. ':.' ?.":"'.;~:, ::,~i ';'"?(~i~'OEO~'I~'M~F~I~E~R~; .... ' "" : ...... ;~;'f';t ~,:::-.~ "~' ' :'~ ~ :":' ': .... ~" ~';'~"~:~' '~ ........ '" ~' ~':"~:~ ~ ~O~M ~N:~ES~S -. . . NAME Include interval tested, pressure data, all fluids r~overed and gravity, MEAS. DEPTH TRUE VERT. DEP.TH GOR, and.time Qf each phase. . . . Top Kuparuk B 6521' 6046' See attached for EFT results. Top Lower Sand 659~' 6100' Base Lower Sand 676~' 6227' . ~ . . . 31. LIST OF ATTACHMENTS Addendum 32. I hereby certify that the foregoing is true and correct to the best of mY knowledge Signed ~O ~ ~ ~ Tide Associate Engineer Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shoWn) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.): Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". ARCO Alaska, Inc. pOst Office Bo..60 Anchorage, Alaska 99510 Telephone 907 277 5637 RETIYRN TO: Date: !/10/85 TranSmittal No: 4966 PAGE 2 of 2 ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2G210 CPL Cyberlook 2"/5" "Poro" Density Neutron 2"/5 ' "Raw" ': " 2"/5" DIL-SFL RFT "DIL-SFL/GR, FDC-CNL/GR" · 9/07/84 Run 1 6300 - 6800 9/07/84 Run 1 6200 - 6806 9/07/84 - " 6200- 6806 9/07/84 " 2794 - 6838 9107184 " /cat, Receipt Acknowledged: B. Currier D~illing DISTRIBUTION W. Pasher State of AK ~ BPAE Chevron ~ Geology Mobil G. Phillips Phillips Oil Sohio o. Union D & M NSK Ops. J. Rat~mell Well Files ARCO Alaska, Inc.. Post Office i,_._~ 360 Anchorage, Alaska 99510 Telephone 907 277 5637 RETURN TO: Date: 1/10/85 Transmittal No: 4966 PAGE i of 2- ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. OH FINALS Schlumberger , 2B-16 CPL Cyberlook " 2"/5" "Poro" Density Neutron/GR " 2"/5" "Raw" " " "" 2"/5" DIL-SFL/GR 2D-6 CPL Cyberlook 2"/5" "Poro" Density Neutron/GR · 21'/5" "Raw" " " 2"/5" DIL-SFL/OR 9/08/84 Run 1 7950 - 8602 9/08/8'4 Run 1 7950 - 8575' .. 9/08/84' " 7950 - 857.5 9/08/84 " 3356 - 8602 9/07/84 Run 1 8-40Q- 8959 9/07/84 "RunZt 8400 - 8997 9/07/84 :' 8400 - 8997 : 9/07/84 " -4112 - 8997 2G-9 CPL Cyberlook 2"/5" "Poro" Density Neutron/GR 2"/5" "Raw" " " 2"/5" DIL-SFL/GR 9/01/84 Run 1 7450 - 8023 9/01/84 " 7450 - 8040 9/01/84 " 7450 - 80~0 9/01/84 " 2965 - 8063 /cat Receipt Acknowledged: B. Currier BPAE Chevron Dkilling ~Geology' ~~ Mobil RECEIVED. e: , __. . W. ~asher State G. Phillips Sohio Phill'ips Oil Un'ion D&H NSK Ops. J. Rat~mell Well Files ARCO Alaska. Inc. ia a subeidiar¥ of AllanllcRichfieldComl~any ARCO Alaska, In~.._.~ ~ Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 December 14, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2G-10 Dear Mr. Chatterton' Enclosed are the Well Completion Report and gyroscopic survey for the subject well. The portion of the well history concerning the completion activities has not been done yet. When I receive a copy, I will forward it to you. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU3/L07 Enclosures RECEIVED DEC 1 9 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE Of ALASKA ALASK~-~::)~L AND GAS CONSERVATION (. ~'MISSION WELL COMPLETION OR RECOMPLETION-'REPORT AND LOG ,I 1. Status of Well Classification of Service Well OIL [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, loc. 84-106 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-211#0 4. Location of well at surface .......... 9. Unit or Lease Name ~CA, h.._.,~Si Kupa'ruk RiVer Unit 183' FNL, 272' FWL, Sec.5, T10N, RgE, UN , At Top Producing Interval j VEJ~iJ:iED) ~ 10. Well Number 1#84' FNL, 1283' FWL, Sec.5, TION, RgE, UM,'Surf. 1 2c-10 1552. FNL, 13/+0' FWL, Sec.5, TION, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) J 6. Lease Designation and Serial No. Kuparuk River Oi 1 Pool 140' RKBJ ADL 25667 ALK 2588 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. J 15. Water Depth, if offshore J 16. No. of Completions 09/02/84 09/08/84 10/28/84I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 6897'MD,6328'TVD 6787'MD,6245'TVD YES [~ NO [] 1901 feet MDI 1500' (Approx) 22. Type Electric or Other Logs Run D IL/SFL/GR/SP/FDC/CNL/Cal~ RFT~ Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 116' 24" 202 ~x Cold Set II 9-5/8" 36.0# J-55 Surf 2796' 12-1/4" 740 sx Permafrost E & .~.70 sx P~.rmafro~ 7" 26.0# J-55 Surf 6869' 8-1/2" I 300 sx Class G I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 6612' - 6629' 3-1/2" 6540' 6511 ' 6646' - 6684' w/4 spf, 90° phasing 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE }GAS-OILRATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATEDi~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press, 24-HOUR RATE "Ir 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE RECEIVED DEC 1 . Alaska 0il & Gas Cons. Commission Anchorage Form 10-407 GRU3/WC01 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE , NAME Include inte~al tested, pressure data, all fluids r~over~ and gravity, MEAS. DEPTH TRUE VERT; DEP,TH ~-GOR,aa¢;time. ofeacb phase..~ - ':". :-'L - .. ....... . ......... _ .~, :, · Top Kuparuk B 6521'' 6046' See attached for RFT results. Top Lower Sand .6593' - 6100' ............ Base Lower Sand. - .6763' 6227' .:~; .. ~:.' '~.: .... .......... : .... - .. . . . . 31. LIST OF ATTACHMENTS : 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~~ ~~ Title Associ ate Engineer Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this fcJrm and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached' supPlemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in; Other-explain. Item 28' If no cores taken, indicate "none" Fnrm 1 C1-4C17 ADDENDUM WELL: 9/11/84 10/16/84 2/lt/85 3/20/85 3/21/85 2G-10 Arctic Pak w/42.3 bbls PF "C", follOwed by 57 bbls Arctic Pak. 6787' PBTD AFE 902209 Rn gage ring/JB/CBL f/6765'-4940'. Rn GCT gyro f/6734'-surf. Good cmt bond. Pmp 145 bbls gelled diesel in 5 stages. "A" sand frac grad average 0.66 psi/ft. Frac well in 6 stages w/262 bbls gelled diesel, 3,400# 100 mesh & 14,800# 20/40 mesh. Rn CCL/Temp tl f/6747' 'WLM - 6100'. Release well to Production. Drilling~ Sup~-~int endent RECEIVED MAY 0 Alaska Oil & Gas Cons. Commission Anchorage ADDENDUM WELL: 9/11/84 10/16/84 2/11/85 2G-lO Arctic Pak w/42.3 bbls PF "C", followed by 57 bbls Arctic Pak. 6787' PBTD AFE 902209 Rn gage ring/JB/CBL f/6765'-4940'. Rn GCT gyro f/6734'-surf. Good cmt bond. Pmp 145 bbls gelled diesel in 5 stages. "A" sand frac grad average 0.66 psi/ft. Drilling S~peri~tendent Date . '~' ~ .~ ~'~. '~-_Z~ ~'.~ . ( . .". ' . ~~'.~._ ' '-. ~'~ .~..~A.. ~ ~ .... ~; ~¥,~-. - .~ ~as~,,;':"- ~ '~ '.~~~" North Slope Borough Alaska me,d .... - I.I [w.,, .o. Kuparuk River ADL # 25667 [ 2G-10 A.I~ or W.O. no. _ Ti le AKE 902209 Drill, Complete & Perforate Doyon ~9 API 50-029-21140 IARCO W.I. o~retor' ARcO Alaska, Inc. 56.24% SpuddedorW.O. beg~ [Dm I.our PdoratatuaifaW.O. Spudded 9/02/84 1015 Hrs. Date and dep~ as of 8:00 Lin. 9/04/84 9/05/84 9/06/84 9/07/84 Complete meord for each day reported The above Il cormctl ~ Signature 9-5/8" @ 2796; 2850', (2793'), Drlg Wt. 8.9, PV 3, YP 3, PH 9, WL 12.6, Sol 4 Accept rig @ 0800 hfs, 9/2/84. NU riser & diverter sys. Spud well @ 1015 hfs, 9/2/84. Drl 12¼" hole to 2821', C&C, POH. RU & rn 70 its, 9-5/8", 36#, J-55 HF-ERW BTC csg to 2796' w/FC @ 2715'. Cmt w/740 sx PF "E", followed by 370 sx PF "C". Displ using rig pmps, bump plug. CIP @ 1100 hrs, 9/3/84. ND 20" Hydrl & diverter ins. Perform top job w/50 sx PF "C". NU BOPE &tst; OK. RIH w/8½" BHA to 2690', tst csg to 1500 psi. DO FC, cmt, FS + 10' new hole. Conduct formation tst to 12.5 ppg EMW. 8½" hole f/2831'-2850'. 9-5/8" @ 2796' 4360', (1510'), Navi-Drl Wt. 9.0+, PV 11, YP 9, PH 9.5, WL 7.6, Sol 5 Drl & surv 8½" hole to 4360'. 3300', Assumed vertical 3553', 5° S49E, 3552.63 TVD 10.96 VS, 4028', 15:5°, S33.7E, 4019.48 TVD; 94.80 VS, 4278' 7.24S, 8.33E 61.72E 72.04S, , 19.5°, S37.5E, 4257.86 TVD, 169.38 VS, 133.15S, 105.46E 9-5/8" @ 2796' 5277', (917'), DD Wt. 9.1+, PV 11, YP 9, PH 9.5, WL 4.8, Sol 5 Navi-Drl & DD 8½" hole to 5277'. 4438', 19.5°, S37.2E, 4408.69 TVD, 222.56 VS, 175.60S, 137.87E 4806', 30.8°, S33.3E, 4737.21TVD, 385.54 VS, 310.68S, 231.80E 5186', 36.8°, S39.6E, 5054.17 TVD, 592.49 VS, 483.45S, 349.71E 9-5/8" @ 2796' 6654', (1377'), TIH w/drlg assy Wt. 10.2+, PV 13, YP 8, PH 9.5, WL 4.8, Sol 10 Drl & surv 8½" hole ~o 6654'. 5404', 42.7°~ S39.5E, 5221.70 TVD, 73i-.62 VS, 590.89S, 438.43E 6248', 41.5°, S40.1E, 5842.23 TVD, 1302.61VS, 1033.92S, 800.26E 6598', 41.7°, S42.3E, 6103.96 TVD, 1534.90 VS, 1208.'75S, 953.31E Drl RECEIVED DEC I 91984 Alaska Oil & Gas Cons. Commission Anchorage Drilling Superintendent JOat. 9/26/84 For form preparation and_distribution, ARCO Oil and Gas Company Daily Wel 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 Sold. "Final Rapo~' should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovere when an official test is not required upon completion, report completion and representative test dataHn blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District Alaska Field Kuparuk River Auth. or W.O. no. AFE 902209 Doyon #9 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded Date and depth as of 8:00 a.m. Old TD Released rig 0630 Hrs. 9108184 thru 9/09/84 Classifications (oil, gas, etc.) - .Oil Producing method Flowing Potential test data ICounty or Parish Lease or Unit Title North Slope Borough ADL # 25667 Drill, Complete & Perforate API 50-029-21140 Accounting cost center code State Alaska IA.R.Co. W.I. 56.24% IDate 9/02/84 iComplete record for each day reported IWell no. 2G-10 Iotal number of wells (active or inactive) on this ost center prior to plugging and I bandonment of this well I our I Prior status if a W.O. I 1015 Hrs. 9-5/8" @ 2796' AFE 902209, API 50-029-21140 6850', (196'), TIH Wt. 10.3, PV 15, YP 14, PH 9.5, WL 5.2, Sol 11 Drl & surv 8½" hole to 6850', short trip to 5300', C&C f/logs. RU & rn DIL/SFL/GR/SP/FDC/CNL/CAL f/6847'-2794' WLM. Rn RFT/GR. RD Schl. Drl 8½" hole to 6897', short trip, C&C f/csg, POH. RU & rn 172 its, 7", 26#, J-55 w/ mkr jt & lnd w/FS @ 6869', FC @ 6787'. Cmt w/300 sx C1 "G" w/l% CFR-2, 5% KC1 & .3% Halad-24. Displ w/10.3 ppg.NaC1/NaBr, bump plug. CIP @ 0045 hrs, 9/9/84. ND BOPE, instl pack-off & tbg spool. Tst pack-off~ OK. RR @ 0630 hrs, 9/9/84. Operations suspended - wait on completion rig. 6750', 41°, S45E, 6218.06 TVD, 1635.29 VS, 1281.41S, 1022.62E RECEIVED DEC I 91984 Alaska Oil & Gas ¢o{~s~ Anchorage INew TD Date PB Depth 6850' (9/08/84) Kind of rig 9/09/84 Rotary Type completion (single, dual, etc.) Single · Official reservoir ~me(s) Kuparuk River Well no. Date Reservoir Producing Interval lOll or gasTest 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 ~ · For form preparation and distribution, see Procedures Manual, Section 10, JDate ITitle 9/26/84 Drilling Superintendent Depth 6529 6543 6555 6554 6615 6617 6651 6657 6666 6683 DS 2G-10 RFT Results Hydro. Pressure 3297 ~si 3299 ~si 3307 ~si 3298 ~si 33i8 ~si 3319 ~si 3331 ~si 3335 ~si 3338 ~si . 3348 ~si Shut-in Pressure 3063 psi 3087 psi 3090 psi 3085 psi 3098 psi HILL/O3'tw RECEIVED DEC 1 9 ~aska Oil & Gas Cons. Gommismon Anchorage c~RILLING AN,'HO~.GE FILE COPY AI~CO ALASKA. INC. $ UB-$ URFA CE DIRECTIONAL SURVEY F-~I UIDANCE F~-IONTINUOUS I-fl oo L Company ATLANTIC RICHFIELD COMPANY Well Name 2G-10 (183' FNL 272' FWL, S5, TION, R9E, UM) Field/Location KUPARUK. NORTH SLOPE. ALASKA Job Reference No. Date 6 9654 07-0CT- 1984 LoDged By: Computed By: BE UTLER/WEST COL SON METH[3D.~ I'"![;' COMPUTATION V ? ~,,,I "r' i c' A f~ q'ANGEINTI~L- averaged der i{OR?Z. ~IS'r, P~DjECTED ARCO AbASKA, INC. 2G-10 KI.!PARIIK NORTH SI. OPE, ALASKA O.o0 0,00 -!4n.00 ....... 0'" 0 N 0 0 F. 100 Ou 100 O0 -40 na~,,-u"'":o~'.~.~ N 36 31 E auo oo 3oo.oo ~o ~ ss sa w 4on,no 3~.~ ~5o~9~ .o ~ 60 22 ~ 500.00 499 9o 350,99,: ., 0,(,~5 N 52 ~7 W ~00.~0 509:90 ~'{q,~q' :" '0,4 S g8 t7 W 700,OU b99.Yc} 559.99 0 38 S 75 16 W ~00.00 7Qq.9~ 65n,~ 0 ]7 S 78 47 W 900.00 SOg.gR 759,08 0 25 S 8~ 0 W 000,0!3 9°9.98 Rbg q8 0 20 N 68 20 W ~00.00 ~0~9,97 ~59:97 0 18 N ~0 i6 W 1200.00 1199,¥7 10b~,97 0 10 N 47 7 E 1~00.00 12O9.97 J15 .07 0 ~ S '33 20 E ~400,00 1399,97 1259,~7 0 1~ :21:59 E 500.00 ~409.99 1359.~7 0 ].~ S 42 47 W 1600,00 ~599 97 1459,9/ 0 24 S 82 ~ W 1800,00 1.7q9,97 1659 97 0 ~5 $ 87 39 W lO00 O0 ~809 97 1~59'07 0 14 ~ 55 25 W ,. . . , , ~ 20O0,00 19q9.g& 1~50.06 ~ ,nO 2109.9~ 2n59,o6 2300.00 22g9,96 2159.0~ 2400,n0 ~309.96 2259'q6 ~509,00 2~99.96 2~5~,9b 260O.00 75~9,96 245 .q6 i~O0,O0 ~699.96 2559.9~ O0 O0 77~9 95 26~.~95 3000,00 2999.95 2859,{15 31, On. O0 3099.9~ 2050.95 3~0. O0 ,1 99,94 3(,59. q4 0,00 ~209.94 31 ~0~94 O0 3409.77 3359. 3600,00 3599.35 3459,]5 3700'00 ~b98 '.43 3K5P.43 3800.00 3'/90,15 '3900.00 3{'~4.35 '2,00 '2.]2 "2,71 -3.30 -3,76 -4o2~ -4.72 ... '5,64 -5.80 -6.~9 -6.5 -7 COMPUTATION ARCO AbASKA, INC, 24-10 KUPARIIK NORTH 1N'IERPOLATEr) VALUES 4noo. o s 4100,00 4087~05 4~Oe,~O 4~2.01 4042,uJ $ ~ 4 4300~00 4276~4] 41 ~6,4~ 4400,00 43~0,6~ 4230"~8 Y~" .35 ~ ~g 460n.~0 4556.05 ~416,05 ~ ~! S ~5 11 4700,00 4044,'10 4~64,70 2fl 15 S 35 28 4~0o.00 ~731.81 4900,00 4817,~ 4677,48 60U0.00 5t, St~.51 5K16,51 42 24 S 38 39 F ~,00 5730.5~ 5590,58 ,2.2 5 S ]U 44 E .h0 5904.9(3 56~4.00 ~1 48 S 38 5~ F 6300 00 5~79,07 5739,67 41 27 $ 39 2 F 6400~00 ~954.84 5~14.~4 41 14 S 39 3 E 6500 OO 6030.07 bBgO 07 41 22 S 39 2. E ' 6600:00 6104 92 5904]03 41 3~ $ 39 26 E 4~5,26 53g.84 597.6~ ' ,, ; 660.4 95. ZO01~ 1136,50 1203.~ 140~. 1468, {600 666 5000.00 4902.31 4767,31 32 36 'S~ 28 57 F, 5,00.0,0 49q5,54 4."45,54 ~4 ~ ~? ~' R 53 oO ~144.0~ 5~04: 41 24 38 2 g ~.OO 52t8 151..~8 43 10 $ 5 E 00.00 ~427206 5997.~6 43 20 S 38 Il E 5800 00 5509,04 53~9.64 43 ~7 S 38 ~7 E 590()~00 5582.87 5442.~7 m. 2 43 ~ 38 29 ~ ARCO ALASKA, 2C-10 KUPARI]K NORTH 8T,L)PE, INC. qEASI,IRED DEPT~ 0.00 1000.00 2nOn.O0 3000,00 4000°0O 5000.00 bO00,oO 6897,no TRUE StJn-SE~, """ '':~ COURSE VFHTICAB VER~ICA'b DEV~XA'CIOa AZIMUTH DEPTH ~r. PTH' DEG'~ r M DEC O.On -140.6'0 ..... n ~99.98 859 ~8~ 1999,9~ 1~59~6 .... ' 5656.5~ 5K'k6, 4 6327,~5 b187,85 ~1 10 DOGI,,EG:-<~' :}EC?"i"H(jULAR"':'CO'O'~D'iNRT£$ '~~£eAR'YURIC" VERTI FRET DE~Z'iO0 .... ':"":' ¢~kT ......... :":"" rE~'" ...... :~'~'~~C MXN ..... ., : . -... ..,.,... : . ~ ,:..:'.: ...,..: .:~ ~' .' i .... ,';:.' · ,: 8 N".. ' -W ' ' ..... '~ 9 J3 W '"" '"" ~.tL'''~'''''~':~'~ ....... '~.~"1, ,"'"'":"':"~ ti"", .... '~": ...... :~I, ~ ARCO KUPARUK NORT~ 40,00 140.00 0.00 ...... 240.00 1900.0.0 ' g,::~O 3.~,0 . O0 4 lo, oo 5~0.0~ 4uq.O0 0:13 040 o'~ 50r' O0 0 22 740.'}o ~On.nO 0 40 ~4U.O0 700~00 0 29 40 O0 140~00 240 O0 340~nl 440.01 540.ol 64o.01 740.ni 840,02 N 0 0 E N 37 59 E N 30 20 W N 6'1 59 W .~ 59 .51 W N 55 13 w .~ 632 S 81 44 w $ 78 24 W S 7W R W 0 20 N Bb 12 w 0 18 ,~T 60 40 W o4n 02 94u.()o ~uo oo 1040:02 104(3.,')0 000: O0 1140 03 1140,00. 1000 OO 124n:03 124G.00 11 o0~n(') 1340.03 ~40 Uo 1200~00 1440,03 1440'0a. . 540,03 1540.u0 14.~.)(') ~ O0 64o.n3 1 b.~O. OO lSOO.nO 740,03 1740;00 16O0.Og lq40.n3 1940.0C~ iP()O.Ou 0 14 ~.t 51 '28 W 2040,0~ '2040.00 1.000 O0 u 7 N 19 54 W 2~4A n4 9140 on 2000' , . , ,00 O 13 S 73 1 W ~]40,04 ~3,t0'00 2~00,00 0 2n %{ 39 13 W 2440,04 2~4.0,0n 2300.OO 0 15 N 31 47 W 2540.04 2540,00 240n.00 0 i3 N 67 24 W 2640,04 ~040,00 250 ),Og O ~5 S 48 W 2740.04 2740,00 2600;00 0 25 S 2 W '~.~8~,:,0'~,05 2840,00 27:0.0,00 ..0 o 0 30 ~ ~1 33 E E 2 S ~3 4 5 3 ~ 49:35 E 7 26 50' 42 E lO $'41" ".2940,05 2940,00 2800,00 "3040.05 3040.00 2900.00 3140,05 3140'00 3000,00 3440' 3340 O0 32L)n, O0 ]40,3b 3540,00 340n,o0 ~: 640,05 3040.00 3500,00 42.. 3740~ , · '" 44' 3840.00 37 o,no VERTICAl., 5ECT£ON FFET 0.00 -0.64 t,70 -2.4b '?,94 '3,50 6, 6, :76,74 ,30 -7 86 -~ 30 -8 -8 4,6~ 15'41 COMPUTATION DAT£: ARCO ALASKA~ INC, 2C-10 KUPARUK NnRTH SI, OPE, ALASKA INTERPObATED VAI,UES ..... "~?~'~'~ COURSE DEPTH DFPTH mKPT~'. .... ~E'(; '~IIN DEC, MTN 3~47 07 3940.0n 3ROn.O0~' ...... '~';I'"'"~8 S 37 23 E 050:82 4040,00 3900 00;?:..~:~5 S 37 28 E ~201,3'1 4240,0n 4100.00'<,,~,~;~::~19 S ]8 1.3 ~ 4367,44 4340.00 42nn.O0 ~'i'g.~20 S 39 39 ~ 4694.67 4640,00 450n,00 28 9 S 35 33 E 4926.49 4~40.0o 4700,00 31 4R ~ .29 32 ~ 5044 Q9 494U.uO ~800,00 33 34 S 32 29 E 516a:kb 5(')40.0o 4ouo. O0 ]5 4~ S ]7 43 E 5420.30 ~240,,.)0 5100~00 4 0 S 38 1~ ~ 5566.39 53.40.00 52~n nO ~3 19 S 38 1~ E 5704'05 ~440.00 5~" 0'0(.,. 43.. 20' S 38 11 F 5841 59 55aU.O0 54O0,00 42 56 S 38 25 E 5977~63 ~640,0n 5qOn.nO 42 2n $ 38 35 E .'t~l~,6~ 5740,00 5600,00 4~ 4 S 38 4~ g .~1, ~40.0o 5700.a0 41 35 ~ 39 E 6380.27 59,!0.00 5fl()~,nt.~ 4t 11 $ 3q 5 ~ 6513 2~ 6040,00 5OO0.O0 41 25 $ 39 6 E 6~46~09 6140.0n 6000.no 41 45 S 39 36 }q 678030 6240 O0 b{O0 oO 41 lo S 39 49 E 6897' ' ' .00 ~3~7.~5 6187.~b 41 10 S 39 40 M 509 5 656,3 747"4~ 840,q8, 935.30 ~.44029'45 .. ' 86 S 3'7 34 E I ' '' ARCO AbA~KA, IN¢, 2C-10 NOR?H St. OPE, ~LASKA NARKER .I. NTERPOI,A'TED VAI,[IF,$ FOR OW 65~J,00 6593,00 6787. 0 6897.00 6~99. 62~6, 62 RgE~ Ua" WEST ......... · 8.2 ~. ,,,,, :~ ARCO RbAGKA, 2¢-10 KUPRRUK NORTH MARKER TOP KI!PARUK B BASE IIpPER SAND ~A~E LUWER SAN[) PRTD TOTAl, DEPTH COMPU?ATZDN DATE1 6521.0~ 6593,00 6897,,00 FINAl T R U F: MF. ASURED YFHTICAL DF, PTH DW. PTH 68~7.00 6327.fl5 AT SUB-SEA P T'H 61~7.85 SCHLUMBEROER " ARCO ALASKA, '! NC. 20- lO KUPRRUK NORTH :,SLOPE. ALASKA 12 OCT 84 TVN PLOT FROH GCT DATA JOB REFERENCE 69654 ?WELL:: 2G-10 SURFACE LOCATION: 183~_~NL, 272' FWL, S5, RION, R9E, L. HORIZONTAL PROJECTION -1500 -IOC~ ,WELL: 2G-10 SURFACE LOCATION' 183,,~/NL, 272' FWL, S5, TION, R9E, b VERTICAL PROJECTION - 1CLX) -SIX) 0 0 500 ~ ~ ~.~.;~l~ i ~ ~ ~' := ~:; : ~ ; ;. ; = : ;': '~' ;=; =~ : ~=; :i= ~'-~'~'~'~'~ ...... ~"-~'~'+~'~'~ 4...;..,..~. .... ~-~..~. ~.4..~. ~.~. ~ ~ ~ :~:- ,: ;::: ~ ~ .--~.~ ~.~- -~-.~ ~-'- ~- .~--~.-~.~ -.:---T.-~--~- ..~-4-4-4-. -~.4-~- ~. --~.~.-'-~" ~.7--~ ..... *..,.','-,.. 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DEPI'I.15 HOR]Z SCI:M.E . ]/500 IN/FT $ UB-$ URFA CE DIRECTIONAL SURVEY F-~ UIDANCE F~ONTINUOUS F-~ OOl RECEIVED [.)EC ! 9 Alaska Oil & Gas Cons, Commission Anchorage Company Well Name , Field/Location ATLANTIC RICHFIELD COMPANY 2G-10 (183' FNL 272' FWL~ S5~ TION~ R9E~ UH) ~IlPARUK, NORTH SLOPE, ALASKA Job Reference No. 69654 Logged By: BEUTLER/WEST Date 07-0CT-1984 Computed By: COLSON C HL~'ro~IE~ 2 (; - 1 0 OCT 84 ARCO ALASKA, lrlNl(:, 2(;,-10 KI~PARIIK NORTIt SI,OPE, ^b~.Z,~ 1 O0 o 200. n() 3~0 0() 3o0 uO 4on: no 500 OD 4q9 99 ~0n~no 5~9'90. 700, Ou RO0.O0 709.9P 900,00 Cn/JPSF: ',/rjRTT CAL r')ddbF. G A?,'[NUTIt SECTION SEVERI'r¥ l)V'.~j MTN FFFT DEG/IOO N ,) 0 V 0. ¢)(, 0..00 "' ]6 31 E -0.02 0,36 rc h3, ti W -0.~2 0.24 N 66 5'4 W -0,9~ 0,15 k' 6,) 22 W -1.48 0,0~ ~ 52 47 W -2,00 0,12 g 8B 17 W -2.32 O. S 75 ~6 W -2.71 g 7a 47 W -~.30 0.18 S 81 0 W -3,76 0,07 nbq.q8 O 20 N 6~ 20 W '4.21 0,19 qsq,q7 0 ia N 60 16 W -4.72 O,3 1 1059,97 (J 10 N 41 7 E -5.08 0,28 1159.o7 0 q ,~ 33 20 E -4,00 0.3R 1259,97 t) 1~ $ 21 59 E -4.69 0 11 J~sq,q7 0 lq S 42 47 W -a.46 0~31 1459,91 0 2'~ ,s a2 35 W -4,65 0.41 15b0.9'1 0 2h r,l 7I 23 ,4 5.17 0.07 0 ~b 5 8] 3q 4 -5.64 0,6~ 1 ~ :'J 'i5 25 W -5.~0 0,17 1 ilO0 , O0 170.9 . 9'f 1659 , 97 1000.00 ! 809.97 t75q.07 2o(jn.n0 19qg.ga lqbq. O6 2100 O0 2099.'~6 195q,gb 2300 O0 22q9,96 2159,q6 240o~n0 9309.96 225q,q6 2500,00 2~99 96 2~sq,gb 2600,00 ?~q9~96 2456.96 2700.00 2099.96 2559,q6 2a00 aO 97~9 9q 26'3q 95 2900.0~ 2899.95 2759.95 0 30 N fit 22 E -7,06 ,) 26 "75 21 F, -6,62 0 31 $ H4 2 E -6.04 2 2 S 6t b5 E -3,fl8 4 5 g 48 52 ? 1,48 ~ 24 S SO 1 E 10.$,t q 13 S $(.) 5l F 23.87 S 43 q E 41 .gq $ 38 o E 63.76 3000 00 2999,9.5 28bO,qb 310n.~0,) qOq9,9q 2°5°.95 3~00 O0 ~lq9 94 3300100 3299.9.1 315q,q4 ~400.00 3399,91 3500.o0 3409.77 3!59.77 ]600sO0 ]bgg.35 345o,1b 3700.00 3008.43 3800.00 3790. 15 3656,75 11 33 3900.00 3804,3~, 37!i..'1,35 13 3'7 u,38 O,5g 1.28 0,64 1,86 2,21 , 3 · ';': .'~.*. ~ "t!i!~. ~.' ~ ~':.'..>' PAGE DATE OF' SURVEYI 12 OCT 84 KELLY BUSRING ELEVATIONI 140,O0..E~ ENGINEER: BEUTSEB, WEST · , ,. . StIREt) D~PTH .... - RFCTANGI][,AR COORDZN TES'HORX$',~DEPARTUB~ NORTH/SOUTH EASTIWE8~ D~.~[[IMUTH:~.f. ~ 1: o,oo o,oo 0,25 N 0,25 E .0~~4 20.E . ' 0.57 °'57 w 0~, " 0,79 N O, ~.06 N 1,04 W ~ I 4. 37":W. 1,47 . 1,8~ W 1:'::' 1.J3 N 2,56 W '~.88 N.:62.~]5;.1-:: 1.0~ N 3~69 ~ 3,84 N '~::33'.'~' 0,92 N 4.54 ~ 4,~3 H 0,98 1,23 1,62 1,60 1,3] 0.98 0,72 0.84 1,00 0,97 1,32 N 1,,4R Iv 1,4~ N 1,3q N O,f13 N 2,38 S 8,30 S 16.78 $ 29.23 S 45,70 ..q 5,14 .W 5.63 W 5,74 W g: o w 48 W 5,53 W 6,08 W 6.72 W 7,23 W 7,51 W 7 81 W 7 94 W 8 30 W 8 00 W 8 99 W 9 28 W 9 65 W 9 95 W 10 O0 W 9,80 W ~ 99 W 8:15 w 7,36 W 6,40 W 4,53 W 0,40 W 6,55 E 17.02 E 30,24 E 44,39 E 9 9 10 10 10 2 10 23 42 63 ARCO AhA,SKA, 2n-10 KUPARIIK NO},iTH 5'r.,l)Pt.], AI.,A,SFA CF~MPu?A'I'ION DATF;: 6 hOV 8,1 1N'.I.'ERPt)I,A'PE~) F.o Fill.', EVE~': 100 4100.00 4087 05 4~0o.00 41~2~01 4049 4300.00 4276,4~ 4400.00 4370.68 .i23o. ~ q 4500 O0 4464,61 460n~00 45K6.05 -.416.05 .... ~6~31 4700 O0 4~44 70 4504.70 28 15 48o0~00 ~731~81 4591.~1 30 22 4900,00 4817,t8 46'17,48 31 39 32 36 41. 24 42 44 4.3 10 43 20 42t 2n 43 17 a2 4~ 5000,00 4902,31 47~2,31 5100.O0 4995,54 4R45,54 .5200.00 5067 01. 4,927 01. 5300.00 .5144!65 ~400.00 5218 4, 5o7R,4, 5 00.K ,00 5201,6,q 515~ 56.00, O0 5364,47 5224,47 5700. O0 5437.06 5?97.0~., 5800,00 5509'64 5]bg,64 5000.00 .55~2.87 54,i2.'~7 42 2! 42 ~ 1 48 41 27 41 14 41 2? 41 27 41 10 60U0.O0 565u.51 69. ,{30 '5804,90 &]00,00 5U79,O7 57]9 67 6400. O0 K954,84 5~ ~ ~ ', q4 6500, O0 6030,07 b~90 07 6600,00 ~104.93 ~700,0U 6179,U2 b03O 6~ 6~00.00 6254.~ 61 6897,0U 63~'1,85 O1~7,8b V K; F~'t' T C A I., 5ECTI~IN FEFT 88.77 116,92 181 02 2L4:36 248.60 28R,68 334 , 58 ."t83,18 433,80 4U5.20 530,84 660, 727,65 795.59 863,9a 93~.52 1001,10 1136.50 1203.52 t270.77 1!36 53 1468 Il 1534~79 1600,69 1666,51 1730.29 8 86 543 799,?~ 693, S' ' 855.3 $ 073,88 '4 30 3:71. 0,15 0,43 0,58 0,17 0,87 u,06 0 5~ ~ 21 .0 69 o 49 0 26 0 4g 0 95 0 O0 O,O0 901 960 1012 1064 1115 1166 1218 1269 1319 1368 .22 S 691 63 S 73 78 S 77~ 39 S 817 57 S 858 { S 9O0 8 S 9.4..2 0 $ 984 '90 S 1026 94 S 1067 56. E 1208,69 48 E 1275,5R 85 E 1407',88v's,,13 35 £ 7! 'E 1606,48 82 £ 1736,16 ARcr] AbASKA ~ lO00,OO 3000.00 400~ogO 5000.00 bOOO.nO b897,~0 V FI~'I'I CAL DtFPT,t 6327,~5 CO a PU T,~,T j r~ h I)AT~:: b N[1V d4 S ~, C'T IF)N -4.21 -F.19 -7,06 ~R.77 485,2b J136.50 ,t730,29 t"F[':T f IF S ~.; V' E R 1 T y r~Eq/100 0.00 O,10 O,2g 0,38 1.OF J,lfl 0.51 O,O0 p a DA'rE OF SURVEY1 12 OCT 84 ',~, F KP:LLY RUSHING EbEVATIONI 140 (JO::'" ~I".:.:: EN(;IN~ER: BEUTLER~ WEST ., .... MF'AStIRE!~ DEP1' NORTH/SOUTH F E E T O,O0 1.21 1,32 65,75 392 04 908~22 1368,94 COOP EAST FEE O, 5 59, 1067 /WES~ D $. ' oo oi'o °' 14 W 5~ '".9 81 w 7' 65 E 66 E 48 82 E ~736~6 ~ 37 ARCO ADASKA, 2C-10 KIIPAR/IK i~lOR"rH ST.,or)F;, T R U ¢. MEA~IIHEO YEkTIC DEPT;4 i)FPT 4~,00 40 240.00 240 440,01 4t0, 540.~t 64o.01 o40, 740.01 740, 840.02 840. 940 02 940 1040'02. 1040~ 1140 03 l~4n~03 1240. 340 03 540 03 1540, 640~a3 1040, 1740,03 1740, 1~40.03 1q40,03 1940. 2040 2,4~:n4 21 40. ~24~.04 2240. ]4 ,04 73.10. 440 04 2440. 2640 04 2740'04. ~740, 2840,05 2840, 2940,05 2940, 3040.05 30a0. 3140,05 340,06 334~, ~440.12 34q0. 540,'to 3540, 640,95 ~640. 3742 20 3740, CF;MPUT,~T[(IN L) A'fE: b NI.}V AbASKA IN'rEaPObA?~[) VAI,tlF',i FOR EVtCel tOO S ti D-,~ c:lk C"~ ti P..% F V I... R'I !CAI, Al, V[;]RI'ICA.Ia.'~EV,IATiilh AZI?~0qL'H bECTLON H r) i.: F"[' FI' ' D~' 't,i T i ~ I)F(; ~.!TN 0(', - 14n.~~0~~~ n t,; () 0 E n. OO On o,O'ff'~'O'· ...... 14 ,' 3(~ 2n w -,,o.10 O0 lOO.~L:[ 00 20 N 6'1 b(' W -0.64 OP ?,')0. lq ~: 59 r~l w -1 .1.6 O0 3,,0 ~ g I" N 55 ~3 w -1.70 O0 50*: O0 0 22 S 81 ,t4 W -2.4b O0 6OntO0 0 40 S 78 24 W -P.94 O0 700,00 0 29 S 79 R W go 8u0 oo 0 20 N 8b 12 W -3.92 30 gO0~O0 0 1R ~ 6,') 4n W -4.42 0o 1100~00 0 o N R6 12 P -5.05 0o 1200 O0 0 R S ~0 lo w -4.84 0n l~Oe~oO o 12 8 o 50 ~ -4.56 O0 140(),00 U 20 $ 61 13 W -4,49 :.)0 IGO0,f)O 0 lq ~q 72 2a W On [70n,n0 0 e .$ 51 ~ w -5.69 UO iP00.0~) 0 14 ~' ql '2g W -5,q7 . 2nOn,O0 0 l 3 $ 7 l] 1 W O0 2190,00 ~l)14 W 35 36 W -6,74 OO 2~00.00 0 2n ~ 39 13 !4 -7.~(') U() 2]00,OO 0 15 q tl ,i7 W On 2iOn.qO 0 lq t.l 67 24 W -R,30 0(.) 25()0,0{~ O i5 S ,1~ 1.6 W -8,52 0() 2700,00 0 Il S 1H 8 E -7.80 O0 2ROO.f)O L) 28 N 8b 42 E -7.3b On 2~O0.qO 0 2p ~ l ~ ~0 4d ~? -6,a6 V0 toOo.nO O 30 $ H1 33 E -6.40 On ~1 .7)0.~l,,) ().]0 N Ro ,~ },~ -5,75 On jtuo.q0 2 4~; S s3 42 F' oO ]4Oq. O0 5 3 8 49 35 F' 4,68 O0 3500.00 7 26 S SO 42 F 1.5.41 O~l 36U0,00 10 2.t S 4'7 26 E 31,04 O(1 3700,n0 !2 26 ~ 4i 0 F 51.18 KEt,LY BUSHIN~ ELEVATION ENGINEER: BEUTbER~ WEST ':~ FfiPT (]F SUB-SEA DEPTH ,~ nuqb~:(; RPCmAHGUaAR COORDINAT .S HOR'I~'DgPAR~URB ~Eq/1 O0 FEET PEET FEE~{~EG ' ' o. o. oo . o.oo E t),6P 0.35 N 0.23 E 0-4~N~3 21 E 0,13 0.88 N 0,76 W 1' ~ 0,11 0.21 0,57 0,07 0,41 u 19 0,09 0,30 0.1~ 0,34 0,30 O.OR 0,09 0,16 0,49 0,1.2 0,06 0.18 0,19 0,42 0.13 0.10 0,19 0,34 1,b.7 2,31 1 8,9 0.91 N 1,OR N 1,39 N ~,67 ~ 1,50 N i,lg N 0.85 N 0,74 N 0,92 N 0,95 N 1.07 1,29 1,24 1,41 1,86 2,31 2.fi9 2,56 2.'01 1,3g i,27 1,37 1,48 1,41 1936 0.07 4,4~ 11,4~ 21,47 36,04 1,62 .W ,04 ~,0~ W 4,07 5 78 W 5 63 w 5 50. W 5 44 w 5 70 W 6 36 W 6 94 W 7 37 W 7,65 W ,86 W 8,07 W 8,42 W 8.75 W 9,10 W 9..44 W 9,79 W 9,96 W 10,01 W 9,47 W 8,64 7,84 6 96 W 5 96 W 3 14 W 2 05 E :o 22,50 36,41 E. 4 5 5 5 5 5 5 6 9, 10, 10, 10, ? , 9 55 8 75 15 51, a2 W . N N 10 N 14 ,5 88 4 W' ) S '24 111 S 42 2(';,"1 N E A $ I J R K D 3q47.07 4050.H2 4261 , 37 4367.44 4473,71 4582,10 4694,67 ,1804o 50 4~26.49 5044. 5166, 5293, 542o. 5566. 5704. 584~, 5077. 6513, 6~46. 67~0 6897 0,9 39 ~9 63 6~ '7'1 O9 O0 'I'RU v 37,10. On 4040. On 4140. 4240.0n 4340. ,,-)th 444U,00 4540..r~ n 4640.90 484U, 5() a(;, O0 ~14C, Oo 5240 ' UO 5340. o0 q 440.00 5b4u. OO 5640.0~ 5740.u0 5840. OO 5940.()~ 6040,0n 6140.00 6240,00 a3~7.~5 20 21 25 43 28 q 3(3 2q 31 ,4a V~:P 1' 7 lb 20 t3 44 ~' v ET 2,64 4. o0 fl .2() 3.5U q.38 o ? 7 7,41 SEVERITY Df'j(;/ 100 2,21 76, 1.54 101. 0,81 128 o.sa 15b~ 1o81 183, 5.15 217. 2,19 259, 2,31 305. 1.b7 357, ~77.46 2.72 468. 7/17.4 . , 0 bO2. f140,q8 0.44 675. ~3s,~() 0,16 750, 1029o45 ~,~0 824, 1121.44 f). a 896, 1212.00 U,07 967, l~01.49 0,70 1037. 0,38 6.8b 5.52 0.29 0.63 1105. 0,56 1173~ 0,5q 1242. 0,00 1309', 0.00 1.368. P A G E ' ' :::::..i::.~:i, § ::~:, :L:';?:..:'::,,,, .:':!i! DA'Fk: OF' SURVE¥~ 12 OCT 84 : .. ,c,,.: ,..,,:, KF:I,t,Y PUSHING ELEYATIONI :. ~ ::1,:, ,:: :,.: ENC;TNFER: BEUTLER~ WEST ,""::,,',,:~/ :..,.i, ,- ., : .:,!, 1') EPTH , ~,~ GUI,Ah: CInORDINATE$ HOR"i~'~:~'~pARTURE a4 s 5 1.38 83 S 68,08 F,102~,~~~.-32~E '. S3 S 87.57 E 31 S 108:97 E '4u :~ ~2 S 131 22 64 E .84 s 3e 49 240'5 E ,13 8 38lO E. E 86 S 271,90 E S, 37 I3:E ',::'" S 36 18::..E:::.' ::: 24 S 67 $ 2O S 74 $ 10 S 25 $ 43 S 303 06 E 344 30, K 39 E 507 73 E 566 22 E 024 69 'E 682 11 K ,14 E 47 S 850 55 S 9'05 22 S 962 94 $ 1018 94 S 1067 239 332 389 449,44 51 46 58~:54 660 06 751 49 845 1034 22 1126 4~ 66 E 1394 62 E 1659 82 E 1736 88 50 28 · [_ :--li_ ARC[') AL, ASKA ~ 2~,-. 1U NORTH ,%[,[")Pk~, ^i-/~,SF, A MARKt"YR BA,51F I.,['}I41~R gAND TOTAL DFIPTt'i C'tJf',iP,j't'ATIflN l) h'i'~.~; 6 I~,}(1V i3/1 ,, n g P'.i.' H 65c~3. 6763,, (,'0 67q7. Oe FIIC}}" 1-' ,~ r]RIGTN= TVD SUB-SEA 183" FNL, PAGE p^Te: UF ~URV[:¥~ ~2 .OCT ~4 ' ~ ' ~ ~:~ , ' . . , ENG~NFER: BEUTLER~ WEST RECTANGUBAR~ATE8 - , :a~: ,'-- 1301.20 $~~'~A'~2 :.B.'.:'":~ 1 ~ 1 ]. ] 3 s ~'9-~1; . . BA6E I~PPER PRTO TOTAI, DEPTH FINAl MFASURED ~FRT1CAI, VER'F]fiAb DFPT~~ [~PTj~ DEPTI~ 6~07. On PAGE 7-'". ': DATE OF SURVE~ 12 OCT 84 . KEI~LY hUSHING EbEVATION: 140.00 FT ENGIHFER~ BEUTLER, WEST SUR-SEA fi9o5,82 5959.70 6086,98 61~5.04 61H'/.B5 272; FWL SEC 5 ;. . RgE-, ECTA~GULARi~ ATE$ NORTH/SOIJ/ WEST 1313,33 ' 1368~94 ~ UM !:34 E 82 g' SCHLUMBEROER ARCO ALASKA, INC. 2G,-IO KUPARUK NORTH SLOPE. ALASKA 12 OCT 84 TVW PLOT FROM OCT DATA JOB REFERENCE 69654 :,~ELL- 2G-10 SURFACE LOCATION- 183' FNL, 272' FWL, S5, RION, R9E, UM HORIZONTAL PROJECTION .... ,,~- ..,.~-.,~-..-~..,i.--,~,..4,.. · -4.4-.,--~. ..... ~...-;-.-~--¢.-. . ............ ..~..~..~..¢ .... ~.~..;..~.., ..~..~-.~.~ ....... ~-~-~-~..~..~. .... ~..~..~.-~-..,.~-.~-~..~..~..~.-~..~ ..~...-....~...~..,..~..~ ..... ,.. .... -:..~..~..~..~..~..~..~..~..~..~..~..~..~ .... ~..~..~..~ ...... ~..~..~..::~::.~..~..~ ..... i..~..~..i..}...Li...!..~.. · -~.,~.~.~..,.,~-~,,-~-..~-~-~-,~...~-.~..~-..~-..-~-.'..-~.~-.~--~..~..~..~ .... ~..~-.~..~..~..~..~.-~-~.~ ..~-.~...~.~...~..~..~..~..~ .... ~..~-.~..~...~..~..~...~..~...:..~..~..~..~...h%~...~...-?::!::~::!:::::i::!::!::i:: - _2cJ~__ -20~0 - 1.__~00_ - l__r~Ll_ -~ 0 SOO ' !,tELL: 2G-10 SURFACE LOCATION' 183' FNL, 272' ~L, S5, TION, R9E, ~ ; VERTICAL PROJECTION -~ - 1~__~]0 1~0 -~0 0 0 ~0 10~0 1~0 ! i : : i ! 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I : : / '- i : :-~**'~'-'~'" .-q,-.~t--.l,..'*.. ~ ; : ..... *..,....~..-:_,.;:: .... '*...-~l..*.. : : : : I : : : :; ..... ~'"~' '"~".* .... -t · - -~. : : : :: ..... '*..q...'*..-*:;:: ~ : : : ; ~ : : : : ..... }.-'*...~-.q, .... '*.-.: ...... ; ....... : : : ; ~ : ::"?"':': .... ?---~ · :- ?: - .--.~--,t-o'*-q-,-~-'*--'*--~t--.,/ ..... .... '*.--i.-.'*--,~: .... ~ '*"~'"~::~ ........ ...... "l'"'l~°*.'~'~l --*l'~'*."l~'l~' ............. '~l~"/P'"l~'*'" ""l'~.*'"~".* .... '~]' i~[]U ~1'* --'- ~ ...............: .--*--.*-.-I- ..... }-.'*--.*--'* ...... ~t"'*"q*"'~ .... '*"~""~"'*"'~'".~"'*'"~"*. ...... ....... --*-4-.*-4--~---;--i-.;-.4--.,-4--*-4--*--b-4--~-*-4--~-*-4--.b-*-~-~ -; :-;: }~: ,=4--4-.4-.*-~..-4--~---*--4. .... 4.-*.--~-.¢ ..... 4--*.-*.-*-..-*..,;--i.-i ..... 4.-$..4..¢ .... ¢..4.-¢..4 ...... 4.-4..*.-4 ....... ;--*..,;.-;-.~-.;.-'*---;.-*.. ; : : ;. : : ; ; ; : ; : ~ : ; : : ~ ~ ~ ; ;/ ~ : : : ; : ; ~ ; ; : : : : : : : ; : : : : : : ; : : : : : : : : : ; : : : ::::~:' : ':"': '? ?"i' ..'"": :'?": .... ?" '? .. i' ', : : '.-'~: : :"' ~"..'?"?"~"F'~":'? .... :"-": .... "i"/'?"! ...... :"?.":','. ...... ?.":"; ...... : .... : .... :":":": ....... ~.~,--'*.-'*--I.-->--'*..'*--,--. ~-.'*-'*--*...~..4..-.*...*--.~.-*.-~ -.-t---I--*...I,-. -.~--.~--*.-. ,--q.-.*.-*..*--*.4-*..'*.-'* .... ~..-q...'*-.'*.-~ --~...*..-..----.-. ?.~..o'*o-'*...~. ...... '*.-'*....*---} .... '*--.*---t..'* ...... '*.-'*.-q,.-.~ ..... '*..'*...~-.,*-.?..-~..?-..*..-~..- .... ?:-'!--+--t ...... t-fi'i- ....... ! . I : : ; : - · ; .... : ............. ' .............. ' .... ' ~ : : : ..... :;.:1 : : : · I : ~ : .'L: ; :~ : ; : : I : : : : ; ; .. : : : ; : : : ; : : : : : : : : : : : : : : : : : ~:. ' ~."l L :. :. i :. i -'- : i -: l ~ [ : I -: L ! ~ i ~ ~ '[ -~ [ . : '., : I :. :- :..'. i : i : ! : : : : ! ~ : : : / i ~ : : : : : : / : : :. : i' : ~ II '~ : : ! PRD,.ECTION ON VERT]CI:L PLFINE OF la. ZII"IUTH 1~'/ ~ IN YERT]r.,r.&. I:EPTHS HORIZ $CFt. E - 1/500 IN/Fr Su99es~'~ form to be inserted in each "AL~5'ive" well folder to d~.eck for timely ccmpliance with our regulations. Operator, We~ ~~J~d-Number Reports and Materials to be received by: //,--m~') · '- Date Required Date Received Remarks · , ·Ccmpletion Report Yes Well History Yes " Samples : ---Pi - · Core Chips '' //~ ~ .... (~.,./( Core Description y~~_ · Registered Survey Plat /e~g 7 Inclination Survey /~/~ · , · _ Directional Survey y~ 'P~ / ~- /~ ~ ~ ~ ~7~.. /~/~~ DriLl Stem Test Reports z/~~ ,~/~ ,/~ Logs Run: '-'~"-~'-~'-x Yes . Digitized Data ye'~ ARCO Alaska, Inc. Post Office ,r .,60 Anchorage, A~aska 99510 Telephone 907 277 5637 Date: 11/27/84 Transmittal No: 4868 RETURN TO: ARCO ALASKA, INC. : ATTN: Records Clerk ATO-1115B P.O. Box 100360 T/ran~Chorage, AK 99510 ir,ed herewith, are the following items. Please acknowledge receipt and return one signed copy of this transmittal. CBL's/Schlumberger/FINALS "Variable Density" "GCT/JB/GA" 9/19/84 " " " 9/3i/84 11 II I! 11 I1 I, 11 11 !! 11 I! 11 I1 11 11 Il II 11 11 11 .. !1 ,I .. II I1 II II I! It I! II I1 11 I! Il Il II II Il II !I Il !! "GCT" 10/07 "GCT" 10/07 "GCT/JB/GA" 9/31 "GCT/JB/Ring 9/17 "GA/JB/GCT" 9/19 " 9/17 '.'GCT" ' 7/21 "GCT" 9/21/84 "GCT/GA/JB" 9/14/84 " 9/15/84 "GCT/JC" 10/12/84 " lO/15/84 " 10/12/84 " 10/13/84 "GCT/~rB/GA'' 10/22/84 " 10/22/84 "JB/GA" 8/19/84 " 8/20/84 9/21/84 "GCT/JB" 10/14/84 " 10/14/84 " lO/O5/84 "OCT" 10/05/84 "Per, 4"2 9/10/84 5 iI2"/?PS/JB" 11/05/84 Acoustic "VDL/Signature/GR" /cat- Receipt Acknowledged: /84 /84 /84 /84 /84 /84 /84, Runl Il ' I1 11 I! 11 Il II 11 11 !1 I, 1! ,1 !I II 11 I1 Il Run 3. Run l ,! ,, Run 2 Run 1 DISTRIBUTION 6597 - 8292 >~B-3/ 7000 - 8460 ~/2B-!6/' 4950 - 7004 >2B-13 5750 - 8408 ~-2B-14 5700 - 7970 ~2B-!5/' 5348 - 6824 ~2B-2 7250 - 9182 -~2B-4 5055 - 6487 --2B-l~ 6200 - 7866 ~2D-5~ 6800 - 8954 5054 - 6650 ~2D~7/' 5597 - 8084 --'2D-'8-/ 5650 - 7951 -~2G-9 5840 - 8524 ~G-11~ 4940 - 6765 ~2G-lO~ 5730 - 7950 ~-2G-12 5790 - 7814 ~ 2G-13/ 5989 - 8624 -2G-14~ 8650 - 9334 8650 - 9562 5692 - 6742 ~17-5/'. 5Z50 - 7252 4500 - 6550 ~-1~2~ 68oo - 75~8 ~-4~ 7000 - 8210 ~1~3~/ 796~ - 894~ ~2V-8A 6100 - 6992 ~/1E-24 - · .; .~,~t..~.~ v ~ ~ B. Currier BPAE Drilling W. PAsher Geology /~&¢~ G. Phillips tate 6f-'AK - '.: ;:'A J:TC,~ .9 -I"- Sohio Chevron Mobil Phillips Oil Union D & M NSK Ops. J. Rathmeli Well Files ARCO Alaska, h..... Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 October 23, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Monthly Reports Dear Mr. Chatterton' Enclosed are the Monthly State Reports for the following wells' 2G-9 1L-8 2D-6 2B-16 2G-10 1L-4 2D-5 2B-15 2G-11 1L-3 2D-4 2B-14 2G-12 1L-2 2B-13 2G-13 Sincerely, Area Dril ling Engineer JBK/SH/tw HILL/O1 Enclosures RECEIVED r OV o Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA-OIL AND GAS CONSERVATION C:,~vlMISSION MONTHLY REIIORI' OF DRILLING AND WORKOVER OI:IER&TION$ ;1. Drilling well Jl~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 84-106 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21140 4. Location of Well at surface 183' FNL, 272' FWL, Sec.5, TION, R9E, UM 5. Elevationinfeet(indicate KB, DF, etc.) 140' RKB, Pad 104' 6. Lease Designation and Serial No. ADL 25667 ALK 2588 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 26-10 11. Field and Pool Kuparuk River Fi eld Kuparuk River Oil Pool For the Month of September ,1984 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well (~ 1015 hfs, 9/2/84. Drld 12-1/4" hole to 2821'. Ran, cmtd & tstd 9-5/8" csg. Performed top job w/50 sx PF "C". Drld 8-1/2" hole to 6850'TD as of 9/8/84. Ran logs. Ran, cmtd & tstd 7" csg. Secured well and released rig @ 0630 hfs, 9/9/84. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 9-5/8", 36#, J-55, HF-ERW BTC csg w/shoe @ 2796', Cmtd w/740 sxs PF "E" & 370 sx PF "C". 7", 26#, J-55, HF-ERW BTC csg w/shoe @ 6869'. Cmtd w/300 sxs Class "G". 14. Coring resume and brief description N/A 15. Logs run and depth where run DIL/SFL/GR/SP/FDC/CNL/Cal f/6847' - 2794' RFT (see RFT Results) 16. DST data, perforating data, shows of H2S, miscellaneous data N/A DEr'Ell/Eh l\ L t., L I V LJ NOV 0 51~ Ala~a 0ii & Gas Cons. Commission Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED TITLE ^,.~ D,~.-- ~- ....... DATE L /,,'-~,'~r// ~ - ......... i..u ~.,~ ..... NOTE--Repor~n th~f&~/s required for each calendar month, regardless of the status of operations, and must be ~led '~n duplicate with the Alaska Oil and Gas Conservatio~ommission by the 15th of the succeeding month, unless otherwise directed. Form 10~04 u,, , /uo~ ~. Submit in duplicate DS 2G-10 RFT Results Depth 6529 6543 6555 6554 6615 6617 6651 6657 6666 6683 Hydro. Pressure 3297 psi 3299 psi 3307 psi 3298 psi 3318 psi 3319 psi 3331 psi 3335 psi 3338 psi 3348 psi Shut-in Pressure 3063 psi 3087 psi 3090 psi 3085 psi 3098 psi HILL/O3:tw RECEIVED NOV 0 5 1~1~ Alaska OJt& Gas Cons. Commission Anchorage AF. Co Alaska, Inc. F'C.~' C_fill;c,'-~'Ox i, ,t-::c.~:o:ag,.. ,]ask~ 9S51 'Te~epl-,one 9~)7 277 5637 Date: 10/03/84 Transmittal No: 4743 Return To: ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 ; mitted herewith are the following items. Please acknowledge zeceipt eturn one signed copy of this transmittal. Schlumberger Tapes RFT t/69520 9/07/84 Run 1 '--'--~----~".. 9/07/84 " 2764 - 6866.5 ~_ ~T #695O3 . 8/28/~4 ~ ~ 786 08 '~ 8/28/84 '" _ 3~94.5-68Z0 ~ 0E #69_522 9/08184 3344 - 8621 0H ~9517 9/0~/84 " 23~3.5-7825 OH #69521 9/D7/84 " 4067.5-9007 ... 6683 - 6529 2G-10" 2D-7 J 2B-16 ].L-8 '/ 2D-6/ Receipt Acknowledged: B. Adams -- F.G. Baker P. Baxter BPAE DISTRIBUTION D&M W.V. Pasher Dzilling Geology Mobil G. Phillips Phillips Oil J.J. Rathmell Sohio Union R&D Well Files Chevron NSK Operations MEMORANDUM sta( e of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION TO: C. rton DATE: Cha~~ FILE NO: THRU: Lonnie C. Smith FROM: Commissioner TELEPHONE NO: Ben LeNo rrna, ~~~ SUBJECT: Petroleum Inspector ~ - September 10, 1984 D.iI.31 Witness BOPE Tests om ARCO's Kuparuk 2G-10, Sec. 5, T10N,R9E,IR~, Kuparuk River Umit. Thurs. da~, August 30.,. !984: I departed my home at 6:00 am for a ~'i'30 am showup and 7 30 am departure via Alaska Airlines, Flt. ~55 for Deadhorse, arriving at 9:i0 am. Weather: +30~F, Fair, no wind. BOPE tests on Kuparuk 1L-8 were completed, the subject of a separate report. Meter proving at ARCO's Kuparuk CPF-1 began at 9:00 pm . . . Friday, August 31, 1984: . . and was completed at 1:00 am, the ~hb~ect' of a Separate ~eport~ .Saturdayj Septemb_er 1~.. 1984: Standing by on Kuparuk 2D-6. Sunday, September 2, 1984: BOPE tests on ARCO's Kuparuk 2D-6 and -2BL16 ~e Completed, subjects of separate reports. Plonday, September 3, 1984: BOPE tests on ARCO' s Kuparuk 2G-10 e~n at 6:20 pm and were completed at 7:20 pm. BOPE inspectiom report is attached. Tuesday, September 4, 1984: I departed Deadhorse via Alaska Airlines, Flt. ~54-at' "i0:5-0 am arriving in Anchorage ~t 12:30 pm and at my home at 1:00 pm. In summary, I witnessed successful BOPE test on ARCO's Kuparuk 2G-10. Attachment 02-00IA(Rev. 10/79) STHTE OF Ar~SI~ OIL & GAS ODNSERVATION C~SION B .0. P.E. Inspection Report Operator Well Location: Sec ~-- T/o~R ~M U/'~ Dril ling Contractor ~?'~; ~ Rig # ~ Date ~~Tr ~! J'~::'~,'~' Representative. ~~ Permit # ~ ~asing Set @. Representative _~_~ ft, Location, General_ Well Sign. Ceneral Housekeeping Reserve pit Rig BOPE Stack Annular Preventer Pipe Rams ~ Blind Rams Choke Line Valves__ H.C.R. Valve Kill Line Valves ~- Check Valve___ Test Pressure ACCL~]t~ATOR SYSTEM Full Charge Pressure ~(D~D~ psig Pressure After Closure /~ ~ psig Pump incr. clos. pres. 200 psig. Full Charge Pressure Attained: ~' N2 -~m~w ,,~ ~ psig Controls: Master Remote min~ sec. Kelly and Floor Safety Valves Upper Kelly Lower Kelly Ball Type Ins ide BOP Test Pressure Choke Manifold valves__ /.9 Test Pressure ~ Test Pressure ~D(D Test Pressure ~"~:~ ~ Test Pressure No. flanges ~ Adjustable Chokes ~h Hydrauically operated chcke Test Results: Failures ~ Test Time' / , hrs. Repair or Replacement of failed equipment to be made within, days and Inspector/Ccmmission office notified. Distribution orig. - AO&GTC cc - Operator cc - Supervisor Inspector July 13, 1984 Mr. J. B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 A~.chorage, Alaska 99510-036 Re: Kuparuk River Unit 2G-10 ARCO Alaska, Inc. Permit No. 84-106 Sur. Loc. ].83'FNL, 272'~, Sec. 5, T!0N, RgE, Btmhole Loc. 1578'FNL, !558'F~, Sec. 5, T10N, R9E, Dear Mr. Kewin: Enclosed is the approved application for pe~it to drill the above referenced well. If coring is conducted, a one cubic inch chip from each foot of recovered core is required. Samples of well cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5)-. If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have'been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conse~ation To aid us in scheduling field work, plemse notify this office 24 hours prior to commencing installation of the blowout prevention Mr. Jeffrey B. Kewin Kuparuk River Unit 2G- l 0 -2- ~- July 13, 1984 equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system'is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe, In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very_ truly ~0urs, C. V. Chatterton Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION be Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ARCO Alaska, Inc. Post Office B~_..00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 5, 1984 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2G-10 Dear Mr. Chatterton: Enclosed are: o An application for Permit to Drill Kuparuk 2G-10, along with a $100 application fee o Diagrams showing the proposed horizontal and vertical projections of the wellbore o A proximity plat o A diagram and description of the surface hole diverter system ° A diagram and description of the BOP equipment Since we estimate spudding this well on July 26, 1984, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. ~erely, ~ A~g Engineer /a.. ~ .win. . JBK/JG/tw GRU8/L33 Attachments RECEIVED J U L 0 Alaska Oil & Gas Cons. Commission , Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA t ALASKA O'TL AND GAS CONSERVATION CO~,~/IlSSION PERMIT TO DRILL 20 AAC 25.O05 la. Type of work. DRILL [~X REDRILL [] DEEPEN [] lb. Type of well EXPLORATORY [] DEVELOPMENT OIL E~X DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC SINGLE ZONE MULT,PLE ZONE []'~¢. 9. Unit or lease name Kuparuk River Unit 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100:360, Anchorage, Alaska 99510 4. Location of well at surface 18:3' FNL, 272' FWL, Sec.5, T10N, RgE, UM At top of proposed producing interval 1228' FNL, 12:35' FWL, Sec. 5, T10N, RgE, UM At total depth 1578' FNL, 1558' FWL, Sec.5, T10N, RgE, UM 10. Well number 2G-lO 11. Field and pool Kuparuk River Field 5. ElevationRKB 140',in feetpAD(indicate104, KB, DF etc.) ) 6.ADLLease25667designationALK 2588and serial no. 12. Bond information (see 20AAC25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 30 mi. NW of Deadhorse miles 183 feet 16. Proposed depth (MD & TVD) 6950' MD, 6369' TVD 19. If deviated (see 20 AAC 25.050) KICK OFF POINT :3600 feet. 21 feet 17. Number of acres in lease 2501 20. Anticipated pressures MAXIMUM HOLE ANGLE 40 o I (see 20 AAC 25.035 (c) (2) Proposed Casing, Liner and Cementing Program Kuparuk River Oil Pool Amount $500,000 15, Distance to nearest drilling or completed 2G-gwell 60' ~ surface feet 18. Approximate spud date 07/26/84 2761 psig@ 80°F Surface :3170 psig@ 671F; ft. TD (TVD) SIZE Hole 24" 12-1/4" i ~-1/9,, Casing Weight 16" 62.5# 9-5/8" :36.0# 7" 26.0# 22. Describe proposed program: CASING AND LINER Grade Coupling[ Length "-40 / We]~ 80' H l .w .Te/ J-$5 HFlERW BTC/ 6917' SE ~ I lNG DEPTH QUANTITY OF CEMENT MD TOP TVD (include stage data) 36' 36' 2735' 35' 35' I I 33' I ~ 33' M D BOTTOM TV D 116'II 116' 2770'I 2770' 6950'I 6369' I I ± 200 cf 670 sx Permafrost E & 350 sx Permafrost C 295 sx Class G ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 6950' MD (6:369' TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 1:3-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Expected maximum surface pressure is 2761 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 2000 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 2G-10 will be 60' away from 2G-9 at the surface. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. The well will be completed by the (see attached sheet) 23. I hereby certif, y~hat the foregoing is true and correct to the best of my knowledge · TITLE Area Drilling Engineer SIGNED ~.- r /. ~_..- CONDITIONS OF APPROVAL Samples required f--lYES [~NO Permit number APPROVED BY Form 10-401 Mud log required []YES E~tNO Approval date - ~ I / i Directional Survey required I APl number eYES i-]NO SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE July 13, 1984 by order of the Commission Submit in triplicate Permit to Drill 2G-10 workover rig using 3-1/2", 9.2#/ft, J-55, 8rd tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. ' '"' "' ¢00' " 500 ~ SOO "~ O0 300 ':,' I :~ ! ....... ~ ~ , 5:.' ~ ~ r ' , , ................... , , · ~ ~ , ID'' '[~ .................. ''' ..... ~ .... · ~' ......... X'' X'4ml~' ~-, .... ,'. ~ ...... : ......... , ...... ~n: :~ ~'.: .~--: - ~[~ . ~., : . . ~ ~ , . , ~ .... , . .~ .I~ . ~.. ~. ~ -~'-~'~'. ........................... ~ ..... ~[ ............................. , ............ . .~ · . . ....................... .~ , . . , ...................... q ....... , . .~ . . ............................. .... ....... ~ ~ , , , . .... ..... , ~ , I ANNUI. A~ 9 DIAGRAM fl 13-5/8" 5000 PSI RSRRA BOP STACK 1. 16" - 2000 psi Tankco s%ar~ing head 2. 11" - 3000 psi casing head 3. 11" - 3000 psi x 13-5/8" - 5000 psi spacer spool 4, 13-5/8" - 5000 psi x 13-5/8" - 5000 psi drilling spool 5. 13-5/8" - SOO0 psi pipe rams 6. 13-5/8" - 5000 psi drilling spool w/choke and kill -lines 7. 13-5/8" - 5000 psi pipe rams 8. 13-5/8" - 5000 psi blind rams 9. 13-5/B" -_5000 psi annular BLIND ' RAMS SPO60L : S I-ID 2 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 SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ~J-L UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON NADC REPORT. THE ACCEPTABLE LOWER 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 RETRACT- ED. PREDETEP~MINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND ¥'~aLg'vt~S ~S~ OF C]-IOI<]~S. DON~T TEST AGAINST CLOSED CHOKES 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD 'FOR 10 MINUTES. 5. INCREASE PRESSURE TO 1800 PSI AND HOLE FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAFTS. 7. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 B. ~TF~'P~SS~ IK)WNST~ OF CHOKE ISOIATION V/kLVES_ To ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED ~tANIFOLD.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. 10. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES BLEED TO ZERO PSI. 11. OPEN BOI-FOM SET OF .PIPE P, AJ~S. BACK OFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 12. OPEN BLIND P,~J~$ 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 WITM KOOMEY PUMP. 16. PERFORM COMPLETE BOP£ TEST ONCE A W£~htt ~]J. ~ --C] 'J, TIONALLY OPERATE BOPE DAILY. J U L 1 O Alaska Oil & 2~s Cons. Commission Anchorage IPR£¥ENI'~R PIP~ RAMS DIAGRAM ~1 13-5/8" 5000 PSI RSRRA BOP STACK 1. 16" - 2000 psi Tanked starting head 2. i1" - 3000 psi casing head 3. 11' - 3000 psi x 13-5/8" - 5000 psi spacer s~ool 4. 13-5/8" - 5000 psi x 13-5/8" - 5000 psi drilling spool 5. 13-5/8' - 5000 psi pipe rams 6. 13-5/8" - 5000 psi drilling spool w/choke and kill -lines 7. 13-5/8" - 5000 psi pipe rams 8. 13-5/8" - 5000 psi blind rams g. 13-5/8" -.5000 psi annular BLINI) - ~ _$R ILL I N& , s ( CSG HD 2 t 16. ACCUMULATOR CAPACITY TES.T 1.CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2.ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON NAOC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI RB4AINING PRESSURE. 13-5/B" BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACT- ED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND DON~T TEST AGAINST CLOSED CHOKES 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD 'FOR 10 MINUTES. 5. INCREASE PRESSURE TO 1800 PSI AND HOLE FOR lO MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 3000 PSi AND HOLD FOR i0 B. ~~'PRESSURE DOWNS~ OF CHOKE ISOLATION VALV]~S~ TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD.VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI, 9. OPEN TOP Scl' OF PIPE RAMS AND CLOSE BOTTOM SET OF PIPE RAMS. 10. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES BLEED TO ZERO PSi. 11. OPEN BOt-FOM SET OF PIPE RAMS, BACK OFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 12. OPEN BLIND R~J~S AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET iN DRILLING POSITION. 13. TEST STANDPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSi WiTH KOOMEY PUMP. 15. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM SIGN AND SEND TO DRILLING SUPERVISOR. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE BOPE DAILY. Alaska 0); & C~a$ Cons. Oornm)ssion ARCO Alaska, Inc' Post Office ,-,.,x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 5, 1984 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plat Wel 1 s 5-16 Dear Elaine- Enclosed is an as-built location plat for you have any questions, please call me at Sincerely, Gruber Associate Engineer JG/tw GRU8/L26 Enclosure - 2G Pad the subject wells. If 263-4944. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~ 49th -11 ii i i .... I I i .6 DS 2G I HEREBY CERTIFY THAT I AM PEOPERLT I~EGI STERF~D AND LICENSED TO PRACTICE LA.ND SURVEYING IN THE STATE OF- ALASKA AND TTIAT THIS PLAT REPRES~TS A SURVEY. Mb~DE CrNDER. MY DIRECT SUPERVISION AIfD T!-IAT ALL DETAILS ARE CORRECT AS OF: 5~__~ -~_... 3% LOCATED III $1~CTIOII $2,TI lll.19F..g.l~. ~.Y-.5944195.0~ %- ~08929.92 236 F~L 6,Y-5944 t ~5.21 X- ~05929.90 236 FWL 7. Y-~944075.12 236 ~L $, Y-J94401 X- ~0~929.94 Z3J ~L 427 ~L 9. Y-~94~46~,24 ~T- 70-15-24,321~ 273 ~b 123 ~ 10. Y-~94~40~.I0 ~T- 70-15-2~,7297 272 ~L 18: ~ X- B08969,9l LON~I 272 ~L 243 ~ 272 ~L 30~ ~ ~~ED IR SECTIO~ 6,TION.RgE, U.~ 88 ~ 303 ~ 14, Y-~94~4~.!S' ~T- 70-15-23,1441 88 ~ 243 ~ LAT- 70-1 ~- 31.5000 LONG- 149-~.S-40. ! 62 607 PSL LAY- 70-15-30.9115 LONG- ! 49-~3-40. ! 6~ 547 FSL I.,AT- ?0-15-30,3204 I.,O~G- J 49-55-,i0, ! ~4 487 FSL LAT- 70-15-29.72~ LONG- 149-55-40. ! 68 Y-594~.465.22 LAT- 70-15-24.3252 , . ,c.." Z- 508609.93 LONG-t49--55-49,49'~ ~2 _ ss j !J C i i .:u~4 87 FEI. 123 FNL ~,nch:~,.,. ARCO Alaska, Inc, 4 i . '::: AS- BUILT .' ' ' ( (lo 'and' '11) (4) Cass (12 thr~ 20) (5) /4,7'# (21 thru 24) (6) Add: J-/~.7-ff ?-/1-~ [.0:" ' ;'. ':!~iocated prope~ diStance:,:,from property:(tine ......... ~..; ..... i:"'iacated pr°per d~tan'ee'.,fr0m' ici.ut'. :unaddic'at~'d'; acreage. ',aVail'bie i (!"{~b '. be..'.:deviat, d .'~ild:: is:. Well,'::.;.'i~or~ !¥1'at. :it~Cl~ided ;'.";'":'."'"..;':'. a.;:,:~;:c~n per, it be .aPprovOd before ten'hay wait .' ,~;' ';. ~..; ~ .... ~... .... ~._~~ erator have bond. in force es '.-op ' a .... , .............................. 10. i':'.I~' .... a cO~servation' order '~eeded ....i.~®.®..l®®®®..e .®.®~®~ .....~1®®. , 11, 'IS administrative approvaI needed e le..~lle. ®®e... e e · . · ... el · ee · eeeeee 12. 13. 14. 15. 16. 17. 18. 19. 20. 21, 22. 23. 24. Is conductor string provided ...' .................. Is enough Cement uSed t° circulat;'o~ ~;d;;;o; ;;fi s;;~;c;'. ........ 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 gquipmen;';ttac~ed ...i. Does BOPE have sufficient pressure rating - Test to ~Z) psig Does the choke manifold comply w/API RP-53 (Feb.78) .................. 25. Additional requirements Additional Remarks: 0 i--] HO r,,~. ~--] Geology: Engin~er~ ing: HWK .' LCS ~ BEW .. iffy: 12/08/83 : '6. CKLT INITIAL GEO. I UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effod has been made to chronologically organize this category of information. . U() ;. :'.) o ','.) 0 0 u 0 U O O0 0 [;' 0 0 0 u (:) i b 0 O b 0 ,) b t) 0:2 01 2 (JOb C { } D E; {~ b5 065 0 b5 O55 7 ,.il ,UCK& {~ ,.1'i" APl AP~[ AP1 [.,OG TYO}:.', C F T 0 0 0 00 () O (,;APt 0() 3!u GAP1 O0 .ilo [ ,,, 0 0 P ;~ 0 0 1 G /C 3 (,) U 3 5 0 0 2 ~,, / C 3 o 0 3 5 6 0 .P U t.; 0 H 9 O 0 0 t: ~::' S 0 0 3 3 0 3 1 C,Pb O0 ,:t30 3:0 E i", T ~:: ¥ 0 1 6 0 1 0 5.5 t 3 7 · : I"~ 1." ~.': O, 0 0 4 o 0 4, 1 0 (,) 4 1 U 0 4 1 o 0 ,~ .1 ~ 0 ~ 1. 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