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Home My WebLink About184-026CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 2B-08 (PTD 184-026) Date:Friday, August 29, 2025 9:43:41 AM Attachments:TIO and Bleed History (3).pdf 2B-08.pdf From: Bronga, Jaime <Jaime.Bronga@conocophillips.com> Sent: Thursday, August 28, 2025 3:09 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Automation, AK Wells <akwellsautomation@conocophillips.com> Subject: KRU 2B-08 (PTD 184-026) Well Name: 2B-08 Facility: CPF2 PTD: 184-026 Well Type: Inj AA Number (if applicable): Internal Waiver (Yes/No if applicable): Type of Issue: Plan Forward Maximum Pressure (if applicable): Date of Occurrence (if applicable): Hi Chris, KRU 2B-08 was reported to the AOGCC for possible TxIA on gas injection on July 14th, 2025. After monitoring on gas injection and confirming TxIA, the well was WAG to water injection July 29th, 2025. CPAI conducted a 30 day water injection monitoring and did not observe any TxIA on gas injection. CPAI intends to prepare and apply for an Administrative Approval for water only injection. CPAI intends to keep the well on water injection while preparing and waiting for the AOGCC reply. CPAI conducted wellhead tests, an MIT-IA, and MIT-OA to confirm barriers for water injection. The bleed log, TIO plot and schematic are attached. 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 Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.25 Top (ftKB) 38.0 Set Depth (ftKB) 117.0 Set Depth (TVD) … 117.0 Wt/Len (l… 65.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 37.0 Set Depth (ftKB) 3,030.0 Set Depth (TVD) … 2,726.3 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 35.5 Set Depth (ftKB) 7,500.0 Set Depth (TVD) … 6,303.7 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 33.6 Set Depth (ft… 7,200.9 Set Depth (TVD) (… 6,044.0 Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE-8rd Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 33.6 33.6 0.07 HANGER GRAY GEN III TUBING HANGER 3.500 1,947.9 1,869.4 36.08 SAFETY VLV BAKER FVL SAFETY VALVE (LOCKED OUT 3/26/90) 2.810 6,937.4 5,819.5 32.59 PBR BAKER 10' PBR 3.000 6,951.1 5,831.1 32.44 PACKER BAKER FHL PACKER 3.000 7,097.9 5,955.7 31.51 BLAST RINGS CARBIDE BLAST RINGS (2) 2.992 7,173.3 6,020.3 30.84 LOCATOR BAKER LOCATOR SEAL ASSEMBLY 3.000 7,175.2 6,021.9 30.82 PACKER BAKER FB-1 PACKER 4.000 7,177.7 6,024.0 30.80 SBE BAKER SEAL BORE EXTENSION 3.000 7,190.7 6,035.2 30.68 NIPPLE CAMCO D NIPPLE NO GO 2.750 7,200.3 6,043.4 30.60 SOS BAKER SHEAR OUT SUB, ELMD @ 7182' PER SWS IPROF 6/11/2007 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) 7,149.0 5,999.4 31.06 PACKER WEATHERFORD ER PACKER 7/15/2011 1.750 7,151.8 6,001.9 31.03 PATCH PATCH ASSEMBLY - SPACER PIPE & SNAP LATCH (OAL=20.40') 7/15/2011 1.750 7,171.5 6,018.7 30.86 PACKER WEATHERFORD ER PACKER 5/21/2011 1.750 7,498.0 6,302.0 29.50 FISH 1" DMY Empty Pocket; Fell to Rathole from GLV @6990' 11/7/85 11/7/1985 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,100.0 7,135.0 5,957.5 5,987.4 C-4, 2B-08 7/14/1984 12.0 APERF 120 deg. phasing; SOS 5 1/2" Csg Gun 7,216.0 7,222.0 6,057.0 6,062.2 A-5, 2B-08 7/25/1984 4.0 APERF 90 deg. phasing; 2 1/8" Tornado Link Jet 7,233.0 7,256.0 6,071.7 6,091.5 A-4, 2B-08 6/24/1984 4.0 IPERF 2 1/8" 'GO' Link Jet 7,277.0 7,298.0 6,109.7 6,127.9 A-3, 2B-08 6/24/1984 4.0 IPERF 2 1/8" 'GO' Link Jet Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 6,891.1 5,780.6 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 7/25/1984 2 6,989.8 5,863.8 MMH FMHO 1 INJ DMY BK 0.000 0.0 8/14/1992 3 7,059.6 5,923.2 MMH FMHO 1 INJ DMY BK 0.000 0.0 11/10/1992 4 7,161.6 6,010.2 MMH FMHO 1 INJ PATC H 0.000 0.0 5/27/2005 Notes: General & Safety End Date Annotation 4/29/1999 NOTE: Scale obstruction found @ 802'' WLM 12/4/2009 NOTE: SEAL WELD ON BOTTOM OF STARTER HEAD (NO PATCH) 8/22/2011 NOTE: View Schematic w/ Alaska.Schematic9.0 Comment SSSV: LOCKED OUT 2B-08, 6/14/2018 12:52:44 PM Vertical schematic (actual) PRODUCTION; 35.5-7,500.0 FISH; 7,498.0 IPERF; 7,277.0-7,298.0 IPERF; 7,233.0-7,256.0 APERF; 7,216.0-7,222.0 SOS; 7,200.3 NIPPLE; 7,190.7 SBE; 7,177.7 PACKER; 7,175.2 LOCATOR; 7,173.3 PACKER; 7,171.5 INJECTION; 7,161.6 PATCH; 7,151.8 PACKER; 7,149.0 APERF; 7,100.0-7,135.0 INJECTION; 7,059.6 INJECTION; 6,989.8 PACKER; 6,951.1 PBR; 6,937.4 GAS LIFT; 6,891.1 SURFACE; 37.0-3,030.0 SAFETY VLV; 1,947.9 CONDUCTOR; 38.0-117.0 HANGER; 33.6 Last Tag Annotation Last Tag: SLM End Date 6/13/2018 Depth (ftKB) 7,358.0 Last Mod By fergusp Last Rev Reason Annotation Rev Reason: Drift 7 tag End Date 6/13/2018 Last Mod By fergusp KUP INJ KB-Grd (ft) 35.99 Rig Release Date 2/28/1984 Annotation Last WO: End Date 2B-08 H2S (ppm) Date... TD Act Btm (ftKB) 7,500.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292107900 Wellbore Status INJ Max Angle & MD Incl (°) 39.60 MD (ftKB) 3,700.00 AAnnnnuulaarr BBeehhaavviioorrss |TIO Pressures and Injection Rates Well Name 2B-08  Annular Pressures 0K 1K 2K 3K Date Pressure (PSI)Jun 2025 Jul 2025 Aug 2025 Well is SI Tubing Pressure IA Pressure OA Pressure OOA Pressure Wellhead Temperature 0 100 Date Temperature (F)Jun 2025 Jul 2025 Aug 2025 Injection Rates 0K 5K 10K 15K 20K DateRateJun 2025 Jul 2025 Aug 2025 Gas Rate (MSCFD)Water Rate (STBD) INJ Date 90 5/31/2025 - 8/28/2025 Last Days  AAnnnnuulaarr BBeehhaavviioorrss |Bleed History Date 90 5/31/2025 - 8/28/2025 Last Days  Well Name Test Date  IA Start Pressure IA End Pressure OA Start Pressure OA End Pressure OOA Pressure OOOA Pressure 2B-08 7/30/2025 1:31:59 PM 2000 1250 50 2B-08 7/28/2025 4:54:03 AM 1900 1600 750 2B-08 7/23/2025 2:35:13 AM 1600 975 650 2B-08 7/23/2025 2:34:05 AM 1900 1600 850 2B-08 7/19/2025 4:05:58 PM 1360 890 80 2B-08 7/18/2025 4:09:44 PM 1650 1050 200 2B-08 7/14/2025 11:45:14 PM 1750 1150 280 2B-08 7/13/2025 7:57:38 PM 2250 1150 50 2B-08 7/12/2025 7:37:23 PM 2000 1250 50 2B-08 7/10/2025 8:17:48 PM 1950 1200 100 2B-08 7/5/2025 10:53:02 PM 1975 1100 540 2B-08 6/30/2025 3:52:44 PM 2350 1500 200 2B-08 6/30/2025 2:32:31 AM 2450 2000 1080 200 2B-08 6/22/2025 3:22:44 AM 1850 1300 780 Well Name 2B-08  File Path (Copy and Place in File Explorer) \\nsknafs1\schematics$\Kuparuk and Satellites\Cpf2-Tarn-Tabasco-Meltwater\2b\2B-08.pdf CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 2B-08 (PTD 184-026) Plan Forward Date:Monday, July 28, 2025 8:48:43 AM Attachments:AnnComm Surveillance TIO for 2B-08.pdf From: Bronga, Jaime <Jaime.Bronga@conocophillips.com> Sent: Wednesday, July 23, 2025 8:57 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: KRU 2B-08 (PTD 184-026) Plan Forward Well Name: 2B-08 Facility: CPF2 PTD: 184-026 Well Type: Inj AA Number (if applicable): Internal Waiver (Yes/No if applicable): Type of Issue: Plan Forward Maximum Pressure (if applicable): Date of Occurrence (if applicable): Hi Chris, KRU 2B-08 (PTD 184-026) was reported to the AOGCC on 7/14/25 for suspect integrity on gas injection. CPAI has confirmed the well is exhibited TxIA on gas injection and will WAG the well to water injection to monitor for integrity and develop a further plan forward. 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 2B-08 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 2B-08 2025-06-22 1850.0 1300 -550.0 IA 2B-08 2025-06-30 2450.0 2000 -450.0 IA 2B-08 2025-06-30 2350.0 1500 -850.0 IA 2B-08 2025-07-05 1975.0 1100 -875.0 IA 2B-08 2025-07-10 1950.0 1200 -750.0 IA 2B-08 2025-07-12 2000.0 1250 -750.0 IA 2B-08 2025-07-13 2250.0 1150 -1100.0 IA 2B-08 2025-07-14 1750.0 1150 -600.0 IA 2B-08 2025-07-18 1650.0 1050 -600.0 IA 2B-08 2025-07-19 1360.0 890 -470.0 IA Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.25 Top (ftKB) 38.0 Set Depth (ftKB) 117.0 Set Depth (TVD) … 117.0 Wt/Len (l… 65.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 37.0 Set Depth (ftKB) 3,030.0 Set Depth (TVD) … 2,726.3 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 35.5 Set Depth (ftKB) 7,500.0 Set Depth (TVD) … 6,303.7 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 33.6 Set Depth (ft… 7,200.9 Set Depth (TVD) (… 6,044.0 Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE-8rd Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 33.6 33.6 0.07 HANGER GRAY GEN III TUBING HANGER 3.500 1,947.9 1,869.4 36.08 SAFETY VLV BAKER FVL SAFETY VALVE (LOCKED OUT 3/26/90) 2.810 6,937.4 5,819.5 32.59 PBR BAKER 10' PBR 3.000 6,951.1 5,831.1 32.44 PACKER BAKER FHL PACKER 3.000 7,097.9 5,955.7 31.51 BLAST RINGS CARBIDE BLAST RINGS (2) 2.992 7,173.3 6,020.3 30.84 LOCATOR BAKER LOCATOR SEAL ASSEMBLY 3.000 7,175.2 6,021.9 30.82 PACKER BAKER FB-1 PACKER 4.000 7,177.7 6,024.0 30.80 SBE BAKER SEAL BORE EXTENSION 3.000 7,190.7 6,035.2 30.68 NIPPLE CAMCO D NIPPLE NO GO 2.750 7,200.3 6,043.4 30.60 SOS BAKER SHEAR OUT SUB, ELMD @ 7182' PER SWS IPROF 6/11/2007 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) 7,149.0 5,999.4 31.06 PACKER WEATHERFORD ER PACKER 7/15/2011 1.750 7,151.8 6,001.9 31.03 PATCH PATCH ASSEMBLY - SPACER PIPE & SNAP LATCH (OAL=20.40') 7/15/2011 1.750 7,171.5 6,018.7 30.86 PACKER WEATHERFORD ER PACKER 5/21/2011 1.750 7,498.0 6,302.0 29.50 FISH 1" DMY Empty Pocket; Fell to Rathole from GLV @6990' 11/7/85 11/7/1985 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,100.0 7,135.0 5,957.5 5,987.4 C-4, 2B-08 7/14/1984 12.0 APERF 120 deg. phasing; SOS 5 1/2" Csg Gun 7,216.0 7,222.0 6,057.0 6,062.2 A-5, 2B-08 7/25/1984 4.0 APERF 90 deg. phasing; 2 1/8" Tornado Link Jet 7,233.0 7,256.0 6,071.7 6,091.5 A-4, 2B-08 6/24/1984 4.0 IPERF 2 1/8" 'GO' Link Jet 7,277.0 7,298.0 6,109.7 6,127.9 A-3, 2B-08 6/24/1984 4.0 IPERF 2 1/8" 'GO' Link Jet Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 6,891.1 5,780.6 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 7/25/1984 2 6,989.8 5,863.8 MMH FMHO 1 INJ DMY BK 0.000 0.0 8/14/1992 3 7,059.6 5,923.2 MMH FMHO 1 INJ DMY BK 0.000 0.0 11/10/1992 4 7,161.6 6,010.2 MMH FMHO 1 INJ PATC H 0.000 0.0 5/27/2005 Notes: General & Safety End Date Annotation 4/29/1999 NOTE: Scale obstruction found @ 802'' WLM 12/4/2009 NOTE: SEAL WELD ON BOTTOM OF STARTER HEAD (NO PATCH) 8/22/2011 NOTE: View Schematic w/ Alaska.Schematic9.0 Comment SSSV: LOCKED OUT 2B-08, 6/14/2018 12:52:44 PM Vertical schematic (actual) PRODUCTION; 35.5-7,500.0 FISH; 7,498.0 IPERF; 7,277.0-7,298.0 IPERF; 7,233.0-7,256.0 APERF; 7,216.0-7,222.0 SOS; 7,200.3 NIPPLE; 7,190.7 SBE; 7,177.7 PACKER; 7,175.2 LOCATOR; 7,173.3 PACKER; 7,171.5 INJECTION; 7,161.6 PATCH; 7,151.8 PACKER; 7,149.0 APERF; 7,100.0-7,135.0 INJECTION; 7,059.6 INJECTION; 6,989.8 PACKER; 6,951.1 PBR; 6,937.4 GAS LIFT; 6,891.1 SURFACE; 37.0-3,030.0 SAFETY VLV; 1,947.9 CONDUCTOR; 38.0-117.0 HANGER; 33.6 Last Tag Annotation Last Tag: SLM End Date 6/13/2018 Depth (ftKB) 7,358.0 Last Mod By fergusp Last Rev Reason Annotation Rev Reason: Drift 7 tag End Date 6/13/2018 Last Mod By fergusp KUP INJ KB-Grd (ft) 35.99 Rig Release Date 2/28/1984 Annotation Last WO: End Date 2B-08 H2S (ppm) Date... TD Act Btm (ftKB) 7,500.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292107900 Wellbore Status INJ Max Angle & MD Incl (°) 39.60 MD (ftKB) 3,700.00 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 2B-08 (PTD 184-026) Suspect Integrity Date:Monday, July 14, 2025 10:10:20 AM Attachments:AnnComm Surveillance TIO for 2B-08.pdf From: Bronga, Jaime <Jaime.Bronga@conocophillips.com> Sent: Monday, July 14, 2025 10:08 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: KRU 2B-08 (PTD 184-026) Suspect Integrity Well Name: 2B-09 Facility: CPF2 PTD: 184-026 Well Type: Inj AA Number (if applicable): Internal Waiver (Yes/No if applicable): Type of Issue: Suspect Integrity Maximum Pressure (if applicable): Date of Occurrence (if applicable): Hi Chris, KRU 2B-08 is a WAG injection well currently on MI injection. The IA pressure has been bled multiple times in the last week. The MI injection temperature has also had significant fluctuations during this time period. CPAI is planning to investigate for Tubing by IA communication while on gas injection as without further diagnostics I am unable to verify if the bleeds are due to temperature changes or an integrity issue. CPAI intends to keep the well on gas injection during the initial diagnostics and will WAG the well to water injection for monitoring if integrity issues on gas are detected. Please let me know if you have any questions or disagree with this plan. Thanks, Jaime Warmest regards, Jaime Bronga Well Integrity – CPF2 – ConocoPhillips Alaska Cell: 907-229-8282 2B-08 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 2B-08 2025-04-14 1900.0 1200 -700.0 IA 2B-08 2025-04-17 1675.0 1125 -550.0 IA 2B-08 2025-06-22 1850.0 1300 -550.0 IA 2B-08 2025-06-30 2450.0 2000 -450.0 IA 2B-08 2025-06-30 2350.0 1500 -850.0 IA 2B-08 2025-07-05 1975.0 1100 -875.0 IA 2B-08 2025-07-10 1950.0 1200 -750.0 IA 2B-08 2025-07-12 2000.0 1250 -750.0 IA 2B-08 2025-07-13 2250.0 1150 -1100.0 IA Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.25 Top (ftKB) 38.0 Set Depth (ftKB) 117.0 Set Depth (TVD) … 117.0 Wt/Len (l… 65.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 37.0 Set Depth (ftKB) 3,030.0 Set Depth (TVD) … 2,726.3 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 35.5 Set Depth (ftKB) 7,500.0 Set Depth (TVD) … 6,303.7 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 33.6 Set Depth (ft… 7,200.9 Set Depth (TVD) (… 6,044.0 Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE-8rd Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 33.6 33.6 0.07 HANGER GRAY GEN III TUBING HANGER 3.500 1,947.9 1,869.4 36.08 SAFETY VLV BAKER FVL SAFETY VALVE (LOCKED OUT 3/26/90) 2.810 6,937.4 5,819.5 32.59 PBR BAKER 10' PBR 3.000 6,951.1 5,831.1 32.44 PACKER BAKER FHL PACKER 3.000 7,097.9 5,955.7 31.51 BLAST RINGS CARBIDE BLAST RINGS (2) 2.992 7,173.3 6,020.3 30.84 LOCATOR BAKER LOCATOR SEAL ASSEMBLY 3.000 7,175.2 6,021.9 30.82 PACKER BAKER FB-1 PACKER 4.000 7,177.7 6,024.0 30.80 SBE BAKER SEAL BORE EXTENSION 3.000 7,190.7 6,035.2 30.68 NIPPLE CAMCO D NIPPLE NO GO 2.750 7,200.3 6,043.4 30.60 SOS BAKER SHEAR OUT SUB, ELMD @ 7182' PER SWS IPROF 6/11/2007 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) 7,149.0 5,999.4 31.06 PACKER WEATHERFORD ER PACKER 7/15/2011 1.750 7,151.8 6,001.9 31.03 PATCH PATCH ASSEMBLY - SPACER PIPE & SNAP LATCH (OAL=20.40') 7/15/2011 1.750 7,171.5 6,018.7 30.86 PACKER WEATHERFORD ER PACKER 5/21/2011 1.750 7,498.0 6,302.0 29.50 FISH 1" DMY Empty Pocket; Fell to Rathole from GLV @6990' 11/7/85 11/7/1985 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,100.0 7,135.0 5,957.5 5,987.4 C-4, 2B-08 7/14/1984 12.0 APERF 120 deg. phasing; SOS 5 1/2" Csg Gun 7,216.0 7,222.0 6,057.0 6,062.2 A-5, 2B-08 7/25/1984 4.0 APERF 90 deg. phasing; 2 1/8" Tornado Link Jet 7,233.0 7,256.0 6,071.7 6,091.5 A-4, 2B-08 6/24/1984 4.0 IPERF 2 1/8" 'GO' Link Jet 7,277.0 7,298.0 6,109.7 6,127.9 A-3, 2B-08 6/24/1984 4.0 IPERF 2 1/8" 'GO' Link Jet Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 6,891.1 5,780.6 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 7/25/1984 2 6,989.8 5,863.8 MMH FMHO 1 INJ DMY BK 0.000 0.0 8/14/1992 3 7,059.6 5,923.2 MMH FMHO 1 INJ DMY BK 0.000 0.0 11/10/1992 4 7,161.6 6,010.2 MMH FMHO 1 INJ PATC H 0.000 0.0 5/27/2005 Notes: General & Safety End Date Annotation 4/29/1999 NOTE: Scale obstruction found @ 802'' WLM 12/4/2009 NOTE: SEAL WELD ON BOTTOM OF STARTER HEAD (NO PATCH) 8/22/2011 NOTE: View Schematic w/ Alaska.Schematic9.0 Comment SSSV: LOCKED OUT 2B-08, 6/14/2018 12:52:44 PM Vertical schematic (actual) PRODUCTION; 35.5-7,500.0 FISH; 7,498.0 IPERF; 7,277.0-7,298.0 IPERF; 7,233.0-7,256.0 APERF; 7,216.0-7,222.0 SOS; 7,200.3 NIPPLE; 7,190.7 SBE; 7,177.7 PACKER; 7,175.2 LOCATOR; 7,173.3 PACKER; 7,171.5 INJECTION; 7,161.6 PATCH; 7,151.8 PACKER; 7,149.0 APERF; 7,100.0-7,135.0 INJECTION; 7,059.6 INJECTION; 6,989.8 PACKER; 6,951.1 PBR; 6,937.4 GAS LIFT; 6,891.1 SURFACE; 37.0-3,030.0 SAFETY VLV; 1,947.9 CONDUCTOR; 38.0-117.0 HANGER; 33.6 Last Tag Annotation Last Tag: SLM End Date 6/13/2018 Depth (ftKB) 7,358.0 Last Mod By fergusp Last Rev Reason Annotation Rev Reason: Drift 7 tag End Date 6/13/2018 Last Mod By fergusp KUP INJ KB-Grd (ft) 35.99 Rig Release Date 2/28/1984 Annotation Last WO: End Date 2B-08 H2S (ppm) Date... TD Act Btm (ftKB) 7,500.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292107900 Wellbore Status INJ Max Angle & MD Incl (°) 39.60 MD (ftKB) 3,700.00 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 2B-08 (PTD 184-026) IA and OA Exceeded OPL Date:Monday, June 30, 2025 2:53:15 PM Attachments:AnnComm Surveillance TIO for 2B-08.pdf From: Bronga, Jaime <Jaime.Bronga@conocophillips.com> Sent: Monday, June 30, 2025 1:37 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: KRU 2B-08 (PTD 184-026) IA and OA Exceeded OPL Well Name: 2B-08 Facility: CPF2 PTD: 184-026 Well Type: Inj AA Number (if applicable): Internal Waiver (Yes/No if applicable): Type of Issue: OA Exceeded OPL, IA Exceeded OPL Maximum Pressure (if applicable): 1080 psi, 2450 psi Date of Occurrence (if applicable): 6/29/2025 Hi Chris, KRU 2B-08 (PTD 184-026) is a WAG injection well currently on MI injection. The Operator found the OA at 1080 psi and the IA at 2450 psi on June 29, 2025. The Operating pressure limit (OPL) on the OA is 1000 psi and the OPL on the IA on MI is 2400 psi. The operator bled the OA to 200 psi and the IA to 2000 psi. The high pressure on both the IA and OA are attributed to a thermal increase in MI injection temperature and the well’s recent WAG to MI from water injection. CPAI does not intend to conduct diagnostics or further monitoring at this time. Please let me know if you have any questions or disagree with the plan. The TIO, schematic, and bleed log are attached. Warmest regards, Jaime Bronga Well Integrity – CPF2 – ConocoPhillips Alaska Cell: 907-229-8282 2B-08 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 2B-08 2025-04-10 1400 800 -600 IA 2B-08 2025-04-14 1900 1200 -700 IA 2B-08 2025-04-17 1675 1125 -550 IA 2B-08 2025-06-22 1850 1300 -550 IA Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.25 Top (ftKB) 38.0 Set Depth (ftKB) 117.0 Set Depth (TVD) … 117.0 Wt/Len (l… 65.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 37.0 Set Depth (ftKB) 3,030.0 Set Depth (TVD) … 2,726.3 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 35.5 Set Depth (ftKB) 7,500.0 Set Depth (TVD) … 6,303.7 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 33.6 Set Depth (ft… 7,200.9 Set Depth (TVD) (… 6,044.0 Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE-8rd Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 33.6 33.6 0.07 HANGER GRAY GEN III TUBING HANGER 3.500 1,947.9 1,869.4 36.08 SAFETY VLV BAKER FVL SAFETY VALVE (LOCKED OUT 3/26/90) 2.810 6,937.4 5,819.5 32.59 PBR BAKER 10' PBR 3.000 6,951.1 5,831.1 32.44 PACKER BAKER FHL PACKER 3.000 7,097.9 5,955.7 31.51 BLAST RINGS CARBIDE BLAST RINGS (2) 2.992 7,173.3 6,020.3 30.84 LOCATOR BAKER LOCATOR SEAL ASSEMBLY 3.000 7,175.2 6,021.9 30.82 PACKER BAKER FB-1 PACKER 4.000 7,177.7 6,024.0 30.80 SBE BAKER SEAL BORE EXTENSION 3.000 7,190.7 6,035.2 30.68 NIPPLE CAMCO D NIPPLE NO GO 2.750 7,200.3 6,043.4 30.60 SOS BAKER SHEAR OUT SUB, ELMD @ 7182' PER SWS IPROF 6/11/2007 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) 7,149.0 5,999.4 31.06 PACKER WEATHERFORD ER PACKER 7/15/2011 1.750 7,151.8 6,001.9 31.03 PATCH PATCH ASSEMBLY - SPACER PIPE & SNAP LATCH (OAL=20.40') 7/15/2011 1.750 7,171.5 6,018.7 30.86 PACKER WEATHERFORD ER PACKER 5/21/2011 1.750 7,498.0 6,302.0 29.50 FISH 1" DMY Empty Pocket; Fell to Rathole from GLV @6990' 11/7/85 11/7/1985 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,100.0 7,135.0 5,957.5 5,987.4 C-4, 2B-08 7/14/1984 12.0 APERF 120 deg. phasing; SOS 5 1/2" Csg Gun 7,216.0 7,222.0 6,057.0 6,062.2 A-5, 2B-08 7/25/1984 4.0 APERF 90 deg. phasing; 2 1/8" Tornado Link Jet 7,233.0 7,256.0 6,071.7 6,091.5 A-4, 2B-08 6/24/1984 4.0 IPERF 2 1/8" 'GO' Link Jet 7,277.0 7,298.0 6,109.7 6,127.9 A-3, 2B-08 6/24/1984 4.0 IPERF 2 1/8" 'GO' Link Jet Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 6,891.1 5,780.6 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 7/25/1984 2 6,989.8 5,863.8 MMH FMHO 1 INJ DMY BK 0.000 0.0 8/14/1992 3 7,059.6 5,923.2 MMH FMHO 1 INJ DMY BK 0.000 0.0 11/10/1992 4 7,161.6 6,010.2 MMH FMHO 1 INJ PATC H 0.000 0.0 5/27/2005 Notes: General & Safety End Date Annotation 4/29/1999 NOTE: Scale obstruction found @ 802'' WLM 12/4/2009 NOTE: SEAL WELD ON BOTTOM OF STARTER HEAD (NO PATCH) 8/22/2011 NOTE: View Schematic w/ Alaska.Schematic9.0 Comment SSSV: LOCKED OUT 2B-08, 6/14/2018 12:52:44 PM Vertical schematic (actual) PRODUCTION; 35.5-7,500.0 FISH; 7,498.0 IPERF; 7,277.0-7,298.0 IPERF; 7,233.0-7,256.0 APERF; 7,216.0-7,222.0 SOS; 7,200.3 NIPPLE; 7,190.7 SBE; 7,177.7 PACKER; 7,175.2 LOCATOR; 7,173.3 PACKER; 7,171.5 INJECTION; 7,161.6 PATCH; 7,151.8 PACKER; 7,149.0 APERF; 7,100.0-7,135.0 INJECTION; 7,059.6 INJECTION; 6,989.8 PACKER; 6,951.1 PBR; 6,937.4 GAS LIFT; 6,891.1 SURFACE; 37.0-3,030.0 SAFETY VLV; 1,947.9 CONDUCTOR; 38.0-117.0 HANGER; 33.6 Last Tag Annotation Last Tag: SLM End Date 6/13/2018 Depth (ftKB) 7,358.0 Last Mod By fergusp Last Rev Reason Annotation Rev Reason: Drift 7 tag End Date 6/13/2018 Last Mod By fergusp KUP INJ KB-Grd (ft) 35.99 Rig Release Date 2/28/1984 Annotation Last WO: End Date 2B-08 H2S (ppm) Date... TD Act Btm (ftKB) 7,500.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292107900 Wellbore Status INJ Max Angle & MD Incl (°) 39.60 MD (ftKB) 3,700.00 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, June 12, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2B-08 KUPARUK RIV UNIT 2B-08 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/12/2024 2B-08 50-029-21079-00-00 184-026-0 W SPT 5831 1840260 1500 2300 2310 2310 2310 40 40 40 40 4YRTST P Bob Noble 5/3/2024 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 2B-08 Inspection Date: Tubing OA Packer Depth 840 1820 1750 1740IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN240505124907 BBL Pumped:1 BBL Returned:1 Wednesday, June 12, 2024 Page 1 of 1           ! " # $! % " &$ '"" ()$ *+ )# , # -.$ /. 0$$ " ## ! 1 +1 2 $ 3) 45 $6 784 6 ) 9)4 6 ) :)4 6 * #) 9) * #) :) 94 6 49)6 ;<49)6 /(77=$ " . 5 < : < :9)4 6:)4 6 & ," !< ) >< *+ )# # '* ) ( !< " .5 .$; )5 -:# ) ? ? ? 5@? ?"" #?.$; ! 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Date:Tuesday, November 30, 2021 12:00:39 PM Attachments:image001.png AnnComm Surveillance TIO for 2B-08.pdf From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Monday, November 29, 2021 11:56 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>; Well Integrity Specialist CPF2 <n2549@conocophillips.com> Subject: RE: Kuparuk Injector 2B-08 (PTD #184-026) report of recharging IA. Chris- Kuparuk injector 2B-08 (PTD #184-026) has completed the 30 day monitor period for what appeared to be a recharging IA. DHD conducted several days of bleeding/degassing the fluids in the IA and the well subsequently passed a diagnostics MIT-IA, IA DDT and T & IC pack off tests. The well no longer is showing indications of a recharging IA and will be returned to normal injection status. Please let me know if you have any questions or disagree with the plan. Attached is a copy of the current wellbore schematic and 90 day TIO plot. Dusty Freeborn Wells Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Tuesday, October 26, 2021 8:44 AM To: Wallace, Chris D (DOA) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>; Well Integrity Specialist CPF2 <n2549@conocophillips.com> Subject: Kuparuk Injector 2B-08 (PTD #184-026) report of recharging IA. Chris- Kuparuk injector 2B-08 (PTD #184-026) was reported by operation with a recharging IA after multiple bleed attempts beyond what would be expected from the thermal influence of changing from gas to water injection. CPAI intends to leave the well on water injection while DHD conducts the initial set of diagnostic testing. If the well passes the initial testing, the well will be placed on a 30 day monitor period for further verification of integrity. If the diagnostic testing fails, the proper paperwork for continued injection or repair will be submitted as required. Please let me know if you have any questions or disagree with this plan. Attached is a copy of the current wellbore schematic and 90 day TIO plot. Dusty Freeborn Wells Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 2B-08 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 2B-08 2021-10-08 1500 600 -900 IA 2B-08 2021-10-08 1750 1000 -750 IA 2B-08 2021-10-14 1950 1300 -650 IA 2B-08 2021-10-21 1900 1400 -500 IA 2B-08 2021-10-26 1900 660 -1240 IA 2B-08 2021-10-31 2 475 473 IA 2B-08 2021-11-02 5 850 845 IA Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.25 Top (ftKB) 38.0 Set Depth (ftKB) 117.0 Set Depth (TVD) … 117.0 Wt/Len (l… 65.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 37.0 Set Depth (ftKB) 3,030.0 Set Depth (TVD) … 2,726.3 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 35.5 Set Depth (ftKB) 7,500.0 Set Depth (TVD) … 6,303.7 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 33.6 Set Depth (ft… 7,200.9 Set Depth (TVD) (… 6,044.0 Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE-8rd Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 33.6 33.6 0.07 HANGER GRAY GEN III TUBING HANGER 3.500 1,947.9 1,869.4 36.08 SAFETY VLV BAKER FVL SAFETY VALVE (LOCKED OUT 3/26/90) 2.810 6,937.4 5,819.5 32.59 PBR BAKER 10' PBR 3.000 6,951.1 5,831.1 32.44 PACKER BAKER FHL PACKER 3.000 7,097.9 5,955.7 31.51 BLAST RINGS CARBIDE BLAST RINGS (2) 2.992 7,173.3 6,020.3 30.84 LOCATOR BAKER LOCATOR SEAL ASSEMBLY 3.000 7,175.2 6,021.9 30.82 PACKER BAKER FB-1 PACKER 4.000 7,177.7 6,024.0 30.80 SBE BAKER SEAL BORE EXTENSION 3.000 7,190.7 6,035.2 30.68 NIPPLE CAMCO D NIPPLE NO GO 2.750 7,200.3 6,043.4 30.60 SOS BAKER SHEAR OUT SUB, ELMD @ 7182' PER SWS IPROF 6/11/2007 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) 7,149.0 5,999.4 31.06 PACKER WEATHERFORD ER PACKER 7/15/2011 1.750 7,151.8 6,001.9 31.03 PATCH PATCH ASSEMBLY - SPACER PIPE & SNAP LATCH (OAL=20.40') 7/15/2011 1.750 7,171.5 6,018.7 30.86 PACKER WEATHERFORD ER PACKER 5/21/2011 1.750 7,498.0 6,302.0 29.50 FISH 1" DMY Empty Pocket; Fell to Rathole from GLV @6990' 11/7/85 11/7/1985 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,100.0 7,135.0 5,957.5 5,987.4 C-4, 2B-08 7/14/1984 12.0 APERF 120 deg. phasing; SOS 5 1/2" Csg Gun 7,216.0 7,222.0 6,057.0 6,062.2 A-5, 2B-08 7/25/1984 4.0 APERF 90 deg. phasing; 2 1/8" Tornado Link Jet 7,233.0 7,256.0 6,071.7 6,091.5 A-4, 2B-08 6/24/1984 4.0 IPERF 2 1/8" 'GO' Link Jet 7,277.0 7,298.0 6,109.7 6,127.9 A-3, 2B-08 6/24/1984 4.0 IPERF 2 1/8" 'GO' Link Jet Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 6,891.1 5,780.6 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 7/25/1984 2 6,989.8 5,863.8 MMH FMHO 1 INJ DMY BK 0.000 0.0 8/14/1992 3 7,059.6 5,923.2 MMH FMHO 1 INJ DMY BK 0.000 0.0 11/10/1992 4 7,161.6 6,010.2 MMH FMHO 1 INJ PATC H 0.000 0.0 5/27/2005 Notes: General & Safety End Date Annotation 4/29/1999 NOTE: Scale obstruction found @ 802'' WLM 12/4/2009 NOTE: SEAL WELD ON BOTTOM OF STARTER HEAD (NO PATCH) 8/22/2011 NOTE: View Schematic w/ Alaska.Schematic9.0 Comment SSSV: LOCKED OUT 2B-08, 6/14/2018 12:52:44 PM Vertical schematic (actual) PRODUCTION; 35.5-7,500.0 FISH; 7,498.0 IPERF; 7,277.0-7,298.0 IPERF; 7,233.0-7,256.0 APERF; 7,216.0-7,222.0 SOS; 7,200.3 NIPPLE; 7,190.7 SBE; 7,177.7 PACKER; 7,175.2 LOCATOR; 7,173.3 PACKER; 7,171.5 INJECTION; 7,161.6 PATCH; 7,151.8 PACKER; 7,149.0 APERF; 7,100.0-7,135.0 INJECTION; 7,059.6 INJECTION; 6,989.8 PACKER; 6,951.1 PBR; 6,937.4 GAS LIFT; 6,891.1 SURFACE; 37.0-3,030.0 SAFETY VLV; 1,947.9 CONDUCTOR; 38.0-117.0 HANGER; 33.6 Last Tag Annotation Last Tag: SLM End Date 6/13/2018 Depth (ftKB) 7,358.0 Last Mod By fergusp Last Rev Reason Annotation Rev Reason: Drift 7 tag End Date 6/13/2018 Last Mod By fergusp KUP INJ KB-Grd (ft) 35.99 Rig Release Date 2/28/1984 Annotation Last WO: End Date 2B-08 H2S (ppm) Date... TD Act Btm (ftKB) 7,500.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292107900 Wellbore Status INJ Max Angle & MD Incl (°) 39.60 MD (ftKB) 3,700.00 From:Wallace, Chris D (CED) To:AOGCC Records (CED sponsored) Subject:FW: Kuparuk Injector 2B-08 (PTD #184-026) report of recharging IA. Date:Tuesday, October 26, 2021 9:29:38 AM Attachments:image001.png 2B-08 90 Day TIO.pdf 2B-08.pdf From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Tuesday, October 26, 2021 8:44 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>; Well Integrity Specialist CPF2 <n2549@conocophillips.com> Subject: Kuparuk Injector 2B-08 (PTD #184-026) report of recharging IA. Chris- Kuparuk injector 2B-08 (PTD #184-026) was reported by operation with a recharging IA after multiple bleed attempts beyond what would be expected from the thermal influence of changing from gas to water injection. CPAI intends to leave the well on water injection while DHD conducts the initial set of diagnostic testing. If the well passes the initial testing, the well will be placed on a 30 day monitor period for further verification of integrity. If the diagnostic testing fails, the proper paperwork for continued injection or repair will be submitted as required. Please let me know if you have any questions or disagree with this plan. Attached is a copy of the current wellbore schematic and 90 day TIO plot. Dusty Freeborn Wells Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.25 Top (ftKB) 38.0 Set Depth (ftKB) 117.0 Set Depth (TVD) … 117.0 Wt/Len (l… 65.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 37.0 Set Depth (ftKB) 3,030.0 Set Depth (TVD) … 2,726.3 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 35.5 Set Depth (ftKB) 7,500.0 Set Depth (TVD) … 6,303.7 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 33.6 Set Depth (ft… 7,200.9 Set Depth (TVD) (… 6,044.0 Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE-8rd Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 33.6 33.6 0.07 HANGER GRAY GEN III TUBING HANGER 3.500 1,947.9 1,869.4 36.08 SAFETY VLV BAKER FVL SAFETY VALVE (LOCKED OUT 3/26/90) 2.810 6,937.4 5,819.5 32.59 PBR BAKER 10' PBR 3.000 6,951.1 5,831.1 32.44 PACKER BAKER FHL PACKER 3.000 7,097.9 5,955.7 31.51 BLAST RINGS CARBIDE BLAST RINGS (2) 2.992 7,173.3 6,020.3 30.84 LOCATOR BAKER LOCATOR SEAL ASSEMBLY 3.000 7,175.2 6,021.9 30.82 PACKER BAKER FB-1 PACKER 4.000 7,177.7 6,024.0 30.80 SBE BAKER SEAL BORE EXTENSION 3.000 7,190.7 6,035.2 30.68 NIPPLE CAMCO D NIPPLE NO GO 2.750 7,200.3 6,043.4 30.60 SOS BAKER SHEAR OUT SUB, ELMD @ 7182' PER SWS IPROF 6/11/2007 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) 7,149.0 5,999.4 31.06 PACKER WEATHERFORD ER PACKER 7/15/2011 1.750 7,151.8 6,001.9 31.03 PATCH PATCH ASSEMBLY - SPACER PIPE & SNAP LATCH (OAL=20.40') 7/15/2011 1.750 7,171.5 6,018.7 30.86 PACKER WEATHERFORD ER PACKER 5/21/2011 1.750 7,498.0 6,302.0 29.50 FISH 1" DMY Empty Pocket; Fell to Rathole from GLV @6990' 11/7/85 11/7/1985 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,100.0 7,135.0 5,957.5 5,987.4 C-4, 2B-08 7/14/1984 12.0 APERF 120 deg. phasing; SOS 5 1/2" Csg Gun 7,216.0 7,222.0 6,057.0 6,062.2 A-5, 2B-08 7/25/1984 4.0 APERF 90 deg. phasing; 2 1/8" Tornado Link Jet 7,233.0 7,256.0 6,071.7 6,091.5 A-4, 2B-08 6/24/1984 4.0 IPERF 2 1/8" 'GO' Link Jet 7,277.0 7,298.0 6,109.7 6,127.9 A-3, 2B-08 6/24/1984 4.0 IPERF 2 1/8" 'GO' Link Jet Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 6,891.1 5,780.6 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 7/25/1984 2 6,989.8 5,863.8 MMH FMHO 1 INJ DMY BK 0.000 0.0 8/14/1992 3 7,059.6 5,923.2 MMH FMHO 1 INJ DMY BK 0.000 0.0 11/10/1992 4 7,161.6 6,010.2 MMH FMHO 1 INJ PATC H 0.000 0.0 5/27/2005 Notes: General & Safety End Date Annotation 4/29/1999 NOTE: Scale obstruction found @ 802'' WLM 12/4/2009 NOTE: SEAL WELD ON BOTTOM OF STARTER HEAD (NO PATCH) 8/22/2011 NOTE: View Schematic w/ Alaska.Schematic9.0 Comment SSSV: LOCKED OUT 2B-08, 6/14/2018 12:52:44 PM Vertical schematic (actual) PRODUCTION; 35.5-7,500.0 FISH; 7,498.0 IPERF; 7,277.0-7,298.0 IPERF; 7,233.0-7,256.0 APERF; 7,216.0-7,222.0 SOS; 7,200.3 NIPPLE; 7,190.7 SBE; 7,177.7 PACKER; 7,175.2 LOCATOR; 7,173.3 PACKER; 7,171.5 INJECTION; 7,161.6 PATCH; 7,151.8 PACKER; 7,149.0 APERF; 7,100.0-7,135.0 INJECTION; 7,059.6 INJECTION; 6,989.8 PACKER; 6,951.1 PBR; 6,937.4 GAS LIFT; 6,891.1 SURFACE; 37.0-3,030.0 SAFETY VLV; 1,947.9 CONDUCTOR; 38.0-117.0 HANGER; 33.6 Last Tag Annotation Last Tag: SLM End Date 6/13/2018 Depth (ftKB) 7,358.0 Last Mod By fergusp Last Rev Reason Annotation Rev Reason: Drift 7 tag End Date 6/13/2018 Last Mod By fergusp KUP INJ KB-Grd (ft) 35.99 Rig Release Date 2/28/1984 Annotation Last WO: End Date 2B-08 H2S (ppm) Date... TD Act Btm (ftKB) 7,500.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292107900 Wellbore Status INJ Max Angle & MD Incl (°) 39.60 MD (ftKB) 3,700.00 Annular Communication Surveillance 28-Jul-2021Well Name:2B-08 Start Date:28-Jul-2021 26-Oct-2021Days:90 End Date:26-Oct-2021 50 60 70 80 90 100 110 120 130 140 150 0 500 1000 1500 2000 2500 3000 3500 4000 28-Jul-2131-Jul-213-Aug-216-Aug-219-Aug-2112-Aug-2115-Aug-2118-Aug-2121-Aug-2124-Aug-2127-Aug-2130-Aug-212-Sep-215-Sep-218-Sep-2111-Sep-2114-Sep-2117-Sep-2120-Sep-2123-Sep-2126-Sep-2129-Sep-212-Oct-215-Oct-218-Oct-2111-Oct-2114-Oct-2117-Oct-2120-Oct-2123-Oct-2126-Oct-21Temperature (degF)Pressure (PSI)Pressure Summary WHP IAP OAP WHT 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 28-Jul-2131-Jul-213-Aug-216-Aug-219-Aug-2112-Aug-2115-Aug-2118-Aug-2121-Aug-2124-Aug-2127-Aug-2130-Aug-212-Sep-215-Sep-218-Sep-2111-Sep-2114-Sep-2117-Sep-2120-Sep-2123-Sep-2126-Sep-2129-Sep-212-Oct-215-Oct-218-Oct-2111-Oct-2114-Oct-2117-Oct-2120-Oct-2123-Oct-21Injection Rate (BPD or MSCFD)Injection Rate Summary DGI MGI PWI SWI BLPD MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg '5` DATE: Wednesday, May 20, 2020 P.I. Supervisor ""y� �/' l �W SUBJECT: Mechanical Integrity Tests l ConocoPhillips Alaska, Inc. 213-08 FROM: Lou Laubensteln KUPARUK RIV UNIT 211-08 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry JTF-- NON -CONFIDENTIAL Comm I Well Name KUPARUK RIV UNIT 2B-08 Insp Num: mitLOL200511064927 Rel Insp Num: 1 28-08 Type 1840260 TYPe Pumped: 3 Ma�TST Notes: API Well Number 50-029-21079-00-00 Inspector Name: Lou Laubenstcin Permit Number: 184-026-0 Inspection Date: 5/10/2020 1 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Inj W TVD 5831 Tubing 2240 - 2240- 2240 - 2240 - Test sPT est psi 1500 - IA 460 3000. 2840- 2790 - BBL Returned: 2.9 OA I 40 90 90 - 90 - P/F P f Wednesday, May 20, 2020 Page I of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,December 07,2016 TO: Jim Regg ,, � P.I.Supervisor jRe' 12-11 IIC� SUBJECT: Mechanical Integrity Tests (( CONOCOPHILLIPS ALASKA INC 2B-08 FROM: Bob Noble KUPARUK RIV UNIT 2B-08 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2B-08 API Well Number 50-029-21079-00-00 Inspector Name: Bob Noble Permit Number: 184-026-0 Inspection Date: 12/1/2016 Insp Num: mitRCN161201144902 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2B-o8 Type Inj W TVD 5831 - Tubing 2825 2825 2825 • 2810 - 2850 PTD 1840260 Type Test SPT Test psi 1500 - IA 1360 2160 - 2075 - 2090- 2110 • Interval 4YRTST P/F I ' OA 60 60 - 60 - 60 60 Notes: Temperature did not stablize.Had them bleed the IA back down.Test result inconclusive. SCANNED MAY 1 1201? Wednesday,December 07,2016 Page 1 of 1 • S MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Wednesday,December 07,2016 " P.I.Supervisor le r'j 7. 14 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2B-08 FROM: Bob Noble KUPARUK RIV UNIT 2B-08 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supryy,y_ NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2B-08 API Well Number 50-029-21079-00-00 Inspector Name: Bob Noble Permit Number: 184-026-0 Inspection Date: 12/1/2016 Insp Num: mitRCN161201145504 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2B-08 Type'Ili W' TVD 5831 Tubing 2810 - 2810 - 2810 - 2810 PTD 1840260 Type Test SPT Test psi 1500 - IA 1410 2150 - 2075 - 2050 Interval aYRTST P/F P ' OA 60 60 - 60 , 60 - Notes: 2nd MIT-IA on this well today.The first would not stablize.Had them bleed the IA back down and we waited about 2 hours and did this test. ✓ SCANNED APR 0 6 2017 Wednesday,December 07,2016 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission � DATE: Wednesday,May 04,2016 TO: Jim Regg Il�� 5/15i 1b P.I.Supervisor SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2B-08 FROM: Chuck Scheve KUPARUK RIV UNIT 2B-08 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv,, NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2B-08 API Well Number 50-029-21079-00-00 Inspector Name: Chuck Scheve Permit Number: 184-026-0 Inspection Date: 5/1/2016 Insp Num: mitCS160502123840 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2B-08 1Type Inj Is 1TVD 5831 - Tubing 2400 2400 2400 - 2400 - PTD 1840260 Type Test SPT Test psi i 1500 - IA 460 1910 - 1820 1 810• Interval '4 'RTST PAF P OA so 50 so - so • Notes: 5ANNED SEP 2 7 2016 Wednesday,May 04,2016 Page 1 of 1 • . Kat Z/3.- Prn /84x Regg, James B (DOA) From: NSK Problem Well Supv [n1617 ©conocophillips.com] Sent: Monday, May 14, 2012 8:07 PM � 1i f To: Regg, James B (DOA) 1' I Cc: Brooks, Phoebe L (DOA); Dethlefs, Jerry C; NSK Problem Well Supv Subject: RE: Kuparuk witnessed MIT's Attachments: 2B -09 schematic.pdf; MIT KRU 2D -04 05- 10- 12.xls Jim, 2D -04 — Attached is a corrected MIT form with the MITOA added on it. I apologize for not having that on there. The initial pressure on the OA was 0 psi and remained 0 psi throughout the test so the OA shut in equipment would not have tripped during the CMIT TxIA. ✓2B -08 — The 6019' TVD is for the bottom packer for a tubing patch. The TVD for the Baker FHL production packer is 5831' TVD as noted on the schematic you are referencing. 2B -09 — The top production packer is at 5805' TVD and the lower packer is at the 5956' TVD. Attached is a wellbore schematic for reference. 2B -11 — I was unsure what to put in the result box so the test was designated inconclusive in the comment box. Thank you for clarifying for future reference. Please let me know if you have any further questions. Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. t�) Desk Phone (907) 659 -7224 MialED JUN Pager (907) 659 -7000 pgr. 909 From: Regg, James B (DOA) [mailto:jim.reggOalaska.gov] Sent: Monday, May 14, 2012 5:13 PM To: NSK Problem Well Supv Cc: Brooks, Phoebe L (DOA) Subject: [EXTERNAL]RE: Kuparuk witnessed MIT's KRU 2D -04 (PTD 1841510) - Did not see results of MITOA? - Please explain the 1000psi pre -test pressure on IA. According to AIO2B.037, this well is required to have installed and operational an auto shut in tied to the OA, with a required trip pressure of 1000psi. I understand that this would have to be defeated for the CMIT, a pre -test pressure of 1000psi is confusing VKRU 2B -08 (PTD 1840260) - Packer TVD should be 6019 ft based on the most recent well schematic in our well records (attached to 10 -404 for sundry 311 -147). - This raises a broader question relating to packer TVD. AOGCC and operators made a significant time commitment a few years back — including numerous reviews of well data — to resolve packer TVD differences; seems we are frequently discussing /debating packer TVD with CPAI. How does CPAI and AOGCC resolve this? KRU 2B -09 (PTD 1840270) - Packer TVD again; you show 5805 ft; we show 5956 ft; this time I do not have a well schematic to base this on, and no recent sundry notices /reports. At least the test pressure is unaffected KRU 2B -11 (PTD 1840350) 1 - Initial test shown inconclusive (pressure Toss did not stabilize); show this test result as "I" Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 - 7934236 From: NSK Problem Well Supv [ mailto :n1617(&conocophillips.com] Sent: Saturday, May 12, 2012 8:38 PM To: Regg, James B (DOA); Schwartz, Guy L (DOA); Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay Subject: Kuparuk witnessed MIT's All, Attached are the test forms for the MIT's performed on 05/10/12. These included 2B pad (wells 06 & 10 were not tested as they were shut in at the time of testing), 2D -04 CMIT TxIA & MITOA as per AIO 2B.037 and the witnessed retest of 2H- 16. Please let me know if you have any questions. Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr. 909 2 Pi Iflfo2- Regg, James B (DOA) From: Regg, James B (DOA) Sent: Thursday, April 05, 2012 5:31 PM \ 1f l 4(51(2„, To: 'NSK Problem Well Supv' Cc: Schwartz, Guy L (DOA); Brooks, Phoebe L (DOA) Subject: RE: KRU 2B -08 (PTD 184 -026) Request delay for MIT testing date Good approach. We will change our database to reflect the new anniversary date of 5/11/12 for KRU 2B -08. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 Ai ! k APP. 907 -793 -1236 From: NSK Problem Well Supv [ mailto :n1617(aconocophillips.com] Sent: Thursday, April 05, 2012 3 :16 PM To: Regg, James B (DOA) Cc: Schwartz, Guy L (DOA); NSK Problem Well Supv Subject: KRU 2B -08 (PTD 184 -026) Request delay for MIT testing date Jim, ConocoPhillips requests permission to defer the MIT test date for 2B -08 (PTD 184 -026) until 05/31/12 at the latest. The well was previously granted AIO 2B.031 on 05/16/08 to continue injection with a surface casing leak and the MIT anniversary date on the AA was established as 04/11/08. The surface casing leak was repaired, ConocoPhillips requested cancellation of AIO 2B.031 on 12/20/09 and received the cancellation notice from the AOGCC on 01/11/10. Due to the cancellation of the AA, my understanding would be that the MIT is due by 04/11/12. The rest of 2B pad is required to be tested by 05/11/12, the request is delay the testing one month and to test this well when the rest of the pad is tested. Please let me know if this is acceptable. Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr. 909 1 2Y - k WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. September 14, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Injection Profile: 2B -08 Run Date: 8/26/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2B -08 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50- 029 - 21079 -00 Injection Profile Log �� 1 Color Log it 50- 029 - 21079 -00 s i MP 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: Ri i • nj 2- Sig I WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. May 23, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Setttin : 2B -08 t. ;1 "L} Run Date: 5/21/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2B -08 Digital Data in LAS format, Digital Log Image file b'1 1 CD Rom 50- 029 - 21079 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: / 3 A.6 E 1 Signed: IS Y— ok6 STATE OF ALASKA ALASKA•AND GAS CONSERVATION COMMISSI410 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell r Plug Perforations f Stimulate r Other p- Install Tubing Rill Tubing Perforate New Pool W Patch Alter Casing �' 9 � r r Time Extension Change Approved Program r Operat. Shutdow n r Perforate f ' Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r ' 184 - 026 3. Address: 6. API Number: 4 Stratigraphic f Service p' 00 P. O. Box 100360, Anchorage, Alaska 99510 50- 029 - 21079 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25656 " 2B - 9. Field /Pool(s): v Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 7500 feet Plugs (measured) None true vertical 6304 feet Junk (measured) 7498 Effective Depth measured 7410 feet Packer (measured) 6951, 7149, 7172, 7175 true vertical 6225 feet (true vertucal) 5831, 5999, 6019, 6022 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 117 117 SURFACE 2993 9.625" 3030 2726 PRODUCTION 7465 7 7500 6304 'j Olt Perforation depth: Measured depth: 7100'- 7135', 7216- 7222', 7233'- 7256', 7277' -7298' ., True Vertical Depth: 5958'- 5988', 6057'- 6062', 6072'- 6092', 6110' -6128' i, ' _ i., $ir.kiIISSIOf Tubing (size, grade, MD, and TVD) 3.5, J -55, 7200 MD, 6043 TVD "Tr Packers & SSSV (type, MD, and TVD) PACKER - BAKER FHL PACKER @ 6951 MD and 5831 TVD PACKER - WEATHERFORD ER PACKER @ 7149 MD and 5999 TVD PACKER - WEATHERFORD ER PACKER @ 7172 MD and 6019 TVD PACKER - BAKER FB -1 PACKER @ 7175 MD and 6022 TVD SAFETY VLV - BAKER FVL SAFETY VALVE @ 1948 MD and 1869 TVD 11. Stimulation or cement squeeze summary: 1 Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Developm ent r Service r IV Stratigraphic r 15. Well Status after work: Oil f0 Gas r WDSPL r Daily Report of Well Operations XXX GSTOR fl WINL WAG GINJ r SUSP r SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 311 -147 Contact John Peirce a 265 -6471 Printed Name John Peirce Title Wells Engineer Signature / Phone: 265 -6471 Date � f` /T+ ' .4 "~ — Ropms JUL 2 8 1011 Form 10 -4 4 Revised 1 /2010 < _® 7 Submit Original Only 2B -08 Well Work Summary DATE SUMMARY 3/22/11 TAGGED @ 7270' SLM, EST. 16' *HOLE. BRUSHED AND FLUSHED PATONTERVAL @ 7145' - 7191' RKB. READY FOR CALIPER. 4/7/11 RUN SONDEX 24 ARM CALIPER TOOL TO 7201' RKB (END OF TUBING). LOG SURVEY FROM TTL TO SURFACE AT LOGGING SPEED OF 50 FPM. 5/9/11 DRIFT TBG TO D -NIP @ 7191' RKB W/ 2.80" X 15' DMY PATCH. READY FOR E -LINE. 1/ 5/21/11 SET WEATHERFORD ER PACKER AT 7154.5'. CORRELATED TO 1 -23 -10 HES IPROF. CCL STOP DEPTH AT 7139. TO MID - ELEMENT LENGTH IS 14.8'. * * *ER packer at 7171.5' based on tubing tally- set 2' above base of 5' pup joint below GLM * * ** 7/15/11 SET WEATHERFORD UPPER ER PACKER / SPACER PIPE / SNAP LATCH ASSEMBLY @ 7171' RKB (OAL 20.79' , 1.75" ID). TESTED UPPER PACKER & TBG TO 2500 PSI, GOOD TEST. COMPLETE. KUP • 2B 08 Well Attributes _ Max Angie & MD TD Alasita. inc. Welltore APYUWI Feld Name Well Status Incl (°) MD (ftKB) Act Btu (ftKB) ' t..a+r �cofia lhps . 500292107900 IKUPARUK RIVER UNIT INJ 39.6 3,700 00 7,500 0 ' Comment H2S (ppm) Date An otation End Date IKB - Grd (ft) Rig Release Date SSSV: LOCKED OUT I !Annotation WO _ I 35 99 2/28/1984 - . - _ wgil - 0,9 Bg;,,,;, sau ,alit e �t� rk PM - Annotation Depth (ftKB) [ End Date Annotation !Last Mod ... End Date Last Tag SLM 7,270.0 I 3/22/2011 [Annotation Reason: SET PATCH ninam 7/19/2011 d = Casing Strings I Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd HANDER, 34- °" / '" _- CONDUCTOR 16 15.250 370 117 -0 117.0 65.50 H-40 WELDED ._. _ "% "; Casing Description String 0... String ID ... Top (tfKB) 6) Set Depth ((. Set Depth (TVD) ... String Wt... String ... String Top Thrd F 9 g 0 String D __.. Top (ftKB ) Set Depth O 7 ^ g O Wt... , J 55 BTC p ( t_ Set Depth h (ND) .. String J 55 BTC Casing Tubing Strings Details 37 0 String String Top Thrd • i Description tion Strm 59 2 3 P PRODUC L ION 7 6 276 35 5 7,500 0 6 303 7 26 00 f UBING P 31/2 2.992 336 72009 Set Depth (f -. Set Depth (ND) .. 6,043.9 930 Strip Wt... ' J 5 S J - 5 5 g .. String U T p Thrd E - Srd . .. Completion Tubing Desch Lion Strip 0.. Strip ID .. Top (ftKB CONDUCTOR, Top Depth 37 -117 (TVD) Top Intl Nomi... Top (185) 0 0 (1 Item Description Comment - -...- ID (in) 33.6 33.6 0.07 HANGER GRAY GENII! TUBING HANGER 3.500 - >i... 1,947.9 1,869.2 36.08 SAFETY VLV BAKER FVL SAFETY VALVE (LOCKED OUT 3/26/90) 2.810 SAFETY VLV, - -" - ._--'- - - 1.948 6,937.4 5,819.6 32.59 PBR BAKER 10' PBR 3.000 i t 6,951.1 5,831.2 32.44 PACKER BAKER FHL PACKER 3.000 4*,. 7,097.9 5,955.7 31.52 BLAST RINGS CARBIDE BLAST RINGS 2.992 7,173.3 6, 020.3 30.84 LOCATOR BAKER LOCATOR SEAL ASSEMBLY 3.000 ,i 7,175.2 6,021.9 30.82 PACKER BAKER FB-1 PACKER 4.000 i ' [ 7,177.7 6,024.0 30.80 SBE BAKER SEAL BORE EXTENSION 3.000 7,190.7 6,035.2 30.68 NIPPLE CAMCO D NIPPLE NO GO 2.750 SURFACE„______ 37 - 3,930 7200 6,043.4 30.10 SOS BAKER SHEAR OUT SUB, ELMD @ 7182' PER SWS IPROF 661/2007 2.500 GAS LIFT, _ Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etch - 6,891 - - Top Depth - __- (TVD) Top Ind Top (M(9) ("KB) (°) Deudption Comment Run Date ID (in) 7,149 5,999.5 31.06 PACKER WEATHERFORD ER PACKER 7/15/2011 1.750 7,152 6,002.0 31.03 PATCH PATCH ASSEMBLY - SPACER PIPE & SNAP LATCH 7/15/2011 1.750 PBR. 9937 - - _. 4 _. (OAL= 20.40') - ... PACKER, 6,951 l 7,172 6,018.7 30.86 PACKER WEATHERFORD ER PACKER 5/21/2011 1.750 7,498 6,302.0 29.50 FISH 1" DMY Empty Pocket Fell to Rathole from GLV @6990' 11/7/1985 11/7/85 INJECTION._. 6,990 Perforations & Slots `-' - _ Shot Top (TVD) Btm (TVD) Dens INJECTION,___- Top (ftKB) Btm (tk(5) (BNB) (Wail) Zone Date (sh..- Type Comment 7ION, 7,100 7,135 5,957.5 5,987.5 C-4, 28-08 7/14/1984 12.0 APERF 120 deg. phasing; SOS 5 1/2" Csg Gun 7,216 7,222 6,057.0 6,062.1 A -5, 26-08 7/25/1984 4.0 APERF 90 deg. phasing; 2 1/8" Tornado Link Jet APERF, "(Pf 7,100 -7,135 . 7,233 7,256 6,071.6 6,091.5 A -0, 29-08 6/24/1984 4.0 IPERF 2 1/8" 'GO' Link Jet 7,277 7,298 6,109.7 6,127.9 A -3, 28-08 6/24/1984 4.0 IPERF 2 1/8" 'GO' Link Jet -- - _ -_- Notes: General & Safety End Date Annotation 180<08,7,149 ' „ ' - 4/29/1999 NOTE Scale obstruction found @ 802" WLM 12/42009 NOTE SEAL WELD ON BOTTOM OF STARTER HEAD (NO PATCH) ' : NOTE: View Schematic w/ Alaska.Schematic9.0 . PATCH, 7,152 INJECTION, 7,162 i PACKER, 7,172 r; r LOCATOR, I 7,173 PACKER, 7,175 SBE,7,178 'j„ NIPPLE, 7,191 - ( 7( SOS, 7,200 -. -.. APERF, 7,216-7,222 Mandrel Details Top Depth Top Port (1 VD) Inc' OD Valve Latch Size TRO Run IPERF, Stn Top (ftKB) (6K8) ( °) Make Model (in) Sery TYW ryDa (In) (ps i) Run Date Com... 7.233 - 7.259 1 6,891.1 5,780.6 33.10 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 7/25/1984 . 2 6,989.8 5,863.8 32.01 MMH FMHO 1 INJ DMY BK 0.000 0.0 8/14/1992 IPERF. - 3 7,059.6 5,923.3 31.86 MMH FMHO 1 INJ DMY BK 0.000 0.0 11/10/1992 7,277 - 7,298 • . 4 7,161.6 6,010.3 30.95 MMH FMHO 1 INJ HFCV BEK 0.000 0.0 5/27/2005 FISH, 7,498 PRODUCTION, 357,500 j I TD, 7,500 i • WELL LOG TRANSMITTAL r� PROACTIVE DIACINOSTIC SERVICES, INC. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 [907) 659 -5102 RE : Cased Hole /Open Hole /Mechanical Logs and /or Tubing Inspection[Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 h1`, 2 3 r CIO- Q69 Lib 1) Caliper Report 07 -Apr -1 1 2B -08 1 Report / EDE 50 -029- 21079 -00 .., 1 77 031a Signed : Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 C\Documents and Settings\Diane Williams \Desktop \CIE_Transmit.docx 1 • • I IIIII,_ emor ilp M u It i-F i n ge r Caliper Log Results Summary 1 Company: ConocoPhillips Alaska, Inc. Well: 2B -08 Log Date: April 7, 2011 Field: Kuparuk River Unit Log No.: 10258685 ZX70 State: Alaska I Run No.: 1 API No.: 50-029-21079-00 Pipet Desc.: 3.5" 9.3 Ib. J -55 8rd EUE ABM Top Log Intvll.: Surface Pipet Use: Tubing & Liner Bot. Log Intvll.: 7,182 Ft. (MD) 1 Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS : 1 This caliper data is tied into the bottom of the 3.5" tubing at 7,182 ELMD per the SWS !PROF (dated 6/11/2007). I This log was run to assess the condition of the 3.5" tubing with respect to corrosive and mechanical damage. The caliper recordings indicate the tubing is in good to poor condition with respect to corrosive damage. Wall penetrations from 20% to 43% are recorded from — 5,000' to the end of the tubing. The damage appears in the forms of pitting, lines of pits and line corrosion. No significant areas of cross - sectional wall are 1 recorded. Although no significant minimum I.D. restrictions are recorded, the caliper recordings indicated buckled tubing, where the caliper recorded areas of oval deformation, and slight scale buildup. A 3 -D log plot of the 1 caliper recordings across the buckled 3.5" tubing is included in this report. This is a second analysis of the data from this log, following a field tool calibration correction from I the field services provider. A consistent correlation between tool eccentricity and increased average pipe ID resulting from abnormal elongation of the long axis of pipe ovality recordings in this data set cause concern for the accuracy of this corrected data set. 1 This summary report is interpretation of data provided by Halliburton Energy Services. MAXIMUM RECORDED WALL PENETRATIONS: 1 Oval with Line Corrosion ( 43 %) Jt. 225.1 @ 7,143 Ft. (MD) Oval with Isolated Pitting ( 38 %) Jt. 221 @ 6,983 Ft. (MD) Oval with Isolated Pitting ( 30 %) Jt. 220 @ 6,973 Ft. (MD) I Oval with Line Corrosion ( 25%) Jt. 225.8 @ 7,181 Ft. (MD) Oval with Line of Pits (25 %) Jt. 225.3 @ 7,153 Ft. (MD) MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS: 1 No significant areas of cross - sectional wall loss (> 11 %) are recorded. I MAXIMUM RECORDED ID RESTRICTIONS: Although no significant I.D. restrictions are recorded, the caliper recordings indicate buckling throughout the bottom of the logged interval, where the caliper recorded areas of slight oval deformation, and slight scale 1 buildup throughout the log interval. I I Field Engineer: E. Regnier Analyst: M. Lawrence Witness: J. Condio ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565 -9085 Fax: (281) 565 -1369 E -mail: PDS:amemorylog.com Prudhoe Bay Field Office Phone: (907) 659 -2307 Fax: (907) 659 -2314 1 1 / IN — c -G 2 09 qe I • • PDS Multifinger Caliper 3D Log Plot Company : ConocoPhillips Alaska, Inc. Field : Kuparuk River Unit Well : 2B -08 Date : April 7, 2011 I Description : Detail of Caliper Recordings Across Buckled 15" Tubing Comments Depth Maximum Radius 3 -D Log (Off - Center) nage Map (Off- Centei 3 -D Log (Centered) Image Map (Centered I 1ft:1050R 1.25 inches Minimum Radius 1.75 0° 0° 90° 180° 270° 0° 0° 0° 90° 180° 270° 0° I I 1.25 inches 1.75 I Nominal Radius . 1 .25 inches 1.75 IMO Jt. 133 Jt. 134 4250 - -- 1 Jt. 135 �m :;- __ 4300 — - - - Jt. 136 I Jt. 137 i� o-- 4350 � — --- r Jt.138 Jt.139 4400 �L� IIIIIIIIIII'lllllll illt�IIIIIIIIIIIIIIIIIIIIIIIII, -- Jt. 140 - =� ' 4450 �_�ls��i�_ - - Jt 141 = •' i - _ �i 11t.■.�ii imi.49 . Jt 142 ��a�a�� I 4500 �� riii - il�a��ii _ __ - _ - Jt 143 _ s�� - , • 1 Jt. 144 4550 �� 1 i .; Jt. 145 - 1 s " 1 ! �__ Jt. 146 4600 Jt. 147 - . 4650 --_ - ., Jt. 148 T _ ti Jt. 149 4700 - ---- - s- t Jt 150 == � '• • Jt.151 4750 NIM■ - _ II ii Jt. 152 ` == . ! a 4800 E �� = ' . Jt. 153 S 11111/EM = -— • Jt. 154 4850 J 1 1 • f Ip Jt. 155 IN'MIIMIIMI 27%41" 1" a • 4900 1�7 ■� ilIFIENNIENNIIIII Jt. 156 M11111111111111111 A --- dri•MIIIIIIII• - 1�1• ∎� - - Jt. 157 4950 1 �� ' 1! M_1111♦ - - - - Jt. 158 41116,111111111111111111 _ - _ • •�� _ Jt. 159 5000 ♦ra rit11111111M111111M1 a1111>,_11111 Jt. 160 5050 ell11:1111.1111.1.11111111mi - I Jt.161 • 5100 I Jt. 162 tri,mmmim s �� r 3 �� Jt.163 WA�� ; - c -- 5150 �� _. I Jt.164 a I1�> i�� - ��= le - Jt. 165 5200 �� - - . i "'- ill Jt. 166 = +t . ; s. 5250 Er � - I Jt. 167 ' M to �afJlrIm� _ -r Jt. 168 5300 �Sia �� - - 1 w Iltr4111111111.1.11. lr/�� " __ Jr Jt.169 i�■� ®11♦♦∎ 5350 _ 7 � Jt. 170 ��_ ?' rr ai _ -- Jt.171 �J�� k ra•�a� 5400 • �i _� _ _ �i�aaa�� Jt. 172 - Jt. 173 5450 it�MI� - I Irivamml [�aa �aaM _ II 'r Jt. 174 �M_� L :>• ∎� 5500 riimim. Jt. 175 ia1aa�� A �..�� 'F��r Jt.176 5550 L`i�� 7 � / � r _ Jt. 177 ir�1•∎ z n iwitimmi 111111111=11111M• 5600 7!>>mmr IF Jt. 178 i , • 3' cAandmi .... m ....... ilf�-.....7 11��1♦1♦ " - Jt. 179 5650 i�7�� i� = � Jt. 180 1NVA111■_ 1 F _ Immeanimmil■ •�asl �� ®�� ■■i I Jt. 181 r 5700 mss � � - • -- Jt. 182 1�1•a♦�∎ i : z 1 i 1 • • .. - - 5750 =I UM 1 ° Jt.183 =atom - EiK� r . Jt. 184 5800 illl - �)•M - 1 Jt. 185 11111111ANI 11 _ a 5850 _ • "" Jt. 186 ' - Jt. 187 �� x 5900 lilll : .. Jt. 188 sirl• 1. I r� E-M Jt. 189 5950 ri�a lard = Il Jt.190 11:: 6000 i7[tlI Jt.191 liiti '' I Jt. 192 6050 =AGM '&- ��) -- ��i 1 , Jt. 193 6100 ` : , '"' Jt. 194 - t- — - , -. , �..,a Jt. 195 Mt - 6150 MIE Er 'a + Jt. 196 E at - -_ , — Jt. 197 6200 i Jt. 198 . , I i s 6250 lI JII Jt. 199 =fr t 1 Jt. 200 6300 NSW ..F ; .11.111 Jt. 201 - 6350 — — . Jt 202 Jt. 203 1111111&111 3 6400 E,i •--.E Jt. 204 ii1 : - Jt. 205 6450 �i�. _ Jt.206 Miff+ t�Mi 6500 I IBlE� � Jt. 207 !�! liEt� Jt. 208 6550 M11/�� ., Jt. 209 = I Jt. 210 NEIL • J - I 1 !_ ! 111 Jt. 211 6650 ->_.■•••• Jt. 212 E _ sw IEEE 1 Jt.213 6700 = i Jt. 214 ■Noir -I•mmoisi i 4 II 6750 �iR�a� _ - Jt. 215 �7�� ∎� s miEta�M1 r Jt. 216 �7I�� __ . - AMP II 6800 lir1WIIIIIIIIIIIM■ l k Imo∎ - - Jt.217 7�� MIIIIIIIIIMIN■ at j 44 6850 �� - Jt. 217 �LI7 ;.a1� V GLM #1 - MinililladA11111111111111111 , 1 ��......- T Jt 219 6900 111.11111111M11.11111 �ii�it�� vi 11. Packer M� /VN/M 6950 �`lfE g I Jt. 220 — - �..,... .t 8 Inj#2 �]�frr� Jt. 221 7000 m1tM� _ II t4F-1111■1 Jt. 222 11•11`1M■1 r.w - Inj #3 7050 ` .. ��ir, . I Jt. 223 1111111=1161111111110 - �sIE�� : 111=1111111114m=11 _ Jt. 224 7100 �■sir� - - mirm� - i7l7� . - Jt. 225 ��7�`' I t IMirsl� -. Inj #4 7150 or` --- � AK _--=. _ 1 Pkr, Nip, TTL ■IIMININIMIti/r.�∎ _ - aummor ��7L= MINIIIM 7200 MI ' � 11111MM1 1 Nominal Radius • 1.25 inches 1.75 I I Minimum Radius 1 1 . 25 inches 1.75 Comments Depth Maximum Radius 3-D Log (Off- Center)nage Map (Off - Centel 3-0 Log (Centered) Image Map (Centered is s t 11t:1050ft 1.25 inches 1.75 0° 0° 90° 180° 270° 0° 0 0° 90° 180° 270° 0° 1 1 1 1 • • Correlation of Recorded Damage to Borehole Profile 1 ■ Pipe 1 3.5 in (50.3' - 7181.8') Well: 2B -08 Field: Kuparuk River Unit I Company: Conoco Alaska, Inc. Country: USA Survey Date: April 7, 2011 Phillips 1 1 ■ Approx. Tool Deviation ■ Approx. Borehole Profile 1 1 54 1 25 814 1 50 r.. 1601 1 ii- 75 lk 2418 1 100 3204 p v 2 n c Z 125 3967 t c a o 0 150 4 1 175 II 5499 200 6281 GLM 1 W— GLM 1 GI M2 1 GLM 4 274 _ 7112 4 1 225.9 7182 0 50 100 1 Damage Profile (% wall) / Tool Deviation (degrees) Bottom of Survey = 225.9 1 1 • • 1 PD S Report ort Overview TPS . Body Region Analysis 1 Well: 2B 08 Survey Date: April 7, 2011 Field: Kuparuk River Unit Tool Type: UW MFC 24 No. 1000429 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 I Country: USA No. of Fingers: 24 Tubing: 3.5 ins 9.3 ppf J-55 8RD EUE ABM Analyst: M. Lawrence Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom.Upset Upper len. Lower len. 3.5 ins 9.3 ppf J -55 8RD EUE ABM 2.992 ins 3.5 ins 6.0 ins 6.0 ins 1 I Penetration(% wall) Damage Profile (% wall) 250 — Penetration body Imo Metal loss body 0 50 100 1 200 0 150 100 1 50 0 49 I 0 to 20 to 40 to over 20% 40% 85% 85% Number of joints analysed (total = 235) all I 228 6 1 0 97 A M 1 Damage Configuration ( body) 40 1 30 14 _- 20 1 10 M 0 19 1 Isolated General Line Other Hole/ Pitting Corrosion Corrosion Damage Pos. Hole I Number of joints damaged (total = 35) 33 0 2 0 0 Bottom of Survey = 225.9 1 1 1 1 1 • 0 PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf J -55 8RD EUE ABM Well: 26-08 Body Wall: 0.254 in Field: Kuparuk River Unit Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: April 7, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 0.1 50 0 0 0 0 2.87 Pup Lt. Deposits. 1 54 0 0 0 0 2.86 Lt. Deposits. 1.1 86 0 0 0 0 2.84 Pup Lt. Deposits. 2 92 0 0 0 0 2.85 Lt. Deposits. 3 123 0 0 C. 2.85 Lt. Deposits. I 4 155 0 0 0 0 2.86 Lt. Deposits. 5 186 0 0 0 0 2.86 Lt. Deposits. 6 218 0 0 0 0 2.85 Lt. Deposits. 7 249 0 0.00 0 0 2.86 Lt. Deposits. I 8 281 0 0 0 0 2.86 Lt. Deposits. 9 312 0 0 0 0 2.85 Lt. Deposits. 10 343 0 0 0 0 2.85 Lt. Deposits. 11 375 0 0 0 0 2.85 Lt. Deposits. I 12 406 0 0.00 2 0 2.85 Lt. Deposits. 13 438 0 0 0 0 2.86 Lt. Deposits. 14 469 0 0 0 0 2.85 Lt. Deposits. 15 501 0 0 0 0 2.85 Lt. Deposits. 16 532 0 0 0 0 2.85 Lt. Deposits. I 1 7 563 0 0 0 0 2.85 Lt. Deposits. 18 595 0 0 0 0 2.85 Lt. Deposits. 19 627 0 0 0 2.85 Lt. Deposits. 20 658 0 0 0 2.86 Lt. Deposits. I 21 689 0 0 :) 2.84 Lt. Deposits. 22 720 0 0 0 2.85 Lt. Deposits. 23 751 0 0 0 2.86 Lt. Deposits. 24 783 0 0 0 2.85 Lt. Deposits. I 25 814 0 0 0 2.85 Lt. Deposits. 26 846 0 0 0 0 2.86 Lt. Deposits. 27 877 0 0 0 0 2.85 Lt. Deposits. 28 909 0 0 0 0 , 2.86 Lt. Deposits. I 29 940 0 0 0 0 2.87 Lt. Deposits. 30 972 0 0 0 0 2.86 Lt. Deposits. 31 1003 0 0 0 0 2.87 Lt. Deposits. 32 1035 0 0 0 0 2.86 Lt. Deposits. 33 1066 0 0 0 0 2.86 Lt. Deposits. I 34 1098 0 0 0 0 2.86 Lt. Deposits. 35 1130 0 0 0 0 2.86 Lt. Deposits. 36 1161 0 0 0 0 2.84 Lt. Deposits. 37 1192 0 0 0 0 2.86 Lt. Deposits. I 38 1224 0 0 0 0 2.86 Lt. Deposits. 39 1255 0 0 0 0 2.85 Lt. Deposits. 40 1287 0 0 0 0 2.86 Lt. Deposits. 41 1318 0 0 0 0 2.84 Lt. Deposits. I 42 1350 0 0 0 0 2.85 Lt. Deposits. 43 1381 0 0 0 0 2.85 Lt. Deposits. 44 1413 0 0 0 0 2.84 Lt. Deposits. 45 1444 0 0 0 0 2.85 Lt. Deposits. 46 1475 0 0 0 0 2.86 Lt. Deposits. I 47 1507 0 0 0 0 2.86 Lt. Deposits. 48 1538 0 0.00 0 0 2.84 Lt. Deposits. rat I Metal Loss ion Body 1 Page 1 Penet 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf J -55 8RD EUE ABM Well: 2B-08 Body Wall: 0.254 in Field: Kuparuk River Unit Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.992 in Country: USA Survey Date: April 7, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments ( %wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 49 1570 0 0 0 0 2.84 Lt. Deposits. 50 1601 0 0.00 0 0 2.85 Lt. Deposits. 51 1633 0 0.00 2 0 2.85 Lt. Deposits. 52 1664 , 0 0.01 4 0 2.86 Lt. Deposits. 53 1696 0 0 0 0 2.85 Lt. Deposits. I 54 1727 () 0.00 0 0 2.85 Lt. Deposits. 55 1759 () 0.00 2 0 2.85 Lt. Deposits. 56 1790 0 0.01 3 0 2.86 Lt. Deposits. 57 1821 0 0.01 3 0 2.86 Lt. Deposits. I 58 1853 0 0.01 3 0 2.86 Lt. Deposits. 59 1884 0 0.01 5 0 2.85 Lt. Deposits. 60 1916 0 0.01 3 0 2.85 Lt. Deposits. 60.1 1947 0 0 0 0 , 2.85 Pup Lt. Deposits. I 60.2 1955 0 0 0 0 2.77 Baker'FVL' SSV 60.3 1969 0 0.00 0 0 2.87 Pup Lt. Deposits. 61 1977 0 0 0 0 2.86 Lt. Deposits. 62 2008 0 0.01 3 0 2.85 Lt. Deposits. 63 2040 0 0.01 4 0 2.85 Lt. Deposits. I 64 2071 0 0.01 4 0 2.85 Lt. Deposits. 65 2103 0 0.01 4 0 2.86 Lt. Deposits. 66 2135 0 0.01 5 0 2.87 Lt. Deposits. 67 2166 0 0.02 9 0 2.87 Lt. Deposits. I 68 2197 0 0.01 4 0 2.87 Lt. Deposits. 69 2229 0 0.01 5 0 2.85 Lt. Deposits. 70 2261 0 0.02 6 0 2.85 Lt. Deposits. 71 2292 0 0.02 6 0 2.86 Lt. Deposits. I 72 2323 0 0.01 5 0 2.85 Lt. Deposits. 73 2355 0 0.02 9 0 2.87 Lt. Deposits. 74 2387 0 0.01 4 0 2.87 Lt. Deposits. 75 2418 0 0.02 6 0 2.85 Lt. Deposits. I 76 2449 0 0.02 8 0 2.85 Lt. Deposits. 77 2481 0 0.01 4 0 2.86 Lt. Deposits. 78 2512 0 0.01 4 0 2.85 Lt. Deposits. 79 2544 0 0.01 5 0 2.87 Lt. Deposits. 80 2575 0 0 0 0 2.85 Lt. Deposits. ' 81 2607 0 0 0 0 2.86 Lt. Deposits. 82 2638 0 0.03 10 0 2.86 Lt. Deposits. 83 2669 0 0.01 3 0 2.83 Lt. Deposits. 84 2701 0 0.01 3 0 2.86 Lt. Deposits. I 85 2733 0 0.01 4 0 2.87 Lt. Deposits. 86 2764 0 0.00 2 0 2.85 Lt. Deposits. 87 2795 0 0.04 14 0 2.86 Shallow Pitting. Lt. Deposits. NI 88 2827 0 0.03 13 0 2.88 Shallow Pitting. Lt. Deposits. II 89 2858 0 0.01 4 0 2.86 Lt. Deposits. 90 2890 0 0.02 6 0 2.87 Lt. Deposits. 91 2921 0 0.02 6 0 2.86 Lt. Deposits. 92 2952 0 0.01 3 0 2.87 Lt. Deposits. 93 2984 0 0.01 5 0 2.85 Lt. Deposits. I 94 3015 0 0.02 9 1 2.86 Lt. Deposits. 95 3047 0 0.01 4 0 2.87 Lt. Deposits. Penetration Body 1 I Metal Loss Body Page 2 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf J -55 8RD EUE ABM Well: 28-08 Body Wall: 0.254 in Field: Kuparuk River Unit I Upset Wall: 0.254 in Company: Co Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: April 7, 2011 nocoPhillips I Joint Jt Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Iris.) (Ins.) % (Ins.) 0 50 100 I 96 3078 0 0.02 6 0 2.85 Lt. Deposits. 97 3110 0 0.02 6 0 2.87 Lt. Deposits. 98 3141 0 0.02 8 0 2.85 Lt. Deposits. 99 3173 0 0.03 11 0 2.88 Lt. Deposits. I 100 3204 0 0.03 11 0 2.88 Lt. Deposits. 101 3235 0 0.00 2 0 2.85 Lt. Deposits. 102 3267 0 0.02 9 0 2.84 Lt. Deposits. 103 3298 0 0.03 10 0 2.84 Lt. Deposits. 104 3330 0 0.03 10 0 2.86 Lt. Deposits. I 105 3361 0 0.02 6 0 2.87 Lt. Deposits. 106 3393 0 0.01 4 0 2.88 Lt. Deposits. 107 3424 0 0.01 4 0 2.84 Lt. Deposits. 108 3455 0 0.01 5 0 2.86 Lt. Deposits. I 109 3485 0 0.02 6 0 2.86 Lt. Deposits. 110 3515 0 0.03 13 0 2.86 Shallow Pitting. Lt. Deposits. 111 3545 0 0.01 5 0 2.85 Lt. Deposits. 112 3574 0 0.02 8 0 2.85 Lt. Deposits. I 113 3605 0 0.02 8 0 2.87 Lt. Deposits. 114 3634 0 0.02 8 0 2.85 Lt Deposits. 115 3663 0 0.02 9 0 2.85 Lt. Deposits. 116 3694 0 0.01 4 0 2.85 Lt. Deposits. 117 3725 0 , 0.03 13 0 2.85 Shallow Pitting. Lt. Deposits. a I 118 3757 0 0.03 10 0 2.85 Lt. Deposits. 119 3788 0 0.01 3 0 2.84 Lt. Deposits. 120 3819 0 0.02 8 0 2.86 Lt. Deposits. 121 3851 0 0.00 2 0 2.86 Lt. Deposits. I 122 3879 0 0.02 6 0 2.85 Lt. Deposits. 123 3910 0 0.01 3 0 2.85 Lt. Deposits. 124 3938 0 0.00 2 0 2.87 Lt. Deposits. 125 3967 0 0.01 5 0 2.86 Lt. Deposits. I 126 3998 0 0.01 5 0 2.87 Lt. Deposits. 127 4028 0 0.01 5 0 2.87 Lt. Deposits. 128 4057 0 0 0 0 2.87 Lt. Deposits. 129 4086 0 0.03 11 0 2.86 Lt. Deposits. 130 4116 0 0 0 0 2.85 Lt. Deposits. I 131 4147 0 0.00 2 0 2.86 Lt. Deposits. 132 4178 0 0.02 9 0 2.86 Lt. Deposits. 133 4207 0 0.01 5 0 2.86 Lt. Deposits. 134 4237 0 0.01 3 0 2.87 Lt. Deposits. I 135 4266 0 0.00 2 0 2.87 Lt. Deposits. 136 4294 0 0 0 0 2.85 Lt. Deposits. 137 4325 0 0.01 5 0 2.87 Lt. Deposits. 138 4354 0 0.02 9 0 2.87 Lt. Deposits. I 139 4383 0 0 0 0 2.87 Lt. Deposits. 140 4412 0 0.01 4 0 2.84 Lt. Deposits. 141 4443 0 0.01 5 0 2.87 Lt. Deposits. 142 4473 0 0.01 3 0 2.86 Lt. Deposits. 143 4503 0 0.01 4 0 2.86 Lt. Deposits. 144 4533 0 0.01 3 0 2.86 Lt. Deposits. 145 4564 0 0.01 3 0 2.85 Lt. Deposits. ' Penetration Body Metal Loss Body Page 3 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf J -55 8RD EUE ABM Well: 2B-08 Body Wall: 0.254 in Field: Kuparuk River Unit I Upset Wall: 0.254 in Company: Conoco Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: April 7, 2011 Phillips I Joint Jt. Depth Peri. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (` wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 146 4595 0 0.02 6 0 2.86 Lt. Deposits. 147 4624 0 0.00 0 0 2.86 Lt. Deposits. 148 4653 0 0.02 9 0 2.86 Lt. Deposits. 149 4682 0 0.02 8 1 2.85 Lt. Deposits. 150 4714 0 0 0 0 2.85 Lt. Deposits. I 151 4745 0 0.04 1 4 2 2.85 Oval. Shallow Line of Pits. Lt. Deposits. 152 4777 0 0.04 16 1 2.85 Oval. Shallow Pitting. Lt. Deposits. INN 153 4808 0 0.03 11 1 2.85 Lt. Deposits. 154 4839 0 0.00 2 0 2.84 Lt. Deposits. 155 4871 0 0.03 10 I 2.84 Oval. Lt. Deposits. 156 4902 0 0.00 2 0 2.84 Lt. Deposits. 157 4934 0 0.02 9 1 2.84 Oval. Lt. Deposits. 158 4965 0 0.03 10 0 2.84 Oval. Lt. Deposits. 159 4997 0 0 0 0 2.84 Lt. Deposits. 160 5028 0 0.02 9 0 2.84 Oval. Lt. Deposits. 161 5060 0 0.03 1 1 0 2.84 Oval. Lt. Deposits. 162 5091 0 0.00 0 0 2.84 Lt. Deposits. 163 5122 0 0.03 10 0 2.84 Oval. Lt. Deposits. 164 5154 0 0.03 13 1 2.84 Oval. Shallow Pitting. Lt. Deposits. 165 5185 0 0.02 8 0 2.84 Lt. Deposits. 166 5216 0 0.01 4 0 2.84 Lt. Deposits. 167 5248 0 0.02 8 1 2.85 Lt. Deposits. 1 168 5279 0 0.04 14 1 2.84 Oval. Shallow Line of Pits. Lt. Deposits. 169 5311 0 0.04 14 0 2.85 Oval. Shallow Pitting. Lt. Deposits. 170 5342 0 0.01 3 0 2.85 Lt. Deposits. 171 5373 0 0.04 1 5 1 2.84 Oval. Shallow Line of Pits. Lt. Deposits. I 172 5405 0 0.03 10 1 2.84 Lt. Deposits. 173 5436 0 0.03 11 0 2.84 Lt. Deposits. 174 5468 0 0 0 0 2.84 Lt. Deposits. 175 5499 0 0.02 9 0 2.85 Oval. Lt. Deposits. I 176 5531 0 0.01 5 0 2.84 Lt. Deposits. 177 5561 0 0.02 8 1 2.84 Lt. Deposits. 178 5593 0 0.02 6 0 2.84 Lt. Deposits. 179 5624 0 0.04 14 0 2.84 Oval. Shallow Line of Pits. Lt. Deposits. 180 5655 U 0.02 8 1 2.85 Oval. Lt. Deposits. I 181 5687 0 0.04 1 8 2 2.85 Oval. Shallow Line of Pits. Lt. Deposits. 182 5718 0 0.04 14 1 2.85 Oval. Shallow Pitting. Lt. Deposits. 183 5749 0 0.01 3 0 2.86 Lt. Deposits. 184 5780 0 0.03 11 0 2.84 Lt. Deposits. I 185 5812 0 0.00 0 0 2.85 Lt. Deposits. 186 5843 0 0.04 16 1 2.85 Oval. Shallow Line of Pits. Lt. Deposits. 187 5874 0 0.04 15 0 2.85 Oval. Shallow Pitting. Lt. Deposits. 188 5906 0 0.01 4 0 2.85 Lt. Deposits. I 189 5937 0 0.02 6 0 2.84 Lt. Deposits. 190 5969 0 0.02 9 0 2.84 Lt. Deposits. 191 5999 0 0.05 19 2 2.84 Oval. Shallow Line of Pits. Lt. Deposits. 192 6030 0 0.04 14 1 2.85 Oval. Shallow Line of Pits. Lt. Deposits. 193 6061 0 0.04 1 4 1 2.84 Oval. Shallow Line of Pits. Lt. Deposits. I 194 6092 0 0.02 8 0 2.84 Oval. Lt. Deposits. 195 6124 0 0.03 1 1 0 2.87 Oval. Lt. Deposits. ration Body I Metal Loss Body Page 4 Penet 1 1 1 • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf J -55 8RD EUE ABM Well: 213-08 Body Wall: 0.254 in Field: Kuparuk River Unit Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.992 in Country: USA Survey Date: April 7, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 196 6155 0 0.04 16 1 2.85 Oval. Shallow Line of Pits. Lt. Deposits. 197 6187 (1 0 0 0 2.85 Lt. Deposits. 198 6218 O 0.04 14 2 2.85 Shallow Pitting. Lt. Deposits. 199 6250 1) 0.01 5 0 2.85 Lt. Deposits. 200 6281 0 0.00 2 0 2.85 Lt. Deposits. 1 201 6312 0 0.02 6 0 2.84 Lt. Deposits. 202 6344 0 0 0 0 2.83 Lt. Deposits. 203 6375 () 0.04 18 1 2.84 Oval. Shallow Line of Pits. Lt. Deposits. 204 6407 0 0 0 0 2.84 Lt. Deposits. I 205 6438 0 0.04 14 1 2.84 Oval. Shallow Line of Pits. Lt. Deposits. 206 6470 0 0.01 5 0 2.85 Lt. Deposits. B 207 6501 () 0.05 20 2 2.83 Oval. Line of Pits. Lt. Deposits. 208 6532 0 0.01 4 0 2.84 Lt. Deposits. I 209 6564 0 0.03 13 0 2.84 Oval. Shallow Pitting. Lt. Deposits. 210 6595 0 0.02 9 0 2.84 Lt. Deposits. 211 6626 0 0.04 16 1 2.85 Oval. Shallow Line of Pits. Lt. Deposits. 212 6657 0 0.05 19 3 2.84 Oval. Shallow Line of Pits. Lt. Deposits. • 213 6688 0 0.03 11 1 2.84 Oval. Lt. Deposits. I 214 6719 0 0.01 4 0 2.86 Lt. Deposits. 215 6750 O 0.04 14 1 2.84 Oval. Shallow Line of Pits. Lt. Deposits. 216 6781 0 0.03 10 0 2.85 Oval. Lt. Deposits. 217 6812 0 0.03 13 0 2.85 Oval. Shallow Pitting. Lt. Deposits. I 217 6844 218.1 6875 0 0.03 10 0 2.86 Lt. Deposits. 0 0 0 0 2.83 GLM 1 (Latch @ 1:00) 219 6882 0 0.02 8 0 2.84 Lt. Deposits. 219.1 6913 0 0 0 0 2.86 Pup Lt. Deposits. I 219.2 6922 0 0 0 0 2.86 PBR 219.3 6934 0 0 0 0 2.85 Packer 220 6942 0.09 0.07 30 7 2.86 _ Oval. Isolated Pitting. Lt. Deposits. 220.1 6974 0 0 0 0 2.82 GLM 2 (Latch @ 7:00) 1 221 6980 0 0.10 38 10 2.86 Oval. Isolated Pitting. Lt. Deposits. 222 7011 0.04 0.04 15 2 2.84 Oval. Shallow Pitting. Lt. Deposits. 222.1 7043 0 0 0 0 2.83 GLM 3 (Latch @ 4:00) 223 7050 0 0.05 20 5 , 2.84 Oval. Isolated Pitting. Lt. Deposits. 224 7081 0 0.00 0 0 2.85 Lt. Deposits. I 225 7112 0.04 0.03 10 1 _2.87 Lt. Deposits. 225.1 7142 0.11 0.11 43 11 2.86 Pup Oval. Line Corrosion. Lt. Deposits. 225.2 7144 0 0 0 0 2.82 GLM 4 (Latch @ 5:00) 225.3 7151 0.03 0.06 25 6 2.88 Pup Oval. Line of Pits. Lt. Deposits. I 225.4 7156 0 0.01 4 0 2.87 Pup Lt. Deposits. 225.5 7162 0 0 0 0 2.95 Baker 'FB 1' Packer 225.6 7164 0 0 0 0 2.87 Pup Lt. Deposits. 225.7 7172 0 0 0 0 2.75 D Nipple NO GO I 225.8 7174 0.06 0.06 25 5 2.87 Pup Line Corrosion. Lt. Deposits. 225.9 7182 0 0 0 0 2.88 Shear Out Sub ' Penetration Body Metal Loss Body 1 1 Page 5 i 1 1 • • 1 PDS Report Cross Sections I Well: 2B-08 Survey Date: April 7, 2011 Field: Kuparuk River Unit Tool Type: UW MFC 24 No. 1000429 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 1 Tubing: 3.5 ins 9.3 ppf J -55 8RD EUE ABM Analyst: M. Lawrence 1 1 Cross Section for Joint 225.1 at depth 7143.420 ft Tool speed = 43 Nominal ID = 2.992 I Nominal = 3.5 _ Remaining g w wall arr ea = N/A 111111 Tool deviation = 30° 1 /` 1 1 1 1 1 , 1 Finger = 22 Penetration = 0.110 ins Line Corrosion 0.11 ins = 43% WaII Penetration HIGH SIDE = UP 1 1 1 1 1 1 • • 1 PDS Report Cross Sections I Well: 213-08 Survey Date: April 7, 2011 Field: Kuparuk River Unit Tool Type: UW MFC 24 No. 1000429 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 1 Tubing: 3.5 ins 9.3 ppf J -55 8RD EUE ABM Analyst: M. Lawrence 1 1 Cross Section for Joint 221 at depth 6982.590 ft Tool speed = 43 Nominal ID = 2.992 I Nominal OD = 3.5 Remaining wall area = N/A ` Tool deviation = 30° ( 1 / \ 1 .7 1 \ . 1 -'--- 1 Finger = 2 Penetration = 0.097 ins Oval with Isolated Pitting 0.10 ins = 38% Wall Penetration HIGH SIDE = UP 1 1 1 1 I , ..' a KUP 2B -08 ConocoPhillips g Well Attributes Field Name walmcus lnd(") gle& TD tm ) Al.-( In: cnoccehllepr 500292107900 KUPARUK RIVER UNIT INJ 39.60 3,700.00 7,500.0 Comment H29 (ppm) Date Amotatlon End Date KB (ft) Rig Release Date • We9conrw. - 28-08 c 3/23/2011 8:3848AM SSSV: LOCKED OUT Last WO: 35.99 2/28/1984 Schematic Amotatlon Depth (MB) End Date Annotation Last Mod... End Date Last Tag: SLM 7,270.0 3/22/2011 Rev Reason: TAG, EST. 16' RATHOLE Imosbor 3/23/2011 Casing Strings Casing Description String 0... String ID ... Top (MB) Set Depth (f... Set Depth (7VD) ... String Wt... String ... String Top Thrd CONDUCTOR (QC) 16 15.062 37.0 117.0 117.0 65.50 H-40 I t ' ' hall Description Stu String 'String 0... Sng ID ... Top (19 h (6) Set Depth ... Set Depth (TVD)... String Wt... Stu 'turd String ... String Top P SURFACE (QC) 95/8 8.765 37.0 3,030.0 2,726.3 36.00 J BTC Casing Description String 0... String ID ... Top (MB) Set Depth (f... Set Depth (1VD) ... String Wt... String ... String Top turd PRODUCTION (QC) 7 6.151 35.5 7,500.0 6,303.7 26.00 J-55 BTC Tubing Strings Tubing Description String 0... String ID ... Top (565) Set Depth 8... Set Depth (TVD) ... String Wt... String ... String Top Thnl I TUBING 31/2 2.992 0.0 7,201.0 6,044.0 9.30 J-55 8RD EUE ABM CONDUCTOR Other In Hole reline retrievable plugs, valves, pumps, fish, etc.) (0C). 37 -117 Top Depth MD) Top and Top (RKB) (MB r) Description Comment Rtrr Date ID (in) 1,948.0 1,869.3 36.08 SAFETY VLV Baker'FVL' (LOCKED OUT 3.26.1990) 11/9/1992 2.810 ' SAFETY AN, 6,891.0 5,780.5 33.10 GAS LIFT MMW /l/ FMHO DMYBK// /Comment: STA 1 6,937.0 5,819.3 32.59 PBR Baker 10' 7/25/1984 2.867 7/13/1984 3.000 6,951.0 5,831.1 32.44 PACKER Baker'FHL' 7/13/1984 1000 6,990.0 5,864.0 32.01 INJECTION MMH/FMHO /1 /DMYBK/ / /Comment: STA 2 8/14/1992 2.867 7,060.0 5,923.6 31.86 INJECTION MMH/FMHO/1 /DMY /BK/ // Comment STA 3 11/9/1992 2.867 7,162.0 6,010.6 30.94 INJECTION MMWFMHO /1 /HFCV /BEK// /Comment: Broken Latch 5/27/2005 2.867 J (valve, no go, wable ring & spring in hole) STA 4 (OCS3R3,030 7,175.0 6,021.7 30.83 PACKER Baker'FB -1' 7/13/1984 4.000 OASLFT. 7,191.0 6,035.5 30.68 NIPPLE Camco'13 Nipple NO GO 7/13/1984 2.750 8891 7,200.0 6,043.2 30.60 SOS Baker 7/13/1984 2.992 I 7,201.0 6,044.0 30.10 TTL ELMD @ J182' PER SWS !PROF 6!11/2007 7/13/1984 2.992 7,498.0 6,302.0 29.50 FISH 1" DMY Empty Pocket; Fell to Rathole from GLV @6990' 11/7/1985 11/7/85 PBR, 8,937 ■ Perforations & Slots I - Dena PACKER, 8,951 1 Top (180) Btm (TVD) Top (RKB) Blm OMB) puce) (665) Zone Shot Date (M.- Type Comment 7,100.0 7,135.0 5,957.5 5,987.5 C-4, 26-08 7/14/1984 12.0 APERF 120 deg. phasing; SOS 51/2" Csg Gun 7,216.0 7,222.0 6,057.0 6,062.1 A-5, 26-08 7/25/1984 4.0 APERF 90 deg. phasing; 21/8" Tornado Link Jet IN.ECTYJN, 7,233.0 7,256.0 6,071.6 6,091.5 A-4, 28-08 624/1984 4.0 IPERF 2 1/8" 'GO' Link Jet 6 990 7,277.0 7,2980 6,109.7 6,127.9 A -3, 28-08 624/1984 4.0 IPERF 21/8 "'GO' Link Jet Notes: General & Safety End Date Annotation ' 4/29/1999 NOTE: Scale obstruction found @ 802" WLM I INJECTION 7 aeo 12/4/2009 NOTE: SEAL WELD ON BOTTOM OF STARTER HEAD (NO PATCH) NOTE: Gas Lit #4- Broken Latch, warble ring &spring in hop NOTE: VIEW SCHEMATIC w /Alaska.Schematic9.0 111 APERF 00.7135 IN.k CTION. 7 16 II 1 PACOS& 7 75 W k .4. F ` . i NIPPLE. 7191 * I SOS. 7200 • II TTL. 7201 '! Mandrel Details Top Depth Top Port • (1VD) Ind Op Valve Latch Sire TRO RUt Sm Top (19(8) (DKB) P) Make maw PM Sery Type TYPe fn) (Psi) Run Date com... 7,2122 1 6,891.1 MMH FMHO 1 GAS LIFT DMV BK 0.000 0.0 7/25/1984 IPERF, 2 6,989.8 MMH FMHO 1 INJ DMY BK 0.000 0.0 8/14/1992 7,233 - 7258 3 7,059.6 MMH FMHO 1 INJ DMY BK 0.000 0.011/10/1992 1 4 7,161.6 MMH FMHO 1 INJ HFCV BEK 0.000 0.0 5/272005 PERT, T,277.7398 1 I FISH, 7,498 PRODUCTION (OC), 35-7.500 ' TO. 77.500 1 I DING / TUBING / LINER DET I, k"/C "28 -' >w-/ DRILL SITE 28. I ARCO Alaska, Inc. 0 DATE 7- /3-84 Subsidiary of AtianticRichfieldcompany ALL KEAstatemanshare ;fir Page I of / pages •".7 ?`Olt$ I #ITEMS COMPLETE DISCRIPTION OF EQUIPMENT RUN LENGTH DEPTH �ie8 To 7 stbx. ibyon/ 9) 33.57 0.00 t r ay aiJ/2 Y°r,/Ise y/3)i��8' ree /sni 3 3/r fp.ir 44 33. I / JT 3 9.3 55 B�.UE ABNJ - 7 - 49,046 3/.58 38.31 [ v v ,� •-- .-- a- Pup J7 ~ S)3W . &,r 6..o5' 6989 59 Jrs - -- ~ ' Tve%vG /36 3.90 7554 A-- t✓ i'- , r R"° Jr S. /0 /939.84 I .3k" 134i5e Fie S.S5V •y/ 7`L0 2.81 Z: D. /3.59 /9,L7.9/ 312." 9 3 Js, 8eD£uz A5i , .1-7- 1.09 /96/.53 /58 irs ie s--- ..� a Weil./6 492/.49 /69.6 I 601 AtsfiEs FF I/o z ry/ ;/64 "auFrce eke ✓cvieK z carr,r 4.65 68`91.11 I J 3c 9.3 Js5 8 . A811 Ts„& 31.57 6897.76 I 4.- Rip Jr g. o9 6929.33 ,Bw,r�i¢ /O' P6/ (f is 8 e? t 3.0a I.D. / 3.69 6937.4Z -z 8Rre"2 F/IL P*R 3.00 I.D. 7.00 695/.// I / Jr 3h" 9 3 ✓s5 f A&7 r 3/46 6958. // 61.11 '3 Ames ,F,I -110 ' 4 / / " ter 4 ati2 LATCH 645 4919 .77 I 2 Js 3%.` t 99.3* .155 e 63.21 699 6 . 6U4 nudges FM -No 4I .)toimy #sC -2 (Arca 6.65 759.63 .1 3/t" 9.3* J5s B QO gue. A 1Tie 46 31.6o '7066.28 i , 3u+sTJT 3Yz q.3 Jss s tie. A$M Bo% X FL S pf+�l ms 45' OF 31.01 x iI '" .- i. Ft S m' } oe 2146S �c X S �, t',N 30. a 7122.g? I Mi "9.3* .155 8i atry Mtn POP JT 2.05 7/59.52 GLM 3 / 1 MOS PM-i/o wi / 1 a-Z £47 I 6.65 1/61.57 I 'VA" 9.1 Jss 8 Awl Pup ,rr 5.12 7/68.22 Bye Loc.Sue 6 45'sev. Assts SPAcira Derrloo Abut FB-t PtM /. S3 7/73.34 B &€ L FS-1 Pr-1Z ick1E.ImIESET € 7158' 2.5o 7/71./i I 8Arse *Boer Axre siod *f XO 4.95 7/7167 3/2" '.155 2 ' ABM P uPJT tot 1 2.6 93 ? 8 Z I clew° /4b -6o izt pAei 2. Ts ID /.45 '7190.7o 3y ="9 3 '` ✓55 ��. RIPJ J le 7192.15 +&Leen 3/i.' Some ear 518 Cul2.S I.D. me 10 Rs/ 0.1d 72GD.2 " I Rem ark s mFG2- S'/N /MAIO 8077014 OF 7ZIAING 7»!L. 7209.$0 421 227 Jrs ,00/4.0046 4 �&' ' • Z'• /S' Rips R 223 J73 •+ 6' Rip ' usi�o 33 smarms sari. �r�s I _ UP WT 7514 Zo *us, 9 Raed lb 6(. - 37.25 ', and +rr 50 x INNS / Reek r,6 t 22.75 I d.-E. moss ARCOSP1I8 R. Supervisor SUBURBAN MINIM. CO I • • DIF A[LASEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSIONT ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 John Peirce Wells Engineer _ ConocoPhillips Alaska, Inc. n/ P.O. Box 100360 4 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2B -08 Sundry Number: 311 -147 Dear Mr. Peirce: stAtiNED APR 2 9 2011 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. nor Chair DATED this day of April, 2011. Encl. • STATE OF ALASKA ar�4 ALASK. AND GAS CONSERVATION COMMISSIO• 4• • APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon r Rug for Redrill r Perforate New Pool n Repair w ell r Change Approved Program E Suspend r Rug Perforations r Perforate r" Pull Tubing r Time Extension Operational Shutdown r Re -enter Susp. Well r Stimulate r Alter casing r Other:Install Tubing Patch 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 184 - 026 • 3. Address: 6. API Number: Stratigraphic r Service • P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 21079 - 00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No 17 2B -08 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 25656 . Kuparuk River Field / Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7500 . 6304 . 7410' 6225' 7498' Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 117' 117' SURFACE 2993 9 -5/8" 3030' 2726' PRODUCTION 7465 7 7500' 6304' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7100' 7135', 7216 7222', 7236 7256', 7277' - 7298' 5958'- 5988', 6057'- 6062', 6072'- 6092', 6110' -6128' 3.5 J - 7201 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER 'FHL' MD= 6951 TVD= 5831 PACKER - BAKER 'FB -1' MD= 7175 TVD= 6022 SSSV - BAKER 'FVL' MD= 1948 TVD= 1869 12. Attachments: Description Summary of Proposal Fi 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Development ' Service 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: Y � . � 5/26/2011 Oil r Gas WDSPL r Suspended 4 16. Verbal Approval: Date: WINJ GINJ r WAG r Abandoned Commission Representative: GSTOR r SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Peirce @ 265 -6471 Printed Name John Peirce Title: Wells Engineer Signature .t Phone: 265 -6471 Date 4 /27/11 Commission Use Only Sundry Number:3\ "' `_4'7 Conditions of approval: Notify Commission so that a representative may witness - 11 IHR Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance APR 2 8 Other: 01i klaska Oil & Gas Cuts. Gammission Subsequent Form Required: /6 - 4 04.E 0.0f: /'ge ,fr APPROVED BY f1211(1 Approved by: • COMMISSIONER THE COMMISSION Date: 3 i i "` � � � S u bmit its uplicate REflrw A . 8 RIGINAL yze" y ,�> KU P 2B-08 , �oPhil ips I Well Attributes Max Angle & MD TD Alt:81 3 Inc Wellb APVUWI Field Name I Well Status Inc' (3 MD (H VMS) Act Btu KB) 500292101900 I K.IJPARUK RIVER UNIT INJ 39 60 I 3,700 00 7,500.0 IComment H ( 25 ppm) Date IAn t tion End Date KB - Card (ft) Rig Release Date Wa)C ;„-, - 4440/2611 8 & a:. Fm SSSV_ LOCKED iILIT lit � st WO: 3599 2!28/1984 Sd'em48k4/3 ual A notation Depth IHKB) Date Annotat Last Mod ... End Dat Last Tag: SLM /. 70 0 3/22/2011 Rev Reason: TAG EST. 16' RAT HOLE j Imosbor l 3/23/2011 i Casing Strings I Casing Description [String 0... String ID ... Top (HKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd I I CONDUCTOR (QC) 16 15.062 370 717,0 117.0 65.50 H-40 Casing Description String O... String ID ... Top (HKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd SURFACE (Cc) 95/8 8.765 37.0 3,030.0 2,726.3 36.00 J -55 ETC E Casing Description String 0... String ID... Top MKS) Set Depth (f... Set Depth (TVD)... String Wt... String... String Top Thrd PRODUCTION (CC) 7 6.151 35.5 7,500.0 6,303.7 26.00 J -55 BTC ; Tubing Strings Tubing Description String O.. String ID ... [Top (HKB) [Set Depth (f..l Set Depth (TVD) . String Wt... [String ... String Top Thrd TUBING 31/2 2.992 0.0 7,201.0 60440 I 9.30 J-55 8RD EUE ABM CONDUCTOR Other In Hole �reline retrievable plugs, valves, pumps, fish, etc.) (QC), 37 -117 Top Depth (TVD) Top Intl Top HK( B) (HKB) (°) Description Comment Run Date ID (in) 1,948.0 1,869.3 36.08 SAFETY VLV Baker'FVL' (LOCKED OUT 3.26.1990) 11/9/1992 2.810 SAFETY VLV, 1.916 6 5,780.5 33.10 GAS LIFT MMH /FMHO /1/DMY/BKl // Comment: STA 1 7/25/1984 2.867 _ -- 6,937.0 _ 5,819.3 32.59 PBR Baker 10' 7/13/1984 3.000 6,951.0 5,831.1 32.44 PACKER Baker'PHD 7/13/1984 3.000 6,990.0 5,864.0 32.01 INJECTION MMH /FMHO /1 /DMY/BK/ // Comment: STA 2 8/14/1992 2.867 Id 7,060.0 5,923.6 31.86 INJECTION MMH /FMHO /1 /DMY /BK/ // Comment: STA 3 11/9/1992 2.867 7,162.0 6,0106 30.94 INJECTION MMH /FMHO /1/HFCV /BEK/ /! Comment Broken Latch 5/27/2005 2.867 • (valve, no go, wable ring & spring in hole) STA 4 SURFACE (QC), 97 - 3,930 7,175.0 6,0213 30.83 PACKER Baker'FB -7' 7/13/1984 4.000 GAS LIFT, _ -.,- _;,_ 7,191.0 6,035.5 30.68 NIPPLE Cameo 'D' Nipple NO GO 7/13/1984 2.750 0391 ._• ___ - _. _ __ _ ___.._ _ - __. 7,200.0 6,043,2 30.60 SOS Baker 7/13/1984 2.992 ttt''' _._ -. — - ii 7,201.0 6,044.0 30.10 - TT - L - ELMD @ 7182' PER SWS [PROF 6/112007 7/13/1984 2.992 7,498.0 6,302.0 29.50 FISH 1" DMY Empty Pocket; Fell to Rathole from GLV @6990' 11/7/1985 11/7/85 Slots �. _. t" si ° •- .. .A " ".. 9t PeR,ss37 — Perforations & _ Shot TOp(TVD) Ste(TVD) Dens PACKER, 6,961 - To. MKS Btm Tics) (MB) MKS) Zone Date (oh... Type Comment 7,100.0 7,135.0 5,957.5 5,987.5 C-4, 28-08 7/14/1984 12.0 APERF 120 deg. phasing; SOS 512" Csg Gun 7,216.0 7,222.0 6,057.0 6,062.1 A -5, 28-08 725/1984 4.0 APERF 90 deg. phasing; 2 1/8" Tornado Link Jet INJECTOR, 1 ' 7,233.0 7,256.0 6,071.6 6,091.5 A -4, 28-08 6/24/1984 4.0 IPERF 2 1/8" 'GO' Link Jet 6,990 1 7,277 -0 7,298.0 6,109.7 6,127.9 A -3, 2B -08 6/24/1984 4.0 IPERF 21/8 "'GO' Link Jet Notes: General & Safety '' End Date Annotation ,y - , 4/29/1999 NO E. Scale obstruction found @ 802" WLM INJECTION, - -- - ___ - ` - - - 7,060 - - -- * �y 12-42009 NOTE: SEAL WELD ON BOTTOM OF STARTER HEAD (NO PATCH) NOTE: Gas Lift #4- Broken Latch, warble ring &spring in hole NOTE VIEW SCHEMATIC w /Alaska.Schematic9.0 APERF, 7,1007,135 v N f 4-TGd GL nit e- 7(6 Z ' p1b INJECTION,) tM. 7.162 - i �IB1 -.. -.' PACKER, 7,175 Y{ NIPPLE, 7,191 - ' — ; SOS, 7,200 4�c TI 7,201 Mandrel Details Top Doplh Top Port (TM Inc1 ' OD Valve Latch Size TRO Run APERF,__ . stn Top(HKB) (HKB) (°) Make Model _ (in) _ Sew TYpe Type (in) (_psi) Run Date Can... 7,216 - 7,222 1 6,891.1 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 725/1984 989.8 ..__. _. MMH 2 6,9 MM FMHO 1 INJ DMY BK 0.000 0.0 8/14/1992 IPERF - -'- - - 7,23y7,25s - - 3 7,059.6 MMH FMHO 1 INJ DMY BK 0.000 0.011/10/1992 4 7,161.6 MMH FMHO 1 INJ HFCV BEK 0.000 0.0 5272005 J 1 . — 7,2n -7.2sa FISH, 7,496 PRODUCTION _ (QC), 35 -7,500 \___ TD, 7,500 • • Proposed 2B -08 Injector Tubing Patch Installation 2B -08 was completed in 1984 as a C and A sand selective injector with 3.5 ", J -55 tubing. The objective of this proposed work procedure is to convert 2B -08 to 'A sand only' PWI. A 1/23/10 IPROF shows all C sand PWI enters an injection mandrel at 7162' RKB. The C sand takes 56 - 84% of PWI depending on injection rate. This GLM has remnant broken CV parts left in the pocket, thus DV installation is not possible in the pocket to shut off C sand PWI. Slickline advisories also predict that fishing the CV parts would likely be very difficult. Following a successful dummy patch drift, a tubing patch will be set across the leaky , mandrel at 7162' RKB to convert 2B -08 to 'A sand only' PWI. Slickline: 1. RIH with a dummy patch drift assembly having similar dimensions to run #2 of the planned tubing patch (below). The Caliper of 4/7/11 shows the tubing to be slightly buckled, but no significant minimum ID restrictions were detected in the tubing. E -line: 2. RIH with a 2.74" run OD Packer and set the packer so the element is set in the middle of a 5' pup joint at 7171' RKB. This set location leaves the packer 2 - 3' below the bottom of the leaky mandrel to be patched. Slickline: 3. RIH with run #2 of the tubing patch assembly consisting from top to bottom of a 2.74" run OD Packer, 20' x 2.375" spacer pipe, and a 2.74" run OD Snap- Latch. Latch into the lower packer at 7171' RKB and set the top packer at 7151' RKB 8' above the base of a full joint to complete the patch across the leaky mandrel. Set a test plug in the upper packer and PT tubing to 2500 psi to verify integrity of the packer and the tubing. Pull test plug. RD. Return 2B -08 to `A sand only' PWI and obtain valid injection rate. Conaco~Pl~illips a~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Apri117, 2010 Mr. Dan Seamount Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 .~, i i ~ v ~m Dear Mr. Dan Seamount: LJ -~ APR 2 `~ 2010 +~s~c~ iii ~ has Oons. ~om~tssior, Anchorage O~ S'~ o~ ~~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRLn. Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped January 16, March 21, 2010. The corrosion inhibitorlsealant was pumped Apri115, 16 and 17, 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Projects Supervisor • ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field 4/17/2010 2B. 2E. 2G. 2H. 2K. 2M. 2V. 2W. 2X. 2Z Bi 3S PAD's Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2B-05 50029210670000 1840040 24" n/a 24" n/a 4.2 4/16/2010 2B-08 50029210790000 1&40260 21" 3.30 7" 1/16/2010 2.5 4/162010 2B-16 50029211460000 1841140 92" 0.65 3/21/2010 2.5 4/16/2010 2E-10 50029212460000 1842300 SF Na n/a Na 5.9 4/16/2010 2E-17 50029224190000 1931740 8'9" 1.50 19" 1/16/2010 3.4 4/16/2010 2G-13 50029211600000 1841290 SF n/a 22" Na 3.4 4/16/2010 2H-07 50103200450000 1851700 SF n/a 17" Na 2.1 4/15/2010 2H-09 50103200500000 1852590 SF Na 17" n/a 2.5 4/15/2010 2H-15 50103200340000 1840860 SF n/a 17" n/a 2.5 4/15/2010 2H-16 50103200350000 1840870 SF n/a 17" n/a 2.5 4/15/2010 2K-19 50103201180000 1891090 53" 0.50 9" 1/16/2010 2.1 4/15/2010 2M-07 .50103201780000 1920800 SF n/a 17" Na 3.4 4/15/2010 2M-08 50103201840000 1921010 SF n/a 17" Na 2.1 4/15/2010 2M-20 50103201690000 1920480 SF n/a 17" Na 2.5 4/15/2010 2M-22 50103201700000 1920490 SF n/a 17" Na 2.5 4/15/2010 2M-26 50103201740000 1920700 SF Na 18" Na 2.1 4/15/2010 2V-06 50029210540000 1831790 SF n/a 19" n/a 7.6 4/16/2010 2V-10 50029213100000 1850480 SF n/a 19" Na 2.5 4/16/2010 2V-16 50029212960000 1850330 SF Na 21" n/a 5.1 4/16/2010 2W-03 50029212740000 1850110 SF Na 37" Na 4.2 4/16/2010 2X-11 50029211880000 1841640 SF n/a 1T' Na 6 4/17/2010 2Z-11 50029213790000 1851380 SF Na 19" Na 2.5 4!15/2010 2Z-12A 50029213800100 1951480 SF n/a 19" Na 2.5 4!15/2010 2Z-13A 50029213600100 2061700 SF n/a 22" n/a 4.25 4/15/2010 2Z-19 50029218820000 1881300 SF n/a 16" n/a 2.1 4/15/2010 3S-09 50103204320000 2022050 SF n/a 45" Na 23 4/17/2010 • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Injection Profile: 2B-08 Run Date: 1/23/2010 February 18, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2B-08 Digital Data in LAS format, Digital Log Image file, Interpretation Report 50-029-21079-00 Injection Profile Log ~ ~ ~ ,~ , 50-029-21079-00 ~~~ f~~'r, i~ A ~ ~ `~ ~ ~ ` 1 CD Rom 1 Color Log PLEASE ACKNOWLEDGE RECEIl'T BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barreto~hal lib"urton.com Date: ~_ U-t G ! ~3~-v~ ~ ~ ~LCU~ ~~I ;~ Signed: ~ ~~ \~ ; ~' ConocoPhillips P.O. BOX 100360 Alaska REC EIVE[ ANCHORAGE, ALASKA 99510 -0360 D EC 0 8 'N 09 Alaska Gil & Gas Cons. Commissi011 December 6, 2009 Anchorage Guy Schwartz Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 %%A DE f, 1 g 2009 Anchorage, AK 99501 Dear Mr. Schwartz: Enclosed please find the 10-404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. well 2B -08 PTD184 -026 sundry 309 -376 surface casing repair. Please call MJ Loveland or myself at 659 -7043 if you have any questions. Sincerely, Perry K ConocoPhillips Well Integrity Projects Supervisor I Enclosures • RECEIVED STATE OF ALASKA DEC 0 8 2009 ALASKA OIL AND GAS CONSERVATION COMMISSION 418gk6 Oil & Gas Cons. Cuff ftiSsion REPORT OF SUNDRY WELL OPERATIONS A nrhnrags 1. Operations Performed: Abandon ❑ Repair Well 0 Plug Perforations ❑ Stimulate ❑ Other ❑ Repair SC Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator Name: 4. Current Well Status: Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ❑ Exploratory ❑ 184 - 026 3. Address: Stratigraphic ❑ Service Q API Number: P. O. Box 100360, Anchorag Alaska 99510 50 029 - 21079 - 00 KB Elevation (ft): Well Name and Number: RKB 127' 1 213-08 Property Designation: Field /Pool(s): K aruk River Field / Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 7500' feet true vertical 6304' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 117' 16" 117' 117' NA NA SURFACE 2903' 9 -5/8" 3030' 2726' 3520' 2020 PRODUCTION 7373' 7" 7500' 6304' 4980' 4320 Perforation depth: Measured depth: true vertical depth: Tubing (size, grade, and measured depth) 3 -1/2" , J -55, 7201' MD. Packers & SSSV (type & measured depth) pkr— BAKER 'FHL' ; BAKER 'FB -1' pkr= 6951'; 7175' SSSV = SSSV SSSV= 1948' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbi Casino Pressure I Tubing Pressure Prior to well operation N/A N/A N/A N/A N/A Subsequent to operation N/A N/A N/A E l N/A N/A 14. Attachments Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ❑ Development ❑ Service Daily Report of Well Operations _X 16. Well Status after proposed work: WK 1 a' • C❑ GasO WA GINJ __ WINJ ❑ WDSPL ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 309 -376 Contact P LKlei r2a 'n d Prin d Name P Title Problem Well Supervisor Signature Phone 659 -7043 659 -7043 Date 12/6/2009 �a ic%S Form 10-404 Revised 0412004 /fe— �Z • %• 0 Submit Original Only 2B -08 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 11124/09 Topped off conductor with 3.0 bbls of 15.8 # type 1 /II Portland cement. Fill the void of the conductor to eliminate the volitile organic compounds in the conductor to cut windows. 11/28/09 Rigged up nitrogen purge, cut and removed tanko top and conductor. Cleaned surface casing for cooper heat and weld area. Leak appears at bottom threads of fluted mandrel. Conductor length to be replaced is 29.5" X 16 ". ° 12/04/09 Cooper Heat preheated starter head. Welded surface casing per mechanical engineer (seal weld) specs. Quality control did visual inspection. Wrapped weld with insulation blanket to , control heat loss. Kakivik performed inspection. 12/06/09 MIT OA (passed). Initial T /I /O = SI /100/0, pressured OA up to 1790 psi, with 2`.2 bbl of diesel. Start T /I /O = SIM 00/1790, 15 min T /I /O = SIM 00/1750, 30 min T /l /O = SIM 00/1740, 45 min T /I /O = SIM 00/1740, 60 min T /l /O = SIM 00/1740. Bled OA to 0 psi. Final T /l /O = SIM 00/0. 12107/091 Reinstall 29.5 of conductor. I Y I 1t ! A l l t �.i f t 1 f Y' f 3 Y �� t °: ' � 1 `l .�+ t y � �' ,,• �� ti 6 .. � 4; ,n 5" � 'Y��'- �' ' t A �, y�•�g f�1,r ^:,..) �. N �'; �+ -!C 2- d 7 : b �z a. Y I I I I� x i fill C r � e RECEIVED ConocoPhillips NOV 1 7 2009 P.O. sox 100360 Alaska Alaska Gil & Gas Cons. Commiss ANCHORAGE, ALASKA 99510 -0360 AnGhnisQR November 14, 2009 Mr. Guy Schwartz Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 # L. �� D E C 1 8 2009 Dear Mr. Schwartz: Enclosed please find the 10 -404 Report of Sundry well operations for ConocoPhillips Alaska, Inc. well 2B -08, PTD 184 -026 surface casing repair with Brinker Platelets. Please call Perry Klein or me at 659 -7043 if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor Enclosures i • RECEIVED STATE OF ALASKA NOV 1 7 2009 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIOA Oil & Gas Cons Commission 1. Operations Performed: Abandon ❑ Repair Well Q Plug Perforations ❑ Stimulate ❑ Other Q SC repairw/ Platele Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown❑ Perforate ❑ Re -enter kuspended Well ❑ 2. Operator Name: 4. Well Class Before Work: Permit to Drill Number: ConocoPhillips Alaska Inc. Development ❑ Exploratory ❑ 184 -026 / 309 -307 3. Address: Stratigraphic ❑ Service ❑✓ API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 21079 - 00 KB Elevation (ft): Well Name and Number: RKB 127' 26 -08 Property Designation: . Field /Pool(s): ADL 25656, ALK 2582 Kuparuk River Field / Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 7500' feet true vertical 6304' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 117' 16" 117 117' SURFACE 2903' 9 -5/8" 3030' 2726' PRODUCTION 7373' 7" 7500' 6304'. Perforation depth: Measured depth: 7100 -7135, 7216 -7222, 7233 -7256, 7277 -7298 true vertical depth: 5958 -5987, 6057 -6062, 6072 -6091, 6109 -6127 Tubing (size, grade, and measured depth) 3.5 ", J -55, 7201' MD. Packers & SSSV (type & measured depth) Baker FB - 1; Baker FHL 7175', 6951' 5. SSSV - Locked out 1948' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubina Pressure Prior to well operation NC -- Subsequent to operation NC 14. Attachments NWell Class after work: Copies of Logs and Surveys run _ Exploratory ❑ Development ❑ Service ❑� Daily Report of Well Operations _X Well Status after work: Q!1❑ Gas❑ WAGE] GINJ❑ WINJ ❑ WDSPL❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 309 -307 Contact MJ Loveland/ Perry Klein 659 -7043 Printed Name MJ Loveland Title Well Integrity Project Supervisor � Phone: 659 -7043 Date V d ~ Signature n/ P red b Sharo Allsu D ke 263 -4612 Few s`%tA N OV 1 8 2009 Form 10 -404 Revised 0412006 Submit Original Only 2B -08 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 10/26/2009 SC Leak Repair - (Brinker Platelet), Initial T /1 /0= 2020/1310/15. Rigged up triplex to injection manifold and established several LLR but hole was small enough that we started pumping gel diesel. Have a visual of the leak area looking in the four inch hole in the conductor. Start to inject micro platelets first batch @ 0 psi; 2nd batch micro platelets @ 300 psi, 3rd batch micro platelets @ 600 psi; 4th batch micro platelets @ 900 psi. Pumped approximately 1/2 bbls of gel diesel. Tried flow test but not holding with initial micro platelets. Diesel gel flowing out of SC hole. Shut in OA and mooiitor 1000 psi with wells group vac truck checking for teaks. We will return in the morning and continue test. Final T /1 /0= 2020/1310/1000. Invited John Crisp to witness. He waived due to other commitments 10/27/2009 Brinker Platelets SCLD /Repair- Successful; (continued from 10- 26 -09) Initial T /1 /0= 2190/1400/730; Pressured up OA to 1800psi. Bled to 1670psi. and added 1200 x 2mm cube, 150g x 1 mm - 2mm micro, 250q x 30 micro, 250g x 600 micro. Pressured up to 1800psi. 15min. reading 1725psi. 30min. reading 1715psi. 45min. reading 1690psi. 60min. reading 1690psi. Pumped approxmitely 1bbls. diesel and .5bbls. gel diesel. Bled OA 51Opsi. Final T /1 /0= 2190/135/730 (SC Leak point has been marked on the conductor.) 10/27/2009 Called and invited State inspector to witness MITOA tomorrow - No call back 10/28/2009 MITOA - Passed. Initial T/1/0=. OA FL AS. Pressured up OA to psi with 1/4 bbl of diesel gel. Start MITOA, T /1 /0= 2150/1350/580, 15 min T /I /O = 2150/1350/1000, 30 min T /1 /0= 2150/1350/1000. Bleed OA down to 340. Final T /1 /0= 2150/1350/340. Summary Successful SC repaired with Brinker Platelets - Permanent welding repair is still planned STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg @alaska.gov; phoebe.brooks @alaska.gov; tom.maunder @alaska.gov; doa .aogcc.prudhoe.bay @alaska.gov OPERATOR: ConocoPhillips Alaska Inc. FIELD / UNIT / PAD: Kuparuk / KRU / 2B -08 DATE: 10/27/09 OPERATOR REP: Phillips / Westlake AOGCC REP: State rep was notified with no response Shoe Depth Pretest Initial 15 Min. 30 Min. Well 26 -08 I Type Inj. I W TVD 2,726' Tubing 2,150 2,150 2,150 2,150 Interval O P.T.D. 1840260 I Type test I P I Test psi 1000 Casing 1,350 1,350 1,350 1,350 P/Fj P Notes: OA 580 10001 1000 1000 MITOA Test per Sundry # 309 -307 - Entered Shoe TVD in Packer slot. Weill Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA WeIll Type In'. I N I TVD I Tubing Interval P.T.D.1 I Type test I P I Test psi I Casing P/F Notes: OA Weill Type Inj, I TVD I Tubing Interval P.T.D.1 I Type testj Test psi I Casing 1 P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casin P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test O = Other (describe in notes) MIT Report Form BFL 11127/07 MIT KRU 2B -08 10- 27 -09.XIs ~ ~~ ~ ~ ~ `:: r ~ ' -` , ~ ~ , 1~ ~f, ~ ~l. ~; h } i L 1~. + ,. , ,, . _~ .. ~ , ~ a ~-f ~ - r_ ,._ ~ .. ~ ~J y _~,~ ~ ALASSA OIL A1~TD G~S CO1~T5ERQATIOI~T CODII-iISSIOI~T . SEAN PARNELL, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Perry Klein Well Integrity Projects Supervisor ConocoPhillips Alaska, Inc. PO Box 100360 ~~~~~~ ~ ~,~ ~ ~¢ ~~~~ Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk Oil Pool, 2B-08 Sundry Number: 309-376 Dear Mr. Klein: ~~ ~ ~- Q ~~ Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. ~ Chair DATED this ~ day of November, 2009 Encl. 3,~ ~ ~~~~~'~/'~~ 1,o~ ~ ~~,t ~Ov 7 STA E 1 ~009 ~ ~ ~ ~ ~ ? ~u~ , T ~~?~~ ,~~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~~$~~ ~~~ ~~~5 LOfI~~ ~~titltll[S~~pt~ APPLICATION FOR SUNDRY APPROVA~ Anchora~~ 20 AAC 25.280 1. Type of Request: Abandon ~ Suspend ^ Operational Shutdown ~ Perforate ^ Waiver ~ Other ~ Aftercasing ~ Repairwell ~' Plug Perforations ^ Stimulate ~ Time Extension ~ SC welded patch Change approved program ^ Pull Tubing ~ Perforate New Pool ^ Re-enter S uspended Well ~ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: CollocoPhillips Alaska, Inc. Development ^ Exploratory ^ 184-026 • 3. Add~ess: Stratigraphic ~ Service ~• 6. API Numbe~: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21079-00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line where 8. Weil Name and Number: ownership or landownership changes Spacing Exception Requires? Y@S NO ^d 2B-OS ~ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25656, ALK 2582 • RKB 127' ~ Kuparuk River Field / Kuparuk Oil Pool . 12• PRESENT WELL CONDITION SUMMARY ~ Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7500' ' 6304' ' Casing Length Size MD ND Burst Collapse CONDUCTOR 117 16" 117 ~ ~ ~ na na SURFACE 2g03' 9-5J8" 3030' 2726 3520 2020 PRODUCTION 7373' 7" 7500' 63Q4 4980 4320 Pertoration Depth MD (ft): Pertoration Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7100-7135, 7216-7222, 7233-7256, 7277-7298 5958-5987, 6057-6062, 6072-6091, 6109-6127 3.5~~ J-55 ~201' Packers and SSSV Type: Packers and SSSV MD (ft) Baker FB-1; "Baker FHL 7175', 6951' SSSV - Locked out 1948' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ~ Developmer~t ^ Service ~` 15. Estimated Date for 16. Well Status after proposed work: Commencing Operati~ November 10, 2009 Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: WAG Q' GINJ ~ WINJ ^ WDSPL ~ Commission Representative: 18. I hereby certify tha~ at~~feFegoing~s~t~e d ~ect to e best of my knowledge. Contact: Perry Klein /~MJ Loveland Printed N~ Pe ry K~~" Title: Well Integrity Project Supervisor _ Signature Phone 659-7043 Date 1 ommission Use Only Sundry Number: Condifions of approval: Notify Commission so that a representative may witness ~~ Plug Integrity ~ BOP Test ~ Mechanical Integrity Test ~ Location Clearance ^ Other: ` TN G Lt<~, `LoY~ ~c G cc..w c~.~ ~d ~ /~ L-CS~~= ~"i ~-~a-~- - 0 -/~o ~'i .~ k / .~ ~a r' R. S ~o CcLh n t~, 5 S b ~ u sequent Form RequfCed: 6 APPROVED BY / /~/~ ~ Approved by: C MMISSIONER THE COMMISSION Date: ~~ - - - - .,~ 4 ~ 1 1.,~ 0 1 V /-1 L.._ , ',~' / ./Z. p~ ~ rj ~~,~ j<~ :~ ~ "~ KUP 2B-08 ~OIIOCIJ~I ll~~lp 5 Well Attributes Max An le & MD TD ~85{t41. I/ lr;. Wellbon APINWI Fleltl Nam• Well Stetua Incl (°) MD (ftK8) Act Btm ~RN9) 500292107900 KUPARUK RIVER UNIT INJECTING 39.6D 3,700.00 7,500.0 Comm~nt M23 (DPm) Oab Mnotatlon Ena Dab K9-Grtl (ft) Rip R~leaa~ Dab SSSV: LOCKED OUT 0 1/102009 Last WO: 35.99 228/1984 Wen on :-ze-oa erv Swmeuc- tooa ~. AduY Annohtlon D~pt~ (ftNB) End Oats Annola[lon Last Motl By Entl Uate Last Tag: SLM 7,268.0 6I8/2009 Rev Reason: TAG SLM triplwj 6/9/2009 Caain Strln s smoa oo s~~i~e io se~ a.PCn s.t o.Pm ~rvo~ sm~a wc s~ri~q Cs~InpD~ecrlpbon (~N (ln) Top(ftNB) (RNB) (RKB) ~IDa/R) GraGe g~rlnpTOpThrtl CONDUCTOR 1 6 15.062 36.0 717.0 117.0 65.50 H-40 SURFACE 9 5/ 8 8.765 0.0 3,030.0 2.726.3 36.00 J-55 coNOUCroa, PRODUCTION 7 6.751 0.0 7,500.0 6.303.7 26.00 J-55 tn Tubin Strin s so-ina oo so-i~a io s.~ o.Pm s.~ o.v~n ~rvo~ s<<i~9 m s~ri~e TuEln O~scrlptlon (in) (In) Top (ftN8) (ftNB) (RKB) (Ibs/ft) Cratl~ Strlnp ToD Thrtl sncerrv~v, i s.a TUBING 31/ 2 2.992 0.0 7,201.0 6.044.0 9.30 J-55 BRDEUEABM Other In Hole All Jewe l : Tubin Run 8 Retrievable Fish etc. Top Dapl~ ~TVO) Top Incl SuN ~~ Top (flNB) (RKB) (•) Oescrl0tlon Comment Run Dah 10 (In) 1,948 1,869.3 36.08 S AFETY VLV Baker'FVL' (LOCKED OUT 326.1990) 11/9/1992 2.810 8,891 5,780.5 33.10 G AS UFT MMH/FMHO/1/OMY/BK/// Comment STA 1 725I1984 2.867 cns uFr, 8 891 8,937 5,819.3 32.59 P 0R Bakar 10' 7/13/1984 3.000 . 6,951 5,831.1 32.44 P ACKER Baker'FHL' 7/13/1984 3.000 6,990 5,864.0 32.01 IN JECTION MMH/FMHOIt/DMY/8K//IComment:STA2 811417992 2.867 7,060 5,923.6 31.86IN JECTION MMH/FMHO/1/DMY/BK//IComment:STA3 11/9I1992 2.867 7,182 8,010.6 30.941N JECTION MMH/FMHO/iMFCV/BEK///Commenl: 8mkenLetch 527R005 2.867 PBR, 8.931 (valve, no go, wable nng 8 spring in hole) STA 4 7,175 6,027.7 30.83 P ACKER Baker'F8-1' 7/73I1984 4.000 7,191 6,035.5 30.68 N IPPLE Camco'D'Nipple NO GO 7/13Ii984 2.750 PACKER, 8 951 7.200 6,0432 30.60 S OS Baker 7/13I1984 2.992 . 7,201 6,044.0 30.10 T Tl ELMD ~ 7182' PER SWS IPftOF 6A 120W 7/73/1984 2.992 7,498 6,302A 29.50 FI SH 1" DMV Empty Pocket; Fell lo Rathole from GLV Q6990' 11/7/1985 11(//85 ~wecnoN. PeAora tions 8 Slots 8 990 Shot To01~VD) Btm~TVD) Dsna Top (ftKB) B[m (RKB) (ftlcB) (RKB) Zp~~ psb (~~~~~ Typ~ Lommsnt 7,100 7,135 5.957.5 5,987.5 CA, 28-08 711411984 12.0 APERF 120 deg. phasing; SOS 5 12" Csg Gun INJECTION, ]~2~6 7,222 6,057.0 8,062.1 A-5, 28-08 725I7984 4.0 APERF 90 deg. p~esing; 2 tI8' TorneAo Link ~ 060 Jet 7,233 7,256 6,071.8 6,091.5 A-4,28-OB 624I7984 4.0 IPERF 21/8"GO'LinkJet 7,277 7,298 6,1D97 6,127.9 A-3,28-OB 624I7984 4.O IPERF 21/8"GO'LinkJet ~ERF. Notes: General 6 Safe 1.100~1.135 EnC Deh n~~odno~ 4/29/1999 NOTE: Scale oDstruction founA ~ 802' WLM INJECTION. 1.161 PACNEft. ),115 NIPPLE. 1.191 503, ),700 ~ rri, zzai APERF. /.218-].222 IPERF, l 233~I,Y58 IPERF, 7 Y]1-],298 FISN. 7 698 PRDOUCTION, 1.500 ro, i soa ~ ~ ; ~`~i`V~~ ~~ ~ ConocoPhillips Alaska, Inc. Kuparuk We112B-08 (PTD 184-026) SUNDRY NOTICE 10-403 APPROVAL REQUEST 11-06-09 ~OV 1 0 2QQ9 ~~iasl~~ ~i~ ~ ~as ~ans. ~ammissi~n Ancharag~ This application for Sundry approval for Kuparuk well 2B-08 is for the repair of a surface casing lea.k. The well is a WAG injector and was drilled in Feb. 1984 and completed in April 1984. In 1985 the well was converted to a water flood injector. On 04/11/08 a surface casing leak was confirmed and reported to the AOGCC while preparing the well for cement top out and sealant. Diagnostics confirmed a leak in the surface casing approximately 19" feet below the outer annulus valve. With approval, repair of the surface casing will require the following general steps: 1. Shut-in and secure well. Set positive pressure plug and fluid pack the IA as needed to remove all gas. Freeze protect the T and IA. Perform mechanical integrity test and draw down test on tubing plug to verify barrier. 2. Excavate wellhead location. 3. Install nitrogen purge equipment. 4. Cut away the conductor casing and remove cement around surface casing leak for inspection. 5. Notify AOGCC Field Inspector of repair operation so they may witness the event. 6. Repair damaged surface casing integrity. Repair options include sleeve patch, seal weld, lap patch, deposition weld and will be determined after inspection of the casing damage. 7. QA/QC the repair welds and MIT-OA to verify integrity 8. Install anti-corrosion coating on exposed surface casing. 9. Patch the conductor and top off the conductor void with cement and corrosion inhibiting sealant. 10. Backfill gravel around the wellhead. 11. Remove plugs and return the well to production. 12. Submit 10-404 report of repair operations to AOGCC. i WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. October 6, 2009 Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Injection Profile: 2B -08 Run Date: 7/6/2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2B -08 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50- 029 21079 -00 Injection Profile Log NO .,r 2 7 ZOOS 1 B/W Log 50- 029 21079 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline Perforating Attn: Rafael Barreto 1 5 4-( U 6900 Arctic Blvd. 175tb. Anchorage, Alaska 99518 Office: 907 273 -3527 Fax: 907 273 -3535 rafael.barreto @halliburton.co 41 Date: NOV 6 5 7009 Signed: L yJry ~ ~ ~{ ~ ~ ~~ Gt F ~ q p~ ~ ~ ~ i a i~ ~ ~: r fl ~ ~ @g ~ ~' ~ rp ~ f F ~ ~ ' y?~ ~a4 " ~tp ry~ ~~ ~ ~ ~ ~ . ~ ~ ~ 9 ~~; § 6,d ,~ $ 7 ~ y ~ A ~ S } 4 ~ ~, { ~%~b P ~ ~ ~ ~ ~ F~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~; ~ ~ ~ A~J~ ~p ~ ~ ~~~ ~~~~ ~ SEAN PARNELL, GOVERNOR ~ ~ ~ ~.~ ~ r t,~ ~ ~ X ~-7~~ QIL t~lsi~ Vra47 ~~b 333 W. 7th AVENUE, SUITE 100 C01~5ER~ATI011T CO1rII~IISSIOI~T ~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 ;~ FAX (907) 276-7542 Mr. M.J. Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. ( „ P.O. Box 100360 ~..~U Anchorage, AK 99510 , \.' D (~ v~~ 1'l] Re: Kuparuk River Field, Kuparuk Oil Pool, 2B-08 Sundry Number: 309-307 . ~;. ~ ~.~,.w _, _ . ~~ ~~~~;:,' Dear Mr. Loveland: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this ~ day of September, 2009 Encl. • ~~ ~ ~ ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 28, 2009 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • ~ °; ~ ~ ~ a' ~ ~; "~ ... ; , ; _ .. ti._ ~ ~ ~ l ~ v~ :a . _ ~~~ f, ~ .~ . Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. we112B-08 (PTD 184-026) surface casing repair. Please call Perry Klein or me at 659-7043 if you have any questions. Sincerely, .G~~,. , ~~.~~''`~ ~ MJ Loveland ConocoPhillips Well Integrity Projects Supervisor Enclosures ~ / O ~' ~/ ~ ~ah ~a ;; ~.,~ • (~~~ , ,.- STATE OF ALASKA -~ r~ r~ ,) fAi ^/ ~p~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~Z APPLICATION FOR SUNDRY APPROVAL ~ ~ ~ = ;r, ~~.~ ~ ... 20 AAC 25.280 1. Type of Request: Abandon ~ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ~ Other Q Alter casing ^ Repair well ^/ ~ Plug Perforations ^ Stimulate ^ Time F~ctension ~ SC Platelet • Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ~ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 184-026 ' 3. Address: Stratigraphic ~ Service Q • 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21079-00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownershi p or landownership changes: Spacing Exception Requires? Y2S ^ NO ~^ 2B-08 ' 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25656,~ALK 2582 RKB 127' Kuparuk River Field J Kuparuk Oil Pool • 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7500' 6304' Casing Length Size MD ND Burst Collapse CONDUCTOR 117 16" 117 117 SURFACE 2903' 9-5/8" 3030' 2726 PRODUCTION 7373' 7" 7500' 6304 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7100-7135, 7216-7222, 7233-7256, 7277-7298 5958-5987, 8057-6062, 6072-6091, 6109-6127 3.5~~ J-55 72~~ ~ Packers and SSSV Type: Packers and SSSV MD (ft) Baker FB-1; Baker FHL 7175', 6951' SSSV - Locked out 1948' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ~ Development ^ Service ~^ • 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat October 15, 2009 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG 0• GINJ ^ WINJ ^ WDSPL ~ Commission Representative: 18. I hereby certify that the foregoing is true and correct the best of my knowledge. Contact: MJ Loveland/ Perry Klein 659-7043 ~ Printed Name MJ Loveland ;f Title: Well Integrity Project Supervisor Signature ,s.t~~~ ~ Phone 659-7043 Date ~ ~~' ~ Commission Use Onl Sundry Number: Conditions of approval: Notify Commiss ion so that a representative may witness ~- ~ Plug Integrity ~ BOP Test ~ Mechanical Integrity Test ~ Location Clearance ^ Other: Subsequent Form Required: ~O ~ ~ ~ ~ / ~ ~ / '~i APPROVED BY ~~ Approved by: ~ OMMISSIONER THE COMMISSION Date: Form 10-403 Revised 06/2006 ~+~!~~~ ~~°~„ _~"i' a'~ ~?~~~ ub it in Duplicate w ~~s ~ g~ ~ ~~ ~ ~ ConocoPhillips Alaska, Inc. Kuparuk Well 2B-08 (PTD 184-026) SUNDRY NOTICE 10-403 APPROVAL REQUEST August 28, 2009 This application for Sundry approval for Kuparuk we112B-08 is for the repair of a surface casing leak. Kuparuk River Unit we112B-08 (PTD 184-026) was drilled and completed in 1984 as a development well and subsequently converted to an injector. In Apri12008 surface casing leak was reported to the AOGCC. Subsequent testing indicated the leak depth in the surface casing approximately 19" down from the OA valve. It currently is operating under AA AOI 2B-031 For technology development and due to the back log of surface casing excavation repairs ConocoPhillips is planning a temporary repair with Brinker Platelets (long term plans still include a conventional welded patch). Platelets are free floating (neutral density) discrete particles which are injected into the system (in this case the OA) and transported with the fluid flow and entrained in the leak with fluid force thus providing a seal. The Platelet material is entirely inert, designed to function in oil and gas applications, and within the operating conditions of the well. Each particle is individually sized to fit the predicted leak geometry. With approval, repair of the surface casing will require the following general steps: 1. Rig up Platelet manifold to OA 2. Establish liquid leak rate; 3. Deploy a finite number of Platelets; 4. Maintain specified pressure on OA for a specific amount of time (to be determined by Platelet Tech, however probably less than 1000 psi). 5. MITOA to 1800 psi; 6. Return well to normal operations, however maintaining some positive pressure on OA. 7. File 10-404 FW: Kuparuk Injector 2B-08 (PTD 184-026) SC leak Page 1 of 2 • • Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] ~~ ~I~~O~ Sent: Friday, April 18, 2008 6:35 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Fleckenstein, Robert J (DOA) Cc: NSK Problem Well Supv Subject: FW: Kuparuk Injector 2B-08 (PTD 184-026) SC leak Attachments: MIT KRU 26-08 04-11-08.x1s; 2B-08 TIO.jpg; 2B-08.pdf Jim, Diagnostics were completed and the well was shut in on 04f12/08. It is CanocoPhillips intention to apply for an AA to continue injection. Attached is the data from the passing MITIA performed on 04111108. ,/ Please iet me know if you have any questions. «MIT KRU 2B-08 04-11-08.x1s» Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 ~~A;i11NEC~ MAY (~ ~ 2008 From: NSK Well Integrity Proj Sent: Friday, April 11, 2008 4:03 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)' Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: Kuparuk Injector 26-08 (PTD 184-026) SC leak Jim, While preparing injector 2B-08 (PTD 184-026) for corrosion inhibiting sealant in the conductor evidence of a possible surface casing leak was noted when a small volume of diesel was encountered at the top of cement in the conductor. Today the suspected leak was visually confirmed very close to surface through the cement circulation port during an MITOA. No fluids were spilled outside the conductor during the test. TIO pressures before testing were 2700/1150/25. The plan forward is: 1. Leave well on injection long enough to obtain an MITIA -but no longer than 1 week 2. Install secondary containment in the well cellar 3. Pending a passing MITIA apply for an AA 4. Begin process for surface casing excavation and repair. A 3 month TIO plot and schematic are attached. '/ Please let me know if you have any questions 5/2/2008 FW: Kuparuk Injector 2B-08 (PTD 184-026) SC leak MJ Loveland • Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 «2B-08 TIO.jpg» «2B-08.pdf» Page 2 of 2 5/2/2008 • KRU 2B-08 PTD 184-026 TT(l T)rncmirac _ d~~ Q~7nnR • - CHOKEVV- F1 _ nso 2500 2000 _ 1500 ~i 1000 500 0 T~:`O Plot -26~ 200 150 c m 700 4 u 5D 0 11-Jan-08 2d-Jan-08 00-Feb-OB 19-Feb-OB 03-Mar-OS iu-Hoar-ua ~~-roar-uo Gate TT(l Aracenrac - d~~ ~ ~7nnQ • • 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 / 2B-OS 04/11 /08 Bates - AES Packer De th Pretest Initial 15 Min. 30 Min. Well 26-08 T e In'. W TVD 31' Tubing 2,700 2,700 2,700 2,700 Interva{ O P.T.D. 184026 T etest P Test si ' 1500 Casin 1,200 ,200 3,100 3,100 P!F P Notes: Diagnostic non-witnessed MITIA OA 0 20 20 20 Well T e In'. TVD Tubin Interval P.T.D. T e test Test si Casin P/F Notes: OA Well T e In'. TVD Tubing Interval P.T.D. T e test Test si Casin P/F Notes: OA Well T e In~. TVD Tubin Interval P.T.D. T e test Test si Casin P!F Notes: OA Well T e In~. TVD Tubing Interval P.T.D. T e test Test si Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D =Drilling Waste M =Annulus Monitoring 1=Initial Test G =Gas P =Standard Pressure Test 4 =Four Year Cycle I =Industrial Wastewater R =Internal Radioactive Tracer Survey V =Required by Variance N =Not Injecting A =Temperature Anomaly Survey T =Test during Workover W =Water D =Differential Temperature Test O =Other (describe in notes) MIT Report Form BFL 11!27/07 MIT KRU 2B-08 04-11-08.x1s T ~c~~r~~c~t~~~l~~~'~ ~l~s~~, lr~c. --- - 2a-os - -- - __, _ API: 50029211 € ' SSSV Type: Locked C sssv - (lsaa-1sas, Annular Fluid: OD:3.500) Gas Lift andrel/Dummy Valor 1 (6891-6892, OD:5.313) PBR (6937-6938, OD:3.500) PKR (6951-6952, OD:6.151) Injection 3ndrel/Dummy Valve 2 (6990Fi991, OD:5.313) Injection 3ndrellDummy Valve 3 (7060.7061, OD:5.313) Pert (7100.7135) Injection MandrelNalve 4 (7162-7163, PKR (7175-7176, OD:6.151) NIP (7191-7192, OD:3.500) TUBING (0.7201, OD:3.500, ID:2.992) SOS (7200-7201, OD:3.500) Perf (7216-7222) Perf (7233-7256) Perf (7277-7298) 1" DMY (7498-7499, OD:1.000) • KRU 2B-08 -_ Well T e: INJ An le TS: 32 de 7100 Orig 2/28/1984 Angle @ TD: 30 deg @ 7500 Com letion: Last W/O: Rev Reason: TTL ELMD UPDATE Ref Lo Date: Last U ate: 10/4/2007 TD: 7500 ftKB I I Last Taq Date: 15/27/2005 I Max Hole Angle: 40 deg a(7 3700 Casing String -ALL STRI NGS Descri lion Size To Bottom TVD V1/t Grade Thread CONDUCTOR 16.000 0 117 117 65.50 H-40 SUR. CASING 9.625 0 3030 2726 36.00 J-55 PRC)D CASING 7.000 0 7500 7500 26.00 J-55 Tubing String -TUBING Size Top .i 5u0 i 0 Botto i'01 m - TVD Wl G(1.1-i ~) 3t7 Grade I J-55 i Thread '.RD EUE AEP~1 Perforations Summary _ I -~ Interval TVD Zone Status Ft SPF Date T Gumrnent 7100 - 7135 5958 - 5988 C-4 35 12 7/14/1984 APERF 120 deg. phasing; SOS 5 1!2" Cs Gun 7216 - 7222 6057 - 6062 A-5 6 4 7/25/1984 APERF 90 deg. phasing; 2 1/8" Tornado Link Jet 7233 - 7256 6072 - 6092 A-4 23 4 6/24/1984 IPERF 2 1/8"'GO' Link Jet 7277 - 7298 6110 - 6128 A-3 21 4 6/24/1.984 IPERF 2 1/8" 'GO' Link Jet 'Gas Lift Mandrels/V alves MD TVD SY _ r Man Mfr Man Type Latch Port V Mfr V Type TRO Date Run I ~ 1 I I ~ I Cmnt I 1 6891 5781 MMH FMHO DMY 1.0 BK 0.000 0 7/25/1984 Injection Mandrels/Valves St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 2 6990 5864 MMH FMHO DMY 1.0 BK 0.000 0 8/14/1992 3 7060 5924 MMH FMHO DMY 1.0 BK 0.000 0 11!9/1992 4 7162 6011 MMH FMHO HFCV 1.0 BEK 0.000 0 5/27/2005 ( ]thor lnlnnc onnin otr 1 _ IFIAIFI RV De th .. rvD . T . e_ - - _.Descri lion _ _ ID 1948 1869 SSSV Baker 'FVL' LOCKED OUT 3/26/90. MCX INJ VLV ulled 7/19/99 2.810 6937 5819 PBR Baker 10' 3.000 6951 5831 PKR Baker'FHL' 3.000 7175 6022 PKR Baker'FB-1' 4.000 7191 6036 NIP Camco'D' Ni le NO GO 2.750 7200 6043 SOS Baker 2.992 7201 6044 TTI FI Mn n 71 R9' PFR RWS IPRnF 6/11/9007 9 999 Fish -FISH _ Depth Deschption i Gornment i 7498 1"DMY EmoN Pocket: Fell to Rathole from GLV Cct?6990' 11/7/85 Schlumberger OIC" l'tt.{ - oe'=> - ~ hM"-\EO JUN'" 1 'lOG SCt'U'" 06/14/07 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth NO. 4300 S¡ I) ?flfl7 .;;} ""~ Lt t ~ Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ji [.~ Field: Kuparuk Well Job# BL Color CD Log Description Date 2M-16 11629024 SBHP SURVEY 06/06/07 1 2N-306 11629025 SBHP SURVEY 06/06/07 1 2H-07 11638870 PRODUCTION PROFILE 06/07/07 1 2N-323 11629027 SBHP SURVEY 06/08/07 1 2N-313 11629027 SBHP SURVEY 06/08107 1 2M-29 11638871 SBHP SURVEY 06/08/07 1 1C-104 11638872 LDL 06/08/07 1 1 G-08A 11629026 PRODUCTION PROFILE 06/09/07 1 2N-308 11638874 SBHP SURVEY 06/09/07 1 2M-10 11629031 SBHP SURVEY 06/10/07 1 1A-27 11638876 PRODUCTION PROFILE 06/10/07 1 2M-12 11629030 SBHP SURVEY 06/10/07 1 2L-311 11638881 SBHP SURVEY 06/11/07 1 2N-317 11638878 SBHP SURVEY 06/11/07 1 2B-08 11629032 INJECTION PROFILE 06/11/07 1 1 H-08 11638882 INJECTION PROFILE 06/12/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . MEMORANDlJM State of Alaska Alaska Oil and Gas Consen'ation Commission TO: Jim Regg P.I. Supervisor ~ '\~~6 (~21(O4 DA TE: Wednesday. June 23. ::!OO4 SllBJECT: ~lechanicallntegrl[Y Tests CONOCOPHILUPS ALASKA INC FROM: Chuck Scheve Petroleum Inspector ~B-08 KUPARUK RIV UNIT 28-08 Src: Inspector Reviewed B\': P.I. Suprv 'Jb~ Comm NON-CONFIDENTIAL Permit Number: 184-026-0 Inspector Name: Chuck Scheve I nspection Date: 6/20/2004 Well Name: KUPARUK RlV UNIT 28-08 Insp Num: mltCS04062 1 1 14509 Rellnsp Num: API Well Number: 50-029-21079-00-00 Packer Depth Pretest (nitial 15 Min. 30 Min. 45 Min. 60 Min. Well 28-08 Type (nj. P ITVD 6304 IA 1100 2680 2620 2620 P.T. 1840260 TypeTest SPT I Test psi 1457.75 OA 0 0 0 0 Inten'al 4'{RTST P/F P Tubing '2150 2150 2150 2150 Notes: The pretest pressures were observed for 30+ minutes and found stable. Well demonstrated good mechanical integrity. Wt:'dnesday. June 23, 2004 Page I of I To: W~:Ii Name l.og 'l'ype Run Date Kuparuk Kuparuk Kuparuk Kuparuk iKuparuk Ku[,amk Kupamk. Kuparuk Kuparuk Kupamk Kupatuk Kupamk Kupamk Kupaluk Kupamk Kuparuk i~.ullarllK ! Kuparuk Kuparuk Kuparuk Kuparuk Received by:. Dated: River iJnit iE-iA lurer Unit IA--I 1 ~ver Unit 11.-10 River Unit 1L-I 4 River Unit IU-17 t~]ver Unit IL-22 l~vcr Unit I.R 04 P~vcr Unit 1Y-10 River Unit 1Y-J2 River Unit IY-15 River Unii 2B-08 l~ver Unit 2002 River Unit 2C-04 niver Unit 2C 05 River Unit 2C-06 Uiver llnit 2V-t0 River Unit 2V-13 ~ver Unit 3G-12 River Unit 3t1-02 River Unit 3G-20 Copy sentlo sender: Yes ~// No Water Flow I.og ('ii)'r..P) Injection Profile Injection Profile Injection Profile Injection Profile Injection Profile Injection Profile Injection Profile j ti "'" In ex: on l'rOllle Injection Profile Injection Profile Injection .Profile Injection Profile Injection Profile Survey Injection Profile Survey Injec'tion Profile Production l.og Production Log Injection Profile Injection Profile Survey Injection Profile 07.IA N 1991 10-1.91 03 NOVEMBERI991 4 NOVEMBER 1991 4 NO'v'EMBER 1991 11--06-1991 6/30/91 12-13-.--1991 11-19-91 11-17-1991 12--2-91 12-27-.1991 26 DEC 1991 10-27-1991 11/25/91 11~16-1991 8-JlJNE-1991 31-JULY--1991 11 NOV 1991 10/1 t9/91 11-29-1991 RECEIVED MAR 2 6 1992 Alaska 011 & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 30, 1990 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' · Subject: Kuparuk River Field Water Injection sUrveys In compliance with Rule 4 of Conservation Order No. 198, Kuparuk River Field Waterflood Rules, we are hereby submitting injectivity surveys for Kuparuk water injection wells for the First Quarter, 1990. The data is provided in the form of separate zone surveys or as spinner logs listed in Attachment 1. Injection rates determined by separate zone surveys are also listed in Attachment 1. The blue line and sepia-copies of the spinner logs are also included. If you have any questions concerning the information reported, please contact me at 263-4978. Sincerely, S. E. Schmidt Operations Engineer SES:LLP Attachment ARCO Alaska, Inc. is a Su~.s;diary of Atlan!icRichlieldCornpany ATTACHMENT 1 WELL APl NUMBER NUMBER 50- KUPARUK RIVER FIELD CONSERVATION ORDER 198 RULE 4 - INJECTIVITY PROFILES FIRST QUARTER 1990 SUBMITTAL DATE OF DATE OF DATA TYPE REASON FOR INITIAL PROFILE/ PROFILE/ PROFILE/ INJECTION SURVEY SURVEY SURVEY 1F-lO 02920984 10/28/85 1F-15 02921025 08/16/84 10-02 02920813 10/11/85 10-03 02920824 10/25/85 10-09 02921001 09/15/84 10-16 02921031 08/24/84 1R-03 02921406 11/19/85 1R-15., 02921387 11/10/8~ 28-07 02921080 07/12/86 ¢28-08 02921079 11/07/85 28-'10 02921084 11/09/86 2U-03 02921269 11/19/85 2U-lb 02921262 11/14/85 2U-16 02921264 01/lh/86 .~3A-02 02921431 01/27/87 ~3A-1.! 02921458 01/21/87 03/31/90 SEP ZONE FOLLOWUP 03/31/90 SEP ZONE FOLLOWUP 03/16/90 SEP ZONE FOLLOWUP 03/30/90 SEP ZONE FOLLOWUP 02/06/89 SEP ZONE FOLLOWUP 03/30/90 SEP ZONE FOLLoWup 03/04/90 SEP ZONE FOLLOWUP 03/07/90 SEP ZONE FOELOWUP 03/06/90 SEP ZONE FOLLOWUP 03/25/90 SPINNER FOLLOWUP 07/02/89 SEP ZONE FOLLOWUP 03/29/90 SEP ZONE FOLLOWUP 04/09/90 SEP ZONE FOLLOWUP 03/29/90 SEP ZONE FOLLOWUP 05/14/90 SEP ZONE FOLLOWUP 03/25/90 SEP ZONE FOLLOWUP 03/18/90 SEP ZONE FOLLOWUP 03/10/90 SPINNER FOLLOWUP WELL COMPLETION A&C SS A&C SS A&C SS A&C SS A&C SS A&C SS A&C SS A&C SS A&C SS A&C SS A&C SS A&C S'S A&C SS A&C SS A&C SS A&C SS A&C SS A&C SS 01/lh/90 SPINNER FOLLOWUP A&C SS ZONES TAKING WATER A C A C A C A C A C A C C C c C ¢ C INJECTION BWPD 4,08 MMSCFD 2.00 MMSCFD 3.44 MMSCFD 1.55 MMSCFD 800 5000 800 3600 1000 3000 120 5400 2250 1775 2150 1650 2500 2800 1150 2350 1500 2200 3150 22oo ~375 ~652 ~370 235 5665 ~50 00010000 00020000 00030000 O00hO000 00050000 00060000 00070000 00080000 00090000 O01O0OOO 00110000 00120000 00130000 O01hO000 001~1000 001h2000 001~2100 00142200 001~2300 001h3000 00150000 00160000 00170000 00180000 00190000 00200000 00210000 00220000 00230000 00240000 00250000 00260000 00260102 00260202 00260302 00260403 00260503 00260604 00260704 00260804 00260903 00261004 00261104 00261204 00261304 00261~04 00261504 00261600 00261700 00261800 00261900 00262000 00262100 00262200 00262301 00262~01 00262501 00262601 00262700 00262800 00263000 0026~000 00265000 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WE LL~3 2. Name of Operator ARCO ALASKA, INC. 3. Address P. O. BOX 100360, ANCHORAGE, ALASKA 99510 4. Location of Well SURFACE LOCAT!rhN' 68:2' FSL, 553' T11N, R9E, tJM FEL Sec. 1 9 7. Permit No. 8q-28 OTHER [] 8. APl Number 50- 029-21 079 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 2B-8 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 127' (RKB) ADL 25656, ALK 2582 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data 11. Field and Pool KUPARUK RIVER FIELD . KIJPARUK RIVER OIL POOl_ I 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 lation ~j Aba ndo nm en t Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other C~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is proposed that 2B-8 be converted from an "A" & "C" sand water injection to an "A" sand gas injection well. This conversion process is part of the Phase I water-alternating gas injection proiect. It is anticipated the injection will be routinely alternated from gas to water injection in 3 month and 9 month cycles. Conversion of 2B-8 is expected by 1/21/86. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. _ Signed ~'_.~,/~,~'c~-~' ~'~).-_. Title KIJPA~UK The space below for Commission use OPERAT IONS COORD I NATOR Date 1 / ? ! / 86 Conditions of Approval, if any: Approved by COMMISSIONER Approved CoDy Ileturned By Order of the Commission Date Form 10-403 Submit "Intentions" in Triplicate ,-,_.. -, ,, hr, nnri ".Ch~h~n~nt Reoorts" in Duollcate ARCO Alaska, In~ -, Post Office _ .100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 4, 1985 Mr C. V. Chatterton, Chairman Alaska Oil and Cas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton- Attached in duplicate are subsequent notices following wells at the Kuparuk River Field' Well Action Date Performed on the 1F-4 Convers 1F-5 Convers 1F-8 Convers 1G-3 Convers 1G-4 Convers 1L-3 Convers 1L-5 Convers 1Q-8 Convers 1Q-12 Convers 1Q-1 4 Convers 1R-3 Convers 1R-1 0 Convers 1Y-7 Convers 1Y-10 Convers 1Y-15 Convers 1Y-13 Convers 2B-6 Convers 2B-8 Convers 2B-11 Convers 2B-12 Convers 2C-2 Convers 2C-4 Convers 2C-5 Convers 2C-7 Convers 2D-4 Convers 2D-5 Convers 2F-3 Convers 2F-4 Convers 2F-15 Convers 2F-16 Convers 2D-10 Convers 2D-16 Convers on 10/24/85 on 10/24/85 on 10/24/85 on 10/25/85 on 10/25/85 on 10/24/85 on 10/24/85 on 10/25/85 on 10/25/85 on 10/25/85 on 10/26/85 on 10/26/85 on 10/26/85 on 10/26/85 'on 10/26/85 on 10/26/85 'on 11/5/85 'on 11/5/85 'on 11/5/85 'on 11/5/85 'on 11/6/85 'on 11/6/85 'on 11/6/85 'on 11/6/85 on 11/6/85 'on 11/6/85 on 11/2/85 'on 11/2/85 'on 11/2/85 on 11/2/85 'on 11/6/85 'on 11/6/85 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO ALASKA, INC. 3. Address P. O. BOX 100360, ANCHOR, AGE, ALASKA 99510 4. Location of Well SURFACE LOCATION' 68:2' FSL, 553' FEL Sec.19 T11N, R9E, tim 5. Elevation in feet (indicate KB, DF, etc.) 1 27' (RKB) 12. 7. Permit No. 8q-2~ 8. APl Number 50- 029-21 079 9. Unit or Lease Name KUPARUK RIVER IJN IT 10. Well Number 2B-8 11. Field and Pool KUPAR~JK RIVER FI ELD 6. Lease Designation and Serial No. KIJPARIJK RI VER O I L ADL 25656, ALK 2582 POOl_ Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other ~] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On November 5, 1985 Kuparuk well 2B-8 was converted from a producer to a water injector well as part of the full field waterflood conversion effort. Water is being injected into the "A" sand. 14. I hereby certify that the foregoing is true and correct to the best of my kn~c~R[jK Signed .~ /¢~'~_~--4 ~___~,x~,~ Title OPERATIONS COORDINATORDate The space below for Commission use 11/15/85 Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate Form 10-403 and "Subsequent Reports" in Duplicate Rev. 7-1-80 ARCO Alaska, Im 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 to water injection to implement fullfield waterflood of the KupaTuk 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 dri!lsite 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 RECEIVED ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany ~--. STATE OF ALASKA ---, ALASK, "'LAND GAS CONSERVATION L ?IMISSION SUNDRY NOTICES AND REPORTti ON WELLS DRILLING WELL [] COMPLETED WELL OTHER [] 2..Name of Operator ARCO Alaska, Tnc. 3. Address P.O. Box 100360, Anchorage, Alaska 4. Location of Well N/A 99510 7. Permit No. see attached 8. APl Number so- see attached 9. Unit or Lease Name Kuparuk River Unit 10. Well Number see attached 1 1. Field and Pool Kuparuk River Field 5. Elevation in feet {indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk Ri vet 0i 1 Po01 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 [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other )~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Pursuant to form 10-403, it is proposed that the attached list o 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 approximately 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. ECE V£D SEP 2 0 AlasKa Oil & Gas Cons. commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~, .~t:~-~ ~4~r-r~r',"-~ Title Kuparuk Operations Coordinator Date The space below for Commission use 9/18/85 Conditions of Approval, if any: Appr°vedby ~~ ~~ Form 10-403 Rev. 7-1-80 Approved Copy .... By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate IE- 6 -26 IF- 2 - 4 - 5 -- 1G- 2 - 3 - 4 - 5 IL- 1 - 3 - 5 - 7 -16 IQ- 1 - 2 - 7 - 8 -11 -12 -13 -14 IR- 3 - 8 -10 -13 1Y- 1 - 7 -10 -13 28- 5 - 6 - 7 - 8 - 9 -10 -11 -12 2C- 1 - 2 - 3 - 4 - 5 MARK:009 Permit 80- 78 82-166 81-211 172 132 162 82-138 149 161 83- 20 84-173 158 123 145 181 84-231 .232 218 209 199 193 85- 44 45 85-177 73 96 150 83- 50 68 51 15 84- 4 22 24 28 27 29 35 38 83- 83 93 89 94 99 API# 029-20493 029-20840 029-20881 20846 20807 20836 029-20813 20824 20835 20908 029-21196 21182 21155 21171 21202 029-21247 21248 21234 21225 21216 21210 21306 21307 029-21406 21333 21351 21385 029-20933 20950 20934 20903 029-21067 21078 21080 21079 21082 21084 21089 21092 029-20962 20972 20968 20973 20978 Lease & Serial # Convert Date 25651 469 10/15/85 " " 10/15/85 25652 2578 10/15/85 " " 10/15/85 " " 10/15/85 " " 10 /15/85 256~40 2571 10/15/85 " " 10/15/85 " " 10/15/85 " " lO/15/85 25659 2585 12/15/85 " " 10/15/85 " " 10115/85 " " 12/15/85 " " 10/15/85 25634 2567 10/15/85 " " 12/15/85 " " 12/15/85 " " lO/15/85 " " 12/15/85 " " 10/15/85 " " 12/15/85 " " 10/15/85 25635 2568 10/15/85 " " 10/15/85 " " 10/15/85 " " 10/15/85 25641 2572 12/15/85 25646 2577 12/15/85 " " 12/15/85 25548 2662 12/15/85 25656 2582 12/15/85 " " 10/15/85 " " 12/15/85 " " 10/15/85 25655 2581 12/15/85 " " 12/15/85 " " lO/15/85 " " 10/15/85 25654 2580 12/15/85 " " 10/15/85 " " 12/15/85 " " 10/15/85 S E.P 2 0 Alasl.';~ Oil & Gas C;ons. Commission ARCO Alaska, inc. l:'c..: 01',:::¢ ,'~ ~.':o:~-g-.'_. .ka 9~510 '~ e:~phone 907 277 5637 Date: 1~ Transmi-E'~al No: 4740 Return To: 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. SCHLL~'~ERGER FINALS/PRODUCTION ' ~f% 2G-7 CBL "Variable Density" "GCT/4" HJ" 2G-7 Completion Record "CBL/VDL/GCT" 7/13/84 Run 5 7/14/84 " 6000 - 6459 6000 - 6423 2B-9 CCL & Perf. Record 7/18/84 Run 1 2B-8 CCL & Perf. Record 7/13/84 " 2B-7 . CCL & Perf. Record 7/10/84 " 2A-5 Completion Record "PPS/JB" 6~26~84 " 8.600 - 8920 1F-2 Completion Record "Sq. 4" Retain" 8/02/84 " 7400 - 7750 1F-2 .Completion Record "Set Plug & Retain 8/03/84 Run 2 7450 - 7690 1F-2 CCL'& Perf. "Perf & Packer Set" "CBL/Plug - Reta in/JB" · ~ 1F-2 CBL ' "Var iable Density" "Packer Retain/Perf/JB" 8/06/84 " 8105184 " 6950 - 7 935 lG-4 CBL "Variable Density" 1G-4 Depth Determination Log "CBL" 1G-13 EPL "Tracer" Receipt Acknowledged: 8/11/84 8/11184 7103/84 Run 3 5964 - 6903 Run 1 5934 - 6548 " 7400 - 7941 Date: /cat DISTRIBUTION B. Adams D & M W.V. Pasher C.R. Smith - '/ -~ ~' ;-; ~' ~ G. Phillips State of Alaska F. Baxter -"':~'--~--: ~,~:~,~ C~'~Y~v _.~--"> .-:,., p Phillips Oil Sohio BP.~E ~'~ ~..t: ~.~. '.~: ...... Mo~ " J' J' ~t~ell Union ..... ~:.? ..... :~-~oe R & D Well Yiles Chevron KSK Operations .. ., ~ ,. . , -~, ,,~ .:~7,.:.~,~, (.~X~/~:' '" . ..... ARCO Alaska, In Post Office ~ox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 September 24, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2B-8 Dear Mr. Chatterton' Enclosed is the Well Completion Report for the subject well. you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU1/L53 Enclosure If Alaska Oil & Gas Cons. Cornmissio~ Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~'" STATE OF ALASKA '-~-~ -'' ' ALASK, ..,LAND GAS CONSERVATION £ ....MISSION (~, 'WELL COMPLETION OR RECOMPLETION REPORT AND LOG' 1. Status of Well Classification of Service Well OIL [~(X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-26 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21079 4. Location of well at surface 9. Unit or Lease Name 682' FSL, 553' FEL, Sec.19, TllN, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1136' FNL, 3526' FEL, Sec.30, TllN, RgE, UM 2B-8 At Total Depth 11. Field and Pool 1233' FNL, 3703' FEL, Sec.30, TllN, RgE, UM Kuparuk River Field , 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk Ri vet 0i 1 Pool 127' RKB ADL 25656, ALK 2582 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 02/21/84 02/27/84 04/20/84 N/A feet MSLI 1 17. Total Depth (MD+TVD} 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set I 21. Thickness of Permafrost 7500'MD,6304'TVD 7410'MD,6225'TVD YES [~ NO [] 1948 feet MD 1450' (approx) 22. Type Electric or Other Logs Run D IL/SFL/SP/GR/Cal/FDC/CNL, CBL/GR/CCL, 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 107' 24" 190 sx Cold Set II 9-5/8" 36.0# J-55 Surf 3030' 12-1/4" 750 sx Permafrost E & :50 sx Permafrost C 7" 26.0# J-55 Surf 7500' 8-1/2" 250 sx Class "G" & 250 sx 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) 7115' - 7135' 3-1/2" 7201' 7175' & 6951' 7100' - 7115' w/12 spf, 120° phasing 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production t 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 iTEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED.I~ 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 r~ Form 10-407 GRU1/WC08 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. ' 30. - ' ·: :' :- . .... . ~'-: . .. , .... - .. . .. .~ ,,' . ·" ., . . . .,' --GEOLOGIC MARKERS ' · FORMATION TESTS NAME Include interval tested, pressure 'data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. : Top Upper Sand 7098' 5956' Base Upper Sand 7135' 5987' Top Lower Sand 7205' 6047' N/A Base Lower Sand 7265' 6099' .? .. 31. LIST OF ATTACHMENTS l~orkover Wel 1 History 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title Ar'~.a Dri I linr~ Friar. 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 iterr.~ 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Kuparuk Rivet. Auth,.or W.O~ AFE 90012.5 WWS #1 *lTitle _ Unit NotCh Sloe Bo~ ADL # 25656 Alaska '~'ell no. 2s-8 w/o Completion Ol~rmtor Date and depth aa of 8:0~ a.m. ARCO Alaska, Inc., Spudded or W.O. begun IOate Workover Complete record for each clay reported 7/13/84 I Hour 7/12/84 1400 Hrs. ARCO W.,. 76.24% Prior status if a W.O. 7" @ 7500 7410' PBTD, RIH Wt. 10.2 NaC1/Br Accept Rig @ 1400 hfs 7-12-84. Pull BPV. Bullhead kill well w/5 bbls, 10.2 NaC1/NaBr, 35 bbls BridgeSal pill. Observe well, no flow. Set BPV, ND tree, NU BOPE & tst to 250/3000 psi. Tst ann 250/1800 psi, OK. PU landing jr, back out LDS, unsting from pkr. circ ann, recovered 6 bbl diesel, no gas. POH w/3-i/2" tbg, std back 73 stds. RIH w/3-1/2" tbg. Alaska Oil & The above II correct IOate · - - I Title ARCO Oil and Gas Company Daily' Well History- Final Report la~t~etleae: Prepare and submit the "Final R~I" oe~_.~ fim~ Wldftlldly I.ffer allow, able has be?n ass. lgne.d or well la_ Plugged. Abandoned, o.[r Sold. "Fi~II R~" should be submitted also when o~_~ded foz~.~l, lndefimte or apprecl_a.ble, t_ength ,o,f.time. un .workove. m. when an omclal te.?t il not required upon completion, report completion Ind;~.~: d&tt,' II~'-blocka provided. The "Plnal I~el~rr Iorm may De USeD for reporting the entire operation if space is available. _ :~.~.;~-. _ '- ~'- coat center code District Field Alaska North Slope Borough Alaska ICounty or Parish Lease or Unit Title IAccounting State Kuparuk River ADL #25656 Well no. 2B-8 W/O Auth. or W.O. no. AFE 900125 Completion Operator W.I. ~_RCO Alaska, Inc. 56.24% A.R.Co. Date Spudded or W.O. begun Workover 7 / 12/84 I otal number of wells (active or inactive) on Ihis Dst center prior to plugging and ~ bandonment ~f this well I our I Prior status if a W.O. I 1400 Hrs. Oate':;~nd depth as of 8:00 a.m. Old TD Released rig 7/14/84 2200 Hrs. CiasSificatinns (oil. gas, etc.) -Oil Complete record for each day reported 7" @ 7500 7410' PBTD, RR Kup crude in ann & tbg w/±20 bbl diesel cap in tbg Fin TIH w/3½" tbg w/2-1/6" stinger to pkr @ 7158', stab thru, tag fill @ 7304'. Rev circ hole @ PBTD, tbg packed off, lost 40 bbls brine. Spot 30 bbl BridgeSal pill to pkr, sqz 25 bbl pill to formation. Stage in hole feeling f/fill; no fill, POH. Perf 7115"-7135' & 7100'-7115' @ 12 SPF/120° phasing. TIH w/223 jts, 3½", 9.3# J-55 8RD EUE ABM tbg & lnd w/SSSV @ 1948', PBR @ 6937', FHL Pkr @ 6951', FB-1 pkr @ 7175', "D" Nipple @ 7191', Tbg Tail @ 7201', Shear Sub @ 7200'. ND BOPE, NU &tst tree to 250/5000 psi. Displ well to Kup crude. RR @ 2200 hrs, 7/14/84. ~ New TO PB Depth 7500' 7410' Date Kind of rig 7/14/8.4 Rotary IType completion (single, dual, etc.) Single Official rese~oir name(s) Kuparuk Sands Producing method Flowing Potential .test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test 'Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Date I Title 7/23/84 Drilling Superintendent ARCO Alaska, I: Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 September 24, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2B-8 Dear Mr. Chatterton. Enclosed is a Subsequent Sundry Report for the subject well. you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU1/L51 Enclosure If RECEIVED SEP 2 7 19B4 Alaska 0ii & Gas Cons. Commissio~ Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION UOMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well COMPLETED WE LLxI~ 7. Permit No. 84-26 8. APl Number 50- 029-21079 9. Unit or Lease Name OTHER [] Surface: 682' FSL, 553' FEL, Sec. 19, T11N, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) RKB 127' 6. Lease Designation and Serial No. ADL 25656 ALK 2582 12. Kuparuk River IJni~ 10. Well Number 2B-8 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) Perforate [] Alter Casing [] Perforations Stimulate ~ Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Accepted rig ~ 1400 hfs, 07/12/84. Killed well. ND tree. NU BOPE and tstd - ok. Pulled tubing. Spotted a Bridgesal pill. Perforated the following intervals w/12 spf, 120° phasing: 7115' - 7135' 7100' - 7115' Ran 3-1/2" completion assy w/tail @ 7201', FB-1 pkr @ 7175', FHL pkr ~ 6951' & SSSV ~ 1948'. Dropped ball & set pkr. ND BOPE. NU tree & tstd to 5000 psi - ok. Tstd tbg to 3000 psi - ok. Disp well w/diesel & Kuparuk crude. Tstd SSSV - ok. Opened SSSV. Set BPV. Secured well & released rig ~ 2200 hrs, 07/14/84. RECEIVED 'Alaska 0il & Gas Cons. Commission A~ch0rage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ./~2/'~ ~/r~/~_..~ Title Area Pti1 ling Engineer The space ~v~r ~'o/mission ;se ConditioF[s of ApprovaJ, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1 ~0 GRU1/SN48 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska,. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 August 10, 1984 Mr. C. V. Chatterton State of 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 Well Action Date Performed 1F-11 Fracture 6/25/84 1F-12 Perforate 6/29/84 1F-12 Fracture 7/08/84 1G-6 Re-perforate 8/01/84 1G-7 Fracture 7/29/84 1G-8 Fracture 7/23/84 2B-7 Perforate 7/24/84 2B-8 Perforate 7/25/84 2B-9 Perforate 7/27/84 .. ., the If you have any questions, please call me at 263-4253. Mike L. Laue Kuparuk Operations Coordinator MLL/kmc Attachment (Duplicate) RECEIVED AUG ! Oil & Gas Cons, Commission Anchorag~ ARCO Alaska, Inc. is a Subsidiary of AllanlicRichlieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL 2. Name of Operator ARCO ALASKA, INC. ;3. Address P. O. BOX 100360, ANCHORAGE, ALASKA 99510 OTHER [] 4. Location of Well SURFACE LOCAT ION' T11N, RgE, UM 682' FSL, 553' FEL Sec.19 5. Elevation in feet (indicate KB, DF, etc.) 127 ' (RKB) 12. 7. Permit No. 84-28 8. APl Number 50- 029-21 079 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 2B-8 11. Field and Pool KUPARUK RIVER FI ELD I6. Lease Designation and Serial No. KUPARUK RI VER O ! L ADL 25656, ALK 2582 POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations ~ Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On July 25, 1984, the "A" sands of Kuparuk well 2B-8 were perforated for production. After testing the lubricator to 3000 psi, the well was shot with a wireline conveyed gun. Interval (MD)- 7216'-7222' (4 SSPF) RECEIVED AUG 1.3 1984 Alaska Oil & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title OPERATIONS COORDI N^TOR The space below for Commission use 8/10/84 Date 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, Ir Post Offic,~ =lox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 23, 1984 Mr. C. V. Chatterton Chairman Alaska Oil and Gas.Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' Attached are notices of intention 2B-7, 2B-8, and 2B-9.' If you have any questions, please to perforate Kuparuk wells .. call me at 263-4253. Mike L. Laue Kuparuk Operations Coordinator MLL/kmc Attachment (In Triplicate) RECEIVED JLIL 2 5 L.q Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary ol AllanticRichfieldCompany -"- STATE OF ALASKA ----. ALASKA ,_ ,L AND GAS CONSERVATION CC .MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER 2. Nam~ of Operator ARCO ALASKA, INC. ANCHORAGE, ALASKA 9951 0 3. Address P. O, BOX 100360,. 4. Location of Well SURFACE LOCATION' T11N, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) 127' (RKB) 12. 682' FSL, 553' FEL Sec.19 7. Permit No. 84-2t~ 8. APl Number 50- 029-21 079 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 2B-8 11. Field and Pool KUPARUK RIVER FI ELD 6. Lease Designation and Serial No. KUPARUK RIVER O I L ADL 25656, ALK 2582 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 J~ Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Per my telephone conversation with Mike Minder (AOGCC) on July 1984, it is proposed that the "A" sand in Kuparuk well 2B-8 be perforated for production. Procedures call for the well to be perforated with a wireline conveyed gun under a lubricator. 20, Proposed Intervals (MD). 7216'-7222' (4 SPF) ANTICIPATED START DATE: July 24, 1984 RECEIVED JUL25 I984 Alaska 0il & Gas Cons. Commission Anchorage 14.' hereby certify that the foregoing is true and correct to the best of my kn'°'w' I'e-dg'e~-UK~UPA~ Signed ~/~~~e,X-qZ,.__., Title OPERAT IONS COORD I NATOR Date 7-Z,,-~' (_'_'_~"~Z' The space below for Commission use Conditions of Approval, if any: Approved by COMMISSIONER Approved Cc=, Returned .... ,/: By Order of the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ~-. STATE OF ALASKA ALASKA L AND GAS CONSERVATION Ct ,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO ALASKA, INC. 3. Address P. O. BOX 100360, ANCHORAGE, ALASKA 99510 4. Location of Well SURFACE LOCATION: 682' FSL, 553' FEL Sec.19 T11N, R9E, UM 7. Permit No. 84- 2~ 8. APl Number 50- 029-21 079 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 2B-8 1 1. Field and Pool - KUPARUK RIVER FIELD 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. KUPARUK R I VER O I L 127' (RKB) I ADL 25656, ALK 2582 POOL 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [~ Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10407 for each completion.) 13. Describe Propos.ed 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). Per my telephone conversation with Mike Minder (AOGCC) on July 1984, it is proposed that the "A" sand in Kuparuk well 2B-8 be perforated for production. Procedures call for the well to be perforated with a wireline conveyed gun under a lubricator. 20, Proposed Intervals (MD)' 7216'-7222' (4 SPF) ANTICIPATED START DATE- July 24, 1984 Subsequent Work Reoorted on Form No./~ .Z~Dated RECEIVED JUL 2 5 Alaska Oil & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledqe. KU PARU K Signed _~//~~~..).-q)...__~ Title OPERATIONS COORDINATOR Date The space below for Commission use Conditions of Approval, if any: Approved by Approved Copy Returned By Order of COMMISSIONER the Commission Form 10403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc Post Office ~,,)~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 5, 1984 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservati on Commi ssi on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Conductor As-Built Location Plats - 2B-Pad Wells 5-12, 1-4, 13-16 Dear Elaine' Enclosed are as-built location plats for the subject wells. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU8/L27 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompany j ,r..~. BUILT LOCATIONS WELL 5 Y: $ e54 664.'r9 Lot. 70°t?'t4.48B4" ~ x = 508 166.01 L~. 149°56'C~059" =~ 479 FE~, 519 FSL EL. 91.0', O.G. 87.0' , '~ WELL 6 Y = 5 954 7[9.~0 Lot. 70017'15.0249'' X=- 50~ 14t.09 Lon~. 149°56~0~.7~4" WEL~ 7 Y: ~ e~" ~.~ L.t. ~O°'i~'~~'' X~ 508 II6,16 Long, 149056'03.~8'' 5~8 FEL,6~8 FSL EL. 91.~', O.G. 8~0' , , , WELL 8 Y ~'g5482~53 ~0t. 70°i7~16.0998'' X= 508091.27 Long. i49°56'04.~3~'' 553 FEL ~68~ FSL EL. 91.O',O.G. ~7.0' X~ 507 B63,~6 Long, 1~9°56'{0.86i TTgFEL~i183FSL EL. 89.4'~O.G. 85-5' WELL ~ Y = 5 955 ~s3.54 ~ot. 7~°I'~'~t.5614" x= 507 858.34 L0ng. 149°56'll.585" t9 , e~ .... 803 FEL~38FSL EL. 89.4'~O.G. 85.0 30 z9 WELL II Y=5955438.~1 Let, 70°!7'~'2.0985 X= 507 8t3.47 Long. 149°56'lZ,308'' 8Z8 FEL, IZg~ FSL .... , WELL 12 Y=595549~.55 Lat. 70~17'22.6~1'' X~ 507 788.5~ Long. t49°56't3.033'' 853 FEL,1347 FSL __~ ..... ;-- il ........... ' CONDUCTORS 5-12 ~ OF A~t AS-BUILT ~?,,,,-,.,,,,~,..,. ~.~.., LOCATED IN PROTRACTED SECTION 19 ~~ TOWNSHIP I1 N,~ RANGE 9 ¢ ~ UMI~T MERIDIAN. ~ ~ ~a~H ~ ~ aB ~UTH PER ~HD & A~. j ~ . .~.~ 0.~. ELEV. BASED ON O.G CONCURS PER ~RNS,~OGER "'J L ~ .~ .~; ~%, ~,~.,- ~ DWG. NO. 8~-I2-~0~0 REV. ~. ' -, ~-~-----~, ,, ' -,~,~,~-~ ~ ~ bu~',~bo~,.,missinn ..... J I HEREBY CERTIFY:~HAT,,I AM PROPERLY REGI~ERED ~m ' ~ I I[ ' I I I THIS : Kuparu~ Project North Slope Drilling 3 [~ '~ ~ DRI[~ sITE 2. B ' Dote: gonuory l~1984 $cele~ -. I ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 9, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT: 2B-8 Dear Mr. Chatterton' Enclosed is a Sundry Notice for the subject well. We propose to pull the existing work string and complete 2B-8 as a selective single. Since we expect to start this work on July 14, 1984, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. JBK/JG/tw GRU8/L40 Enclosures RECEIVED J U L 1 0 1984 .f.'Jaska Oil & Gas Cons. Commission ~,nchora~e ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA -. ALASKA ~ AND GAS CONSERVATION C( MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL[] COMPLETED WELL 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 84-26 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21079 OTHER [] 4. Location of Well Surface: 682' FSL, 553' FEL, Sec.19, T11N, R9E, UH 6. Lease Designation and Serial No. ADL 25656 ALK 2582 5., Elevation in feet (indicate KB, DF, etc.) RKB 127' 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 2B-8 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] ~ Other ~ Pulling Tubing [] Pull 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 Abandonmentsee20 AAC 25.105-170). ARCO Alaska, Inc., proposes to pull the existing work string and complete 2B-8 as a selective single. The procedure will be as follows: 1. MIRU workover rig. 2. Pull existing work string. 3. Run a retrievable packer to verify zone isolation between A and C sands. 4. Complete well as a selective single. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. BOP equipment will be tested weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. The subsurface safety valve will be installed and tested upon conclusion of the job. Estimated Start: July 14, 1984 J U L 1 0 igC4 Alaska 0/I & Gas COns. CommJssio~ Anchorage 14. I hereby cert~that the foregoing is true and correct to the best of my knowledge. Signed Title Area Dri 11 ing Engi neet The spac f ion use Conditior~of Appro~]~if any: Date Approved by ~.~ COMMISSIONER Approved Copy ~.,Returned . By Order of the Commission Date .... Form 10403 Rev. 7-1-80 GRU8/SN16 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate KUPARUK ENGINEERING Date: ~~ Z~I Iq~ J Well Name: _%fJL ~010 Transmittal Log 2r--g" " " Date Run Ioq.fl, n ~ compa.,~., DISTRIBUTION NSK Operations Dr il 1 lng Geolbgy /Ken State of AK Blueline Bluel ine Film Blueline & Sepia · n & return t~'e a,~/,a/~d, copy as receipt of' ..:, ~..: :,.~(~~ '~'"b':> '7,/ :~ r-. ~': ~-' :i:~ f-, .... zl,.,,,''~ .'~9. f~ ~.. Return to: ARCO ALASKA, INC. ATTN: Pav~/ri.W~Trl~ ATO-1115B P.0. Box 100360 Anchorage, AK 99510 ARCO Alaska, I Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 15, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2B-8 Dear Mr. Chatterton: Enclosed is a Subsequent Sundry Report for the subject well. you have any questions, please call me at 263-4944. Si ncerely, Gruber Associate Engineer GRU7 / L47: tw Enclosure If ~.~. Oil 6 gas Cons. Commission ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALAS, . OIL AND GAS CONSERVATION ,~OMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [~X 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 84-26 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21079 OTHER [] 4. Location of Well Surface: 682' FSL, 553' FEL, Sec.19, T11N, RgE, UM 5. Elevation in feet (indicate KB, DF, etc.) 127' RKB I 6. Lease Designation and Serial No. ADL 25656 ALK 2582 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 2B-8 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE QF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) (Su~mit in Duplicate) Perforate [] Alter Casing [] Perforations ~0 Altering Casing Stimulate [] Abandon [] Stimulation ~[] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] 12. (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}. RU Gearhart/Eastman. Removed lower tree assy. Ran CBL/GR/JB/gauge ring - good bond. Ran Gyro. RD Gearhart/Eastman. Installed lower tree assy. Secured well. Accepted rig ~ 2200 hfs, 04/18/84. ND tree. NU BOPE. Tstd BOPE to 3000 psi - ok. Tstd annulus to 1800 psi. - ok. RIH w/FB-1 pkr & set @ 7158'. Ran 3-1/2" completion assy w/tail ~ 7184' & pkr @ 7158'. (See attached I tubing detail sheet). Disp well w/diesel and crude oil. Set BPV. ND BOPE. NU tree & tstd to 5000 psi - oH. Tstd annulus to 1500 psi - ok. Tstd tbg to 4000 psi - ok. Bled pressure off tbg & ann. Secured well & / released rig @ 0900 hfs, 04/20/84. Alaska Oil a ~.i'c.s Co:xs. Co,~nmissio~ 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Area Dri 11 i ng Engineer The spacxcZbelov~ f6~/~flmission use Conditions of Appeal, if ,any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 CRU7/SN08 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Ir Post Office c~ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 15, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2B-8 Dear Mr. Chatterton: Enclosed are the Completion Report and gyroscopic survey for the subject well. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG:tw GRU7/L48 Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany tv?AY l 7 19 4 Alaska Oil & 6a.~ Cons. Commission ' ~ ~ ' '--'~-- STATE OF ALASKA ..~_.. ALASI* c,,LAND GAS CONSERVATION -,MISSION WELL COMPLETION OR RECOMPLETION'REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-26 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21079 4. Location of well at surface 9. Unit or Lease Name 682' FSL, 553' FEL, Sec.19, T11N, RgE, UM ~' L6CATIO~-~' Kuparuk River Unit I VERIFIED At Top Producing Interval 10. Well Number 1136' FNL, 3526' FEL, Se¢.30, T11N, R9E, UH Surf.. ~ ~i 2B-8 At Total Depth B. H .... ~ [ 11. Field and Pool 1233' FNL, 3703' FEL, Sec.30, T11N, RgE, UN - Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 127' RKBI ADL 25656, ALK 2582 12. Date Spudded02/21/84' 13. Date T.D. Reached02/27/84 14' Date C°mp" Susp' °r Aband' I 15' Water Depth' if °ffsh°re 116' N°' °f C°mpleti°ns04/20/84 N/A feet MSL 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 7500'MD,6304'TVD 7410'MD,6225'TVD YES 1)(-I NO []I N/A feet MD 1450' (approx) 22. Type Electric or Other Logs Run D! L/SFL/SP/GR/Cal/FDC/CNL, CBL/GR/CCL, 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 107' 24" 190 sx Cold Set II 9-5/8" 36.0# J-55 Surf 3030' 12-1/4" 750 sx Permafrost E & 250 sx Permafrost C 7" 26.0# J-55 Surf 7500' 8-1/2" 250 sx Class "G" & 250 sx 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) NONE 3-1/2" 7184' 7158' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OtL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD 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 Form 10-407 GRU7/WC14 ,,i .:'! U'('~SSL/J~oi~ij~ll~pJicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE '~u,'c,';Oi-~!,.j,~, '"o~u~l 29. 30~ GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 7098' 5956' Base Upper Sand 7135' 5987' Top Lower Sand 7205' 6047' N/A Base Lower Sand 7265' 6099' 31. LIST OF ATTACHMENTS Drilling. History, Completion Summary, Tubing Detail Sheet, Gyroscopic Survey (2 copies) 32. I h~reby certify that the foregoing is true and correct to the best of my knowledge Signed Title Area Drillino Fn~nr; 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 ©perati'on: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 2B-8 DRILLING HISTORY NU 20" hydril and diverter. Spudded w~ll @0915 hrs on 2/21/84. Drld 12-¼" hole to 3045. Ran 70 jts 9-5/8" 36# J-55 HFERW BTC csg w/shoe @ 3030. Cmtd 9-5/8" csg w/700 sxs Permafrost "E" and 250 sxs Permafrost "C". Bumped w/1500 psi - ok. ND 20" hydril & diverter. Instld..9-5/8" packoff. NU BOPE and tstd to 3000 psi - ok. Tstd csg to 1500 psi -ok. Drld FC and cmt. Tested csg to 1500 psi - ok. Drld FS and i0' new form. Tstd form to 12.5 ppg - EMW - ok. Drld 8½" hole to 7450. Ran logs DIL/SFL/GR/SP/FDC/CNL/CAL f/7450' to 3030'. Cont drlg 8½" hole to 7500'TD as of 2/27/84. Ran 172 jts 7" 26# J-55 HFERW BTC csg w/shoe @ 7500. Cmtd 7" csg w/250 sxs class "G". Bumped plug and tstd csg to 3000 psi - ok. ND BOPE. Instld 7" packoff and tstd to 3000 psi - ok. Displ fluid from top of well. Performed Arctic pack using 250 sxs of Permafrost "C" and 58 BBLS Arctic Pack. Secured well and released rig @ 0900 hrs on 2/28/84. DH105 3/14/84 /±h 2B-8 COMPLETION SUMMARY RU Gearhart/Eastman. Removed lower tree assy. Ran CBL/GR/JB/gauge ring - good bond. Ran Gyro. RD Gearhart/Eastman. Installed lower tree assy. Secured well. Accepted rig @ 2200 hrs, 04/18/84. ND tree. NU BOPE. Tstd BOPE to 3000 psi - ok. Tstd annulus to 1800 psi - ok. RIH w/FB-1 pkr & set @ 7158' Ran 3-1/2" completion assy w/tail @ 7184' & pkr @ 7158'. (See attache~ tubing detail sheet.) Disp well w/diesel & crude oil. Set BPV. ND BOPE. NU tree & tstd to 5000 psi - ok. Tstd ann to 1500 psi - ok. Tstd tbg to 4000 psi - ok. Bled pressure off tbg & ann. Secured well & released rig @ 0900 hrs, 04/20/84. GRU7/CS14'tw · ARCh Alaska, inc. Sub;i¢i~ry c,l AtlanticRlchfieldC~mpa~Y DRILL SiTE __ ~L.,,-C.) -~-~ DATF~" ~1- .. (~ .- ~'~ . Page . ! of / ,._ _ pages #ITEMS COMPLETE DISCRIPTION OF' EQUIPMENT RUN LENGTH DEPTH .._ ~3,$? '7 3 '/¢' F..UF- &DC x 5 Y',." r~Tc ~, ~ '/,0 5'b." LSTc ~ × 5,'~" 2~' F-_.UF-.. p,,.) Xo. !,[5 221.11 -I /.q4- l ,, i 2.$ .~ O. ia l / '".'?.'. :: '_ AI2ska 0~i SI (:c.:; Co~:s. Ca~~ I/~ r~olm ~,~.d~,, ::£7 3~ !mission Remarks R. Suoer;'isor ¢,,.:c;dZ.t'6. gZO6 d i40;~ F'A!;~ 2B~ WELL NO: 8 SIGMA-GYRO ,_)OB NO: A0384Z0247 KI..~F"ARUK FIELD~ NORTH '..~LOPE? ALASKA .... ~]~.~=F~YRO, 0--7410 MD, SURVEYOR: CORAM/PEFFERKCmRN~ DATE RUN: 27-MAR-84- SIGMA 300· NO: 746~ PROBE NO: 058 FORESIGHT:S24 34. 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( ,' 500. ¢~. lC'N,_, 32 42 E 100. 499. c~-~...- ........... 600 .............. ~,..~._~_~,~.E ! 00. 599.99 '7('~¢) 0 '12 S 6,4 0 E 100. /-,99 f~9 :300,, 1 0 S :3 18 E 100. 7'?'F*. 98 ............. S~O0 ............. 3:36 S, 43 6 N .___~00~ 8'99.~9 0.00 - 127.00 0.00 0.0 C) -¢~.. ~ ~. -27. O0 O. 15 N ___.0...09 F -0.64 7:3 ..00 0.56 N 0.41 E -1.25 173.00 1.17 N 0.74 E -1.78 272. '.-?';¢' 1.83 N 0 ~2.-75 E . '"J SY '.:'/ '-. -2 ..:,C :::72. '7 .7.:7 N 1.2::2: E -':, F,L.3 472. '"'"" '2. .... 2~ 74 N 1.45 E '"' 9'::.,¢ R .-, c)o ":.' 83 N 1 75 E ~..' ._7." . .... -3.02 6,72.98 ....-'? (~0 N ~..":' :'2:1 E . "') '~, C) · .... -.~- .,--,~ , _ CJ..O/_-. 7__~, 1 67 S (')~_9::: E O. 00 0 0 O. 00 O. ! :--:N ~ :3 :--:L_! ::2-_':..E ......... ~j!.._._ 2=._'_ (_.:! _. 0../:,9 N :36, 5 E 0.21 1. :38 N 32 25 E O. 1'? 2.06 N 2'7:32 E 0.04 2.67 N 27 20 E O. 12 · 3.10 N 2'7_5_4__E ......... _<_.')_._.1(.'.')_ ..... 3. 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Operator, ~ell Name and Number Reports and Materials to be received by: ,~'L..:.~'(3 Date Required Date Received Remarks _ Ccmpletion Re~ort Yes · · Samples Core Chips '' ///~:, : /?:C ...... '"- ~ K - Core Description , _~-~----.- /~ . Registered Survey Plat 7E~'~' . Inclination Survey ? ~:~. . ~.~.~_~ Drill Ste~n Test Reports _///~,:~.._ · Prcddctibn Test Reports ., Logs Run. Yes Digitized Data y:.: KUPARUK ENGINEERING Transmittal Log Date Run # DISTRIBUTION NSK Operat ions Dr il 1 ing Geolbgy/Ken ~_~tat e of Bluel~ne Bluel ine Film Blueline & Sepia.-~.~ _ , /3/Sign & return the attached copy as receipJ; o~, ~at~,.~. ,' Return to: ARCO ALASKA, INC.,~ ATTN: D. Fay ALLISON ATO-1115B P.O. Box 100360 Anchorage, AK 99510 KUPARUK ENGINEERING TRANSMITTAL TO' ~ FROM: . . . D. F~y Allison DATE: ~- Z ~ ~ ~/ WELL NAME: / ~ee below Transmitted herewith are the following' PLEASE NOTE- BL - BLUELINE, S - SEPIA, F - FILM~~C - PHOTOCOPY . Well De script ion Date RECEI pT ACKNOWLEDGED' PLEASE RETURN RECEIPT ~CO ALASKA, INC. ATTN' D. FAY ALLISON - ATO/1115-B P. O. BOX 100360 ' ANCHORAGE, AK. '99510 Alaska Oil & Gas Cons. Commission .~r i,., ARCO~ Alaska, Ir Post Of;ice dox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 March 15, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Enclosed are the Monthly State Reports for the following wells: 2F-5 2B-5 WSP #3 2F-6 2B-6 Hemi Spring St #1 2F-7 2B-7 2B-8 2B-9 Thank you. Sincerely, JBK/SH1: ih ARCO Alaska. inc. is a subsidiary of AtlanticRichfieloCompany STATE OF ALASKA -'~ "ALA~K~"PlL AND GAS CONSERVATION ('~';MMISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling welll~ Workover operation [] 2. Name of operator. ARCO Alaska, Inc. 3. Address :P, 0, :Box 100360, Anchorage, AK 4. Location of Well at surface 99510 682' FSL, 553' FEL, Sec. 19, TllN, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) PAD 91' 127' RKB , 6. Lease Designation and Serial No. ADL 25656 ALK2582 8. APl N~e..r21079 50- 9. Unit or Lease Name KPK River Unit 10. Well No. 2B-8 11. Field and Pool KPK River Field KPK River Oil Pool For the Month of. February , 19__84 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 0915 hrs, 02/21/84. Drld 12¼" hole to 3045'. Ran, cmtd & tstd 9-5/8" csg. Drld 8½" hole to 7450. Ran logs. Cont drlg 8½" hole to 7500'TD. Ran, cmtd and tstd 7" csg. Performed Arctic pack. Displ fluid from top of well. Secured well and released rig @ 900 hrs on 02/28/84. 13. Casing or liner run and quantities of cement, results of pressure tests 9-5/8" 36# J-55 HFERW BTC csg w/shoe @ 3030. Cmtd w/700 sxs Permafrost "E" & 250 Permafrost "C". 7" 26# J-55 HFERW BTC csg w/shoe @7500'. Cmtd w/250 sxs class "G". sxs 14. Coring resume and brief description N/A 15. Logs run and depth where run DIL/SFL/SP/GR/CAL/FDC/CNL f/7450' to 3030'. I 6. DST data, perforating data, shows of H2S, miscellaneous data N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N GTE-- R eP"or~;n~%~o,~' is re%u i'red fof'--~-r %ach calendar month, regardless of the statu sLfope'"rations, and must eb/e filed '~n/dupllcate with the Alaska Oil and Gas/~onserv~rfCommission by the 15th of the succeeding month, unless otherwise directed· Form 10-404 HILL/MR119 Submit in duplicate 2B-8 DRILLING HISTORY NU 20" hydril and diverter. Spudded well @0915 hrs on 2/21/84. Drld 12-¼" hole to 3045. Ran 70 jts 9-5/8" 36# J-55 HFERW BTC csg w/shoe @ 3030. Cmtd 9-5/8" csg w/700 sxs Permafrost "E" and 250 sxs Permafrost "C". Bumped w/1500 psi - ok. ND 20" hydril & diverter. Instld 9-5/8" packoff. NU BOPE and tstd to 3000 psi - ok. Tstd csg to 1500 psi -ok. Drld FC and cmt. Tested csg to 1500 psi - ok. Drld FS and 10' new form. Tstd form to 12.5 ppg - EMW - ok. Drld 8½" hole to 7450. Ran logs DIL/SFL/GR/SP/FDC/CNL/CAL f/7450' to 3030'. Cont drlg 8½" hole to 7500'TD as of 2/27/84. Ran 172 jts 7" 26# J-55 HFERW BTC csg w/shoe @ 7500. Cmtd 7" csg w/250 sxs class "G". Bumped plug and tstd csg to 3000 psi - ok. ND BOPE. Instld 7" packoff and tstd to 3000 psi - ok. Displ fluid from top of well. Performed Arctic pack using 250 sxs of Permafrost "C" and 58 BBLS Arctic Pack. Secured well and released rig @ 0900 hrs on 2/28/84. DH105 3/14/84 /±h ARCO Alaska, Ir Post Offic= ~ox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 February 16, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2B-8 Dear Mr. Chatterton' Enclosed is a Sundry Notice for the subject well. complete this well with our workover rig. We expect to start this work on April 27, 1984. questions, please call me at 263-4970. Sincerely, Area Drilling Engineer JBK/JG'tw GRU6/L06 Enclosures We propose to If you have any AI.=o,~,3 Oil &. Gas C~ns. Commission ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~ STATE OF ALASKA ---. ALASi OILAND GAS CONSERVATION )MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] 2. Name 9f Operator 7. Permit No. ARCO Alaska, Inc. 84-26 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21079 OTHER 4. Location of Well Surface: 682' FSL, 553' FEL, Sec.19, T11N, RgE, UN 5. Elevation in feet (indicate KB, DF, etc.) 127' RKB 12. I 6. Lease Designation and Serial No. ADL 25656 ALK 2582 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 2B-8 11. Field and Pool Kuparuk River Field 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) Perforate ~] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other ~ Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) [] Altering Casing [] [] Abandonment [] [] Other [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc., proposes to complete this well with the Westward Well Service Rig #1. The procedure be as follows: 1) A mast truck will be utilized to run the CBL/VDL/GR and Gyro. 2) The rig will be moved on location; the BOPE will be nippled up and tested. 3) Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. 4) The well will be completed with 3-1/2", 9.2#/ft, J-55, BTC tubing. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. The BOP equipment will be pressure tested weekly and operationally tested each trip. A non-freezing fluid will be left .in all uncemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. Th~ subsurface safety valve will be installed and tested upon conclusion of the job. Estimated Start: April 27, 1984 on Form NoJ~-~-~ Dated 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Conditio~ns of Ap~val, if any: Approved Date Approved by COMMISSIONER _ Returned .... By Order of the Commission Date Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Form 10-403 Rev. 7-1-80 GRU6/SN03 KUPARUK ENGINEERING Date: Well Name: Transmittal Log Date Run # DISTRIBUTION NSK Operation Blueline Dr ill lng Bluel ine Geology BI/Se/Film R&D Blueline D&M Blueline s~ F.G. Baker Blueline D.B. Schafer Blueline Sign & return the attached copy as receipt o:f dat~', ~_.;~, .~" '- /.-? .s . i...I...~:.,...~.....::~?... ?:.; ~: ~.,-,.-~~ urn to: ARCO ALASKA, INC. ATTN: D. Fay ALLISON ATO-1115B P.0. Box 100360 Anchorage, AK 99510 M EMORA,, -DUM TO: FROM: State of Alaska ALASKA OIL ANqD GAS CONSERVATION COPR~ISSION C ,, ~on ~ DATE: Chai~Nh--~ Lonnie C. Smith Co~s sio~er TELEPHONE NO: Edgar W. Sipple, Jr ~ SUBJECT: Petrole~ Inspector~ February 28, 1984 51.15 Witness BOPE Test on ARCO's Kuparuk 2B-8, Sec. 19, TllN,R9E,UM, Permit No. 84-26, Doyon Rig 9. Thursday, February 23, 1984: I left ARCO's DS 12-27 (subject of ~n0ther rep0~t) and'"d~OVe to ARCO's Kuparuk 2B-8 to witness a BOPE test .on Doyon Rig 9. The drilling contractor was in the process of nippling up. The ambient temperature was -40°F with 8 mph winds. The BOPE test commenced at 11:45 pm and was concluded at 1:45 am. There were no failures. i filled out the A.O.G.C.C. BOPE inspection report which is attached to this report. In summary, I witnessed the BOPE test on ARCO's 2B-8, Doyon Rig 9. Attachment 02-00IA(Rev. 10/79) ~ . ~ -~"~ ~&G .~4 .4/80 STATE OF' A!,ASKA ALAS?b\ OIL & GAS CONSERVATION COHMISSIO~ B.O.P.E. Inspection Report Location: Sec 1¢ Drilling Contractor TUN ~9¢ ~_ t~ Rig #__ Representative ~¢~ Casing Set Representat ivy. Location, General Well Sign General Housekeeping Reserve pit Rig BOPE S~j~ . Ann ~lar r ter Pipe Rams BI/nd R~ms ~oke t~ne Valves ~.c.~. ~ve, Kill Line Valves ~e=k Va~e ACCU~%Ui~\TO R S'YS TI:2.1 Full Charge Pressure ~OOO ps.ig Pressure After Closure } ~7~ psig 200 psig Above Precharge Attained: Omin 3~_sec Full~ Charge Pressure Attained: ~min ~sec Cqntrols: Hasler ~ ~¢~r ~ ~~ Remote O~ Blinds switch cover ~ Test Pressure -. Kelly. an.d Floor Sa~fpet¥ Valves - - / t~0o !IUpper' Kelly ~/~ Test Pressure ~~ Lower Kelly ~)~ ~'"Test Pressure ~oo~ Ball Type ~/~/ Test Pressure ~O~o Inside BOP ~/~/Test Pressure ~0~o Choke Manifold ~~est Pressure ~;o. Valves No. flanges Adjustable Chokes / ,~.~ llydrauically operated choke . Test Time /'est Results: Failures ]tepair or Replacement of failed equipment to be made within Inspector/Commission office notified. / Distribution orig.' - AC&GCC cc - Operator cc - SOpervisor Inspcctor~ February 15, 1984 ~r. Jeffrey B. Kewin Area Drt!l~ng Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510 Re--. Kuparuk River Unit 2B-8 ARCO Alaskan.s, Inc. Permit No. 84-26 Sur. Loc. 682'FSL, 553'FEL, Sec. 19, TllN, RgE, 19f. Btmhole Loc. !428'Fl,~L, 3921'FEL, Sec. 30, TllM, RgE, UM. Dear Mr. g_ewin; Enclosed is the approved application for permit to drill the above referenced well. If coring is-conducted, a one cubic inch chip from each foot of recovered core is renu!red. Samples of well cuttings and a m~td !og are not required. A continuous directional survey is required as Der 20 AAC 25.050(b)(5). If available, a tape co'raining t~e digitized log information shall be submitted on all logs for eopy{ng except experimental logs, velocity surveys -and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as i~ortant for the spawning or migration of anadromous fish- Operations in these areas are subject to AS 16.05.870 and the reg31!ations promulgated thereunder (Title 5, Alaska A~ministrattve Code). Prior to commencing operations 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 promulaated thereunder (Title 18, Alaska Adm!nlstrativa Code, ChaDter 70) and by th~ Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation'. To aid us in scheduling field work, please notify this office 74 hours prior to eo~enCing installation of the blowout prevention Jeffrey B. K~wln Kuparuk River Unit 2B-8 February 1.5, .1.084 e~uip~nt so .that a representative of the Commis.~ion may be ~r~esent to witness testing of the equipment before, the ~urface ~asing .~hoe is drilled. ~ere a diverter 8ymtem is requ~.red, 9i~ame a!~o notify this office ~4 hour~ prior to co~encinK bafore driI!inS below the ~hoe of the conductor ~ipe. In. the ev~t of suspension or abandovanent, please give this office adequate advance p. ottficat~on so that we may have m witnezs present. Very truly yours, ,.. r,- V. Chatterton B~ O~D~P, OF ~H~ GO~~$~0.~ Ch~i~n of " Alaska Oil and Gas Con~e~mtion Co, ismS. on EneloaUr~ cc~ Department of Fish & Game, Habitat Sect,.on w/o encl. Department. of F-,~w{.ronment~! Conservation w/o enc!. ARCO Alaska, Inc. ~'~ Post Office B~,_ I00360 Anchorage, Alaska 99510 . Telephone 907 276 1215 February 6, 1984 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2B-8 Dear Mr. Chatterton: Enclosed are: o An application for Permit to Drill Kuparuk 2B-8, along with a $100 application fee o Diagrams showing the proposed horizontal and vertical projections of the wellbore o A proximity plat ° A diagram and description of the surface hole diverter system o A diagram and description of the BOP equipment Since we estimate spudding this well on February 25, 1984, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, J. B. Kewin/ Area Drillilng Engineer JBK/JG5/L159-tw Attachments ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA o,- AND GAS CONSERVATION COt,,,,vllSSION RERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN 1 b. Type of well EXPLORATORY [] DEVELOPMENT OIL 00( DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE [~]X MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, Alaska 99510 4. Location of well at Surface 682' FSL, 553' FEL, Sec.19, TllN, R9E, UH FEB s 0 i984 At top of proposed producing interval 1279' FNL, 3683' FEL, Sec.30, T11N, RgE, UM -',.~r.~. 0il ' At total depth 1~28' FNL~ 3921' FEL, Sec.30, T11N~ RgE~ UH 5. Elevation in feet (indicate KB, DF etc.) RKB 127', Pad 91' 6. Lease designation and serial no. ADL 25656 ALK 2582 9. Unit or lease name ,,I1'-"/"~,".-' g ~i'~,'~ 10. Well number 2B-8 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 30 mi. NW of Deadhorse miles 1056 feet 2B-7 well 60' ~ surface feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 7727' MD, 6383'TVD feet 2485+ 02/25/84 19. If deviated (see 20 AAC 25.050) I KICK OFF POINT 750 feet. MAXIMUM HOLE ANGLE 39 o I 21 20. Anticipated pressures 2769 (see 20 AAC 25.035 (c) (2) B182 psig@ RO°F Surface psig@ 6_?27, ft. TD (TVD) Proposed Casing, Liner and Cementing Program sIz Hole ~4" 2-1/4" ~-1/2" Casing Weight 16" 65.5# 9-5/8" 7" 36.0# 26.0# 22. Describe proposed program: CASING AND LINER Grade I CouplingJ H- 0 / J-55/HF-rRW BTC -SS/HF-r w BTC Length SETTING DEPTH MD TOP TVD 80 36' I 36' I 2994 35 ' 35 ' I I 33' I 33' 7694' MD BOTTOM TVD 110' 110' 3029'I 2716' I 7727'16383' I I QUANTITY OF CEMENT (include stage data) ±200 cf 748 sx Permafrost E & 250 sx Permafrost C 300 sx Class G ARCO Alaska, inc., proposes to drill a Kuparuk River Field development well to approximately 7727'MD (6383'TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 13-5/8", 5000 psi, RSRRA 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 2769 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. Completion operations with the workover rig will be covered under a separate sundry notice. 2B-8 will be 60' away from 2B-7 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. SIGNED~~ / /~~~/ p~. J.j~J~ ~_~TITLE Area Drilling Engineer DATE ~ /~/ The space below'for~0mm~-on uy ' f CONDITIONS OF APPROVAL Samples required []YES ~J,.N o Permit number APPROVED BY Form 10401 GRU5/PD38 Mud log required Directional Survey required APl number []YES ~NO ~YES DNO 50- O L~ - % ~ o 7~' Approval date ,,,,"'"'"'~ / ~ / ~4 SEE COVER LETTER FOR OTHER REQUIREMENTS DATE F~_hr~,ary 15, ,COMMISSIONER by order of the Commission 1984 Submit in triplicate .... T ........ t ..... ~ .............. I ..... ', . - i - --_ _!:. ~ =_~ ....... ~ ..... ~ ~ ~ , _ ~ I~ Al &~V~_ ~ I ..... . - -~ ~ ~ ~ .... :--~ ................ ~ ........ ~ ....... u~ ~ : ~ _--_ = ~ ........ 4 ..................... t ........ ': ...... - ~i~,~i[,~ ~U~_ ~.,~,, ~, ~ ., ~,~-- ~ - - ~ -- ---~ ............ t ........... , ........... I ~~ .... '-~ --~----- ~- :~ -; ~' z .......... ~ ....... ~I ....... ::.~ ' ' - - - ~'~ ............... :~ .... ~ ' :~ / I .... :ff ...................... ~-: .... x~ - ........... ~ ....... ~ ~ . ' , --~ . _ . ~ -. .... 4 .......... ~ ..... ~-,., .... _ I ........... i ..... ~ ~ 'T ~ ......... ...... L ; ........ - i ....... ! ..... I ............ ~ ............ i ........ ' I !-- I , ~ , I · i I ' ...... ~ .......... I ...... ~ .... ~ ' ~ :~___ -----i- ~: .: _._ ~: ..... ~ ....... ~ .... , ~.: ~ t ~--~-- :~:_~ ~-~ .............. ! ......... ~ ....... I' ' L -4 ~ ~ ---~ .................... ~ ..... ~ ...... · L ......... 4 ....... I ............... ; ~ ! ....... i ~ ~ [ _ . : . ~ :. ~ ....................... ~ ............... ~: i2~ i~A~ ~-~.~-~~ ~-~' ~ ~g~ ~.~=- ~ ~ ~7 ~EP~?~ ~ ' -~- ..................... 1 -~ ...... 4~ ~-~ :--:i_:--' :-:-. ......................................... .......... ............. , ........... , ...... ~ :~ - : , . - ' :::::::::::::::::: :::::::: ::::: ' : ' ~ _. ~ ~ - . :-:~-:::::I::-:':'-::::!' "t' ~ ' I ~ ~ , _.~ ................. i ..... 1:::~: :iii ,:: 111 .... ~ .... ~ ~: . ......... +__ _ ~-~:~ ......... : ....... ,,. . :; :'-:: --- :~- .- : -%:'. -T7-::::::!:::::--~::::;:;t':::;:::::: ;':::-- ~ ; : ......... x ..... 1 .... ~ ...... ~ ............ ~ ....... ' '- l'' , ~ ......... ~ ..... : ........ : ......... , .... ~ .... ~ ..... i ..... '~ ~ .... ~ k-:-:~ ~-t ,,~-4--:-.i-::::~ ::: :::i' : ~-: - :- . - ~ .......... ~:_:~ :_: ::_ _j_ .: ......... ~ .... ~... 1 ....... .............. ::::::::::::::::::::::: :::: : - :-: :' p '(9. Surface DiveY'~'r System 1. 16" Bradenhead. 2. 16" x'20" 2000 psi double studded adapter. 3. 20" 2000 psi drilling spool w/lO" side outlets. 4. 10" ball valves, hyraulically actuated, w/lO" lines to reserve pit. Valves to open automati- cally upon closure of annular preventer. 5. 20" 2000 psi annular preventer. 6. -20" .bell .nipple. 16" Conductor that gas or fluid flow to surface is · detected. If necessary, manually over- ride and close ball valve to upwind diverter line. Do not. shut in well under any circumstances. 3~ Close annular preventer in the event Maintenance & Operatign ~ 1. Upon initial installation close annular ! preventer and verify that ball valves ! ' have opened properly. ' · ! 2. Close annular preventer and blow air ~__ . through diverter lines every 12 hours. .-< · [ . _ : BLIND RRHS -. ._ ) __) . . PIPE RRHS 13-5/8" 5000 PSI 'RSRRA BOP STAC:< DR-ILLIN~ _SPOOL ~ .-~' ) . ( P i P£' R HS . 'S ( 1. 16" Bradenhead 2. 15" 2000 PSI x i0" 3353 ?SI c~sing head 3. lO" 3000 PSI tubing 5a:d 4. 10" 3000 PSI x 13-5/5= 5000 PSI adapter spool -:' 5. 13-5/8" 5000 PSI pipe rams 6. 13-5/8" 5000 PSI drilling s-po31 w/choke and kill lines -- 7. 13-5/8" 5000 PSI pipe'rar~s- ... 8. 13-5/8" 5000 PS! blind rams -- 9. 13-5/8" 5000 PSI an~Jlar -' ' ' ACCL~-IULATOR CAPA£Illr TE_ST 1. C-IECK ~u',q) FILL ACCI$%q_kTOR -?~._SERN~3I]~ 'il3 L~"YEI] WIT4 HYD?AULIC ~ID. .. 2. ~S~ ~AT A~-~T~ PP~E I5 ~ NI~ 1500 PSI ~~ ~ ~ 3. ~S~YE TIHE Th~ C~E ~ t~;ITS S~~- ~.~L~ $;D RECO2~ ~ T~Z ~ ~~ ~IN- '. F~ OFF. 4. ~ ON I$~C ~T. ~ A~E~$~ L~IT IS 45 SE~N~ ~I~ ~LME ~ l~ PSI P~NI~ PP~SU~. - 13-5/$' BOP STA...T.( TEST 5. 6. 7. 8. 13. 14. o_ 15. 1. FILL BOP STACK NJD ¥~%NIFOLD l~I~-l( ¢.~-315 ~.A~ED. P~D~E~INE DEPT~ T~T h'IR S~T AND S~T IN ~~D. ~N SC~S IN H~. ~E ~'ClU~. PREN~R ~D ~ Y~V~ ON ~XIFOLD. T~T ALL C~NENT5 TO ~ lO MIID~S. INC~E PRESSU2~ TO 1~ lO MINUTES. BLEED TO ~0 ~SI. ~D; 'N~U~R P~F~, ~;D ~E PIPE I~E-PR~su~ TO ~ ~I' ~;D B~ED ~'NST~] P~b~ ~' ZERO Y$~VE ~iD Z~O PSI ~:~H- TO Z~RO PSI. - 9. ~ TOP S~ OF PIPE ~ S~ ~ PIPE ~Nv~. lO. '~ "' ¢ HI!~T~. B~ED TO Z~ 2SI. ll. ~J; BO~OM S~ OF PIPE ~. ~ 21D TEST TO 3~ ~I F~ 10 B~ED TO ZERO PSI. lZ. ~{ BLIND P~'tS ~:D P~~ ~ ~'IIFOLD ~D LI~ ~T ~(DPIPE Y~Y~ TO ~ ~I. T~ ~Y ~ ~O l~I~ P~ TEST IllF~'~TI~ T~T FO~4 SIGN ~D S~ TO ~I~ YI~R. o. .-. .., . . . . .- · ARCO Alaska, Irt'~'~ - Post Office ~ox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 February 1, 1984 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plat - 2B Pad - Wells 5-12 Dear Elaine' Enclosed is an as-built location plat for the subject wells. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG5/L154' tw Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AS_- BUILT LOCATIONS . WELL 5 = 5 954 664.79 Lat. 70°17' 14.4884" X= 508 166.01 Long. 149o56'02.059" I 479 FEL 519 FSL EL. 91.O',O.G. 87.0' ~0 WELL 6 Y = 5 954719.50 Lot. 70°17'15.02-49'' 504 F"EL, 573'F'SL EL. 91.0 ~ O.G. 8'7.2' WELL 7 Y'- 5 954 773.92_ Lat. 70°17'15.5623'' X-- 508 116.16 Long. 149056'03.508'' 52.8 FEL,628 FSL EL. 91.1 ', O.G. 8?.0' WELL 8 Y-- 5 954 82_8.53 Lot. 70°17'16.0998'' X= 508 091.2.7 Long. 149°§6'04.232-'' 553 FEL,682- FSL EL. 91.O',O.G. 87.0' WELL 9 Y: 5 955 ;:528.86 Lnt. 70°17'2-1.0234" X: 507 86:5.26 Long. 149°56'10.86i" 779 FEL, 1183 FSL EL. 89.4',0.G. 85.5' WELL !0 Y: 5 955 383.54 Lat. 70°17'21.5614'' X= 507 8:38.34 Long. 149°56'11.585" 19 80;5 FEL, I?-38 FSL EL. 89.4',O.G. 85.0' 30 29 .~'~. WELL !1 Y=5955458.~1 Lot. 70°lT'22.0985'' X= 507 813.47 Long. 149°56'12-308'' 82_8 FEL, 1292FSL EL. 89.5',O.G. 84.0' WELL. 12_ Y= 5 955 492.55 Lot. 70°17'22.634~'' X: 507 788.52 Long. 149°56'13.033'' 85'3 FEL,1347FSL EL. 89.5',O.G. 84.0' CONDUCTORS 5-12 ~ ~.~ ... ,\ ,, ~, ,2.2 ,, ~. .'-7' LOCATED IN PROTRACTED SECTION 19 ~..~'~/'40th TOWNSHIP II N., RANGE 9 E.~ UMIAT MERIDIAN. ~.~ ..... .,_ ,:.. ~,. :'~' '~.. ~.~,.,,,,~.,,,,,.~,,.,-, BASIS OF ELEVATION IS TBM ?_8 7 8~ ?.B 8 PER LHO &As5,~ ~,~' OAVI0 FiL;,Cgl I ~'~ BASIS OF LOCATION IS TEMPORARY MONUMENTS 28 NORTH ~ ..~.. ,,_ ,,~ ~...-..~ & 2_B SOUTH PER LHD ~ Assoc. ~,L~:,.'.~_! !i '.. ~.,;.~., ' .. :'" I,.'; ..... ;, "~ ~,"~,,:£,t'r.~"'L O.G. ELEV. BASED ON O.G CONTOURS PER STEARNS-ROGER . - ~,.,~%,~..,~.~..~...~..~,u .... DWG. NO. 88- 17_- 30?_0 REV. 3. , I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED 81 LICENSED TO PRACTICE LAND SURVEYING IN THE. STATE OF F UNDER MY DIRECT SUPERVISION 8~ THAT ALL DETAILS ARE CORRECT AS OF JANUARY 17, 1984. n , ~. [.~ ARCO Alaska, Inc. E ~E~C~,~" Kuparuk Project North Slope Drilling ;1nilCONDUCTOR AS. BUILT /, LOCATIONS ,, ~.X~ ~ "~ ~t~[r~' Date: danuary'17~1984 Scale: I =400' . 335 ,'~ III~IM~UI Draughtsman: ~ Dwg. no.:NSKg.OS. ZOP;I,I CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No; ITEM APPROVE DATE YES NO , , REMARKS (1) Fee (2) Loc (2 thru 8) (8) (3) Admin Z~7 .~.." ~Z0-'/,Y (g thru 11) '(10 and 11) (12 thru 20) (21 thru 24) (6) Add: 1. Is the pe~it fee attached ........................................ 2. Is well to be located in a defin;d pool ....................... ' ..... 3. Is well located proper distance from property line ............ . 4. Is well located proper distance from other wells ............... 5. Is sufficient undedicated acreage available in this pool ...... 6. Is well to be deviated and is well bore plat included ......... 7. Is operator the only affected party ........................... 8. Can pe~it be approved before ten-day wait .................... 5 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. Does operator have a bond in force .................................. ~_ Is a conservation order needed ...................................... ' !s administrative approval needed .............. ~. ................. .... Is conductor string provided ........... , ............ ~ ................ Is enough cement used to circulate on conductor and surface ..... Will cement tie in surface and intermediate or production strings Will cement cover all known productive horizons ................. . Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ....... ' ..... Is adequate well bore separation proposed ........................... ~ Is a diverter system required ...... ' .................. · ............... Are necessary diagrams of diverter and BOP equipment attached ....... Does BOPE have sufficient pressure rating - Test to.~.,~'F~5 psig .. Does the choke manifold comply w/API RP-53 (Feb.78) .................. ,. ,. Additional requirements .............................................. Additional Remarks: 0 ~--~0 Z Geology: Engi_D~r ing: HWK LCS JAL ~___~ - rev: 12/08/'83 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. LIS TAPE I.,VP Otf',W02 VE-qlF'ICA~'If!~ i, ISTING PAGE', ORIGIN : R~Fb NAMK :RE~L CONTIN~;~TION ~ :01 PREVIO~S REEf., COMMENT~ :REEl,, COMME~!TS ** TAP~ NE~DER ** SERV?CE NAME OATE :B4fO~t TAPE N~E )9019 CO~T)NUA?ION ~ :01 PRE'VTOUS T~PE : ********** MOF ********** ** FILE ~BADEN ** FI~E N~E :EDIT ,0~1 SERVtC~i WA~E : VERSIO~ ~ : DATE : ~AXI~UM t, ENG~H : 102~ PILE ~'¥P~ : PREVTOUS B'~LE : CN : ARCO ALASK~ TNC RANG: 9E TOW~: SMCT~ 19 STAT1 AL~$K~ UNIT TYPE CATE SIZE CODE 000 000 01,6 065 000 000 o04 065 000 000 O08, 065 000 000 002 065 000 000 004 065 000 000 002 065 000 000 008 065 o00 000 006 065 000 000 004 065 t, VP OlO.H02 VE~IFiCATI[')N L.TSTI'NG PAGE 2 WELL = 2B-8 FIELD : KI~PA~t.IK COIINTY ~ NORTH SY.~OP~C JOB }~IU},tBE~ AT ACC: 6~0~9 CASING = 9 6~5" - ~%IT $IZW. = 8,5" TYPE FI.,t..IID = [~6~; $~LIDS POLY}~ER DENSITY = lO.~X T.,~/G ~ = 2,430 [~ 7,~ DF VISCOSITY : 36.0 S R~F = 2,770 8 74 DF M = 10'o ~C = 2,280 (a 74 DF ~[~[]ID LOSS : 6,4 C~ ~N~ AT BHT = 1,286 ~ {46 DF [,VP OlO,~O? VE,q[w'1'CATIrl,,~ t~T$'T'I?'G PAGE , ~C~{LI~MBENG~TF~ LOGS ?NCLUDED WI'liN re!liS MAGNETIC TAPE: , * nUAb INDUCTIOM SPHERIC~L, LY FOCUSED b~G (DIL) * WO~,~AT]'.O~ I)F~NSITY Ct')~.~PENSATED LO~ (FDN) * CO~PENSATED NEUTRO~ LOG (F~N} , , , · · ~ ~ , ~ ~ · , , · ~ ~ · , , , · , , , ~ · , , , ** DATA WORM~T RFCORD ** ENTRY gI.,OCKS T¥ Pi'C SIZE ~.~ EPR CODE ENTRY 4 1 66 1 ~ 4 7~ 60 9 4 6B 0 1 6 6 0 DATt)~ SPECTFICaTIO~,~ ~UOCKS ~N~) SERVICE $~iRV1CE 1)NIT API AP1 API ~P! FtbE SIZE PRnCE$S SAwPLE REPR ID OI~DFR ~ [.,¢)G TYPE CLASS ~[ID NO, Lf~iVF..L CODE DEPT FT 0 0 0 0 0 4 0 1 6~ S F b U h I I,, 0 H ~i ~! 7 O 0 0 0 4 0 1 68 Ib~ ~) II., O~M 7 0 0 0 0 4 0 1 68 ILD DIL o H ~ 7 12 46 0 0 4 0 1 68 SP DIL ~V 7 1 0 0 0 4 0 1 68 GR DIL (~API 7 '~l. 32 0 0 4 0 1 68 NPHI Fi)~ PU 42 6~ 2 0 0 4 0 1 6B ~RHO FD~ C/C3 ~ 44 0 0 ~ a 0 1 6~ ~HOB FDN G/C3 42 35 1 0 0 4 0 I 68 NCNL FDN CPS ~%2 34 92 0 O 4 0 1 68 FCNL FDM CPS 42 34 ~3 0 0 4 0 1 68 CALl FDN TN a2 2~ 3 0 0 4 0 1 68 NRAT FDN 42 42 1 0 0 4 0 1 68 RNPA Fi)N 42 0 0 0 0 4 0 I 68 GR FDN CAP1 42 31 ~2 0 0 4 0 1 68 LVP nlO,g09 VERIFICA. TIO~: LISTI~.~G PAGE 4 DEPT 7449,0000 SF'LL) 3 SP -44.8125 GR 104 RHOB 2,3477 .,~I C m 1~ 2130 DEPT 7400,0000 SFI.Li 3 SP -2~ 4375 GR 104 HOB 2:7441 ~C~b 21 ]0 ~ R A'][' 3.31~4 ~ ~,IR A 3 DEPT 7300,0000 SFI.U 9 SP -36.4063 G~ 80 ~MOB 2,37~9 ~C~L 2~36 NRAT 2.6074 R{~RA 2 3203 oO000 .6738 ,1973 .56~5 .6309 ,8281 .4375 0000 '7227 D~PT 7200 0000 ~FL!J 5!2773 $~ -40:6875 R 97 1875 RHOB 2,39~6 ~.~C~!L 2376 0000 NRRT 2.~16,i ~PA 3 1973 DEPT 7100,00~0 SFLU 13, SP -46,0000 GR 72, RHOB 2.9609 NCML 2968. .)EP~ 7000,0000 SFI...U 13. SP -37,1562 aR 262, RHOB ~.6250 ~iC,Nb 1796. MR.AT 2.7969 r~ a 3. DEPT 6900.00n0 SP -3';,5625 GR 1.83. RHO~ 2.3 9R4 ~C~,II'., NRAT 3.4395 DEPT 6800 0000 SFI.,U SP '30:~531. CR 324, HOB -999,2500 ~CMb -999. ~R~T -999.2500 ~',,~ -999. OEPT 6700 0000 SFI_,U 4, ,aP -46 2813 C~ J,]4, RHOB -qgq ~500 ~l C M 1~,, -ogq, MRAT -999 2500 R~qPA -999. DEPT 6600,0000 SFLtl 5, SP -40,q375 CR 120, RHf3~ -999,~500 NCNb -999, MR.AT -q99.~500 Pt'~'~ -999. DEPT 6500, OOnO SF'¥~U 3. 5469 3125 00~0 8691, 2969 2500 0000 1055 34~8 3750 OOO0 5488 7256 OOOO 25OO ~500 0078 500 5OO .~148 · 250 25OO 4141, I h~~ NPHI FC~[, ~R ~P~I ~PHI FC~I,, ~!PHI FCNL G R IbM FCNL GR IL~4 ~'PHI FCNL GR IL~ NPHI FCNL NPH I I L N I~'CNL NPHI 2.3066 41,1621 579,5000 104,5625 2,8320 41.0156 586,5000 104.5625 7,7305 27.9785 894,5000 80.4375 4.2383 30,8105 743,0000 97,~875 9 4453 30 O293 1034 0000 72 31~5 ~,I172 30,9570 578,0000 262.2500 ~,8633 4[,6992 54.,5000 1_83,3750 ~.4717 '999,~500 '999.9500 3~4.0000 3.3125 -999.2500 -999.2~00 134.5000 .99~: 7773 25o 0 999. 2500 ~PO.i~50 3.3242 1 DRMO C:~LI ILO CAI, I TbD CAI.?I D R H 0 I b h CALl CALl ! LD DRHO CALl I LD D R H 0 CAI,I IhP OREO CALl ILO DRHO CALI 2,1660 0.2046 8,5000 2,8301 0 2373 7:9414 7,6094 0.0342 8,5234 4.0625 0 ~181 9922 8'0151 8.5859 3,8066 0.0479 8.4063 8.0')' 6 1,3750 -999,2500 8,7969 3.2070 -999,2500 9.6953 3,6309 -990.2500 9,3672 3.261 '; LVP OlO.HO? VEi{~IFI('h'~'!f~'d LTST!NG PAC, F~ 5 RP -45,5625 CR {~{R ~T -999.2500 R,~RA DEPT 64_(:2,0 000(~ SFLU Sp -.,4;5938 ~ RHOB .,.999, ~SmO '~CPJL NRA~ -999,2500 R {~ [-!/~ DEPT 6]00 0000 ~FLLJ SF -50i343~ RHOB -999 2500 NR~T -999 2500 RNRA D£PT 62_00 0000 SFLO $P -3626875 GR RHOB -990,2500 NCNL NRAT -999,~500 R~R~ DEPT 6100 0000 SFI, U SP -41~6563 GR RHOB -999,2500 NCS{L NRAT -999,~500 RNRA DEPT 6000 0000 8FI,U · $P -4,3,0938 ~HOB -~99,2500 NC~L gR~T -999.2500 DEPT 5900 0000 SFI.U SP -42i6563 G~ RHOB -099 ~500 NCN[, NRAT -99g,~500 RNRA DEPT 5800,0000 SFLU SP -54,~500 GR RHOB -999,~500 NC.NL NRAT -g99.~500 RNRA 9q,~500 -OOQ 2500 FCNL 5,3867 ILU 110,6250 NPH1 -999.2500 FCNI, -090.2500 ~R 4,05B6 ILM 135 5000 ~PHI -.099i 250() FCN~I, ,990 2500 C.,R i.7607 IBM ~45 3750 -q99[~500 FCN[. -999 2500 3 1465 IbM 1.07,0000 NPHI -090,2500 FCNL -999,2500 GR 3 0762 IL~ 105,06~5 ~PH! -999,~500 FCNL '999,~500 GR 3 9434 IL~ 93,6250 ~PN! -o99,2500 FCNL '999,2500 GR 3,5957 TG~ 123,6250 b!PHI -999,2500 FCNL -999,2500 GR $P -39, 688 GR 151,. 000 NPHI RHOB -ggg,~500 NC~L -999 2500 FCML NRAT 999, 500 R~RA -999' .25OO DEPT 5600,~000 SFLtl SP -4~, 500 GR RHOB -999,~500 HCNL NRAT -999,~500 R~!RA DEPT 5500,0000 SFI..U SP -4~,4375 ~R ~08 999,25¢)0 NCNL NRAT :090.2500 R~RA 2,0156 TL~ 1.10,2500 ~PNI 'ago,2500 FCNL -990,~500 ~R -999.2500 -099.2500 99.25o0 4.1836 -999.2500 -999.2500 110,6250 3.0434 -999,2500 -999,2500 135,5000 2.1484 :~99,25no 99,2500 45.3750 3.4277 -999,2500 -999,2500 !07,0000 3.1445 -999.2500 -999,~500 1.05.06~5 3.0645 ,2500 9.-],625O 3,259B -990.2500 -999.2500 123,6250 2,0938 -999,~500 -999 ,25,.0 -999.2500 2,0000 :999,2500 g9g.~500 1,6865 '999,~500 -999.~500 '099.~500 I bD 13 R }{ 0 CALl I D R h 0 CAI-, ,l IL5 D R tt 0 CALl DRMO C. A L I I L l> l LD D R F{ 0 C A L I DRHO I L D D R 1'10 Chili I L D CALI -99q.2500 10.~484 4,1445 '999,2500 8.9297 ~ 8105 -.o9~i2500 16 6328 2,1699 -999,2500 9,8359 3,40~2 -099,2500 9,8125 3,0879 -999,2500 9,0156 2,9395 -999,2500 9.5078 3.~2285 -999,2500 10,7734 2,'1.211 -999'2500 -999.2500 2,0586 -999,2500 '999,2500 .1,~377 -999, 500 '999,2500 I.,VP OlO,N02. VERIFIOATI('~k~ I:TSTING PAGE 6 DEPT 5300,0000 SFLt.i SP -48,9375 GR RNOB -999 2500 NCEL NRAT -999:2500 RNRA DEPT 5200,0000 SP -45.R125 RHOB 990 2500 NCNb DEPT 5~.00.00~0 SP -47,7500 RHRB -999,2500 NRA? -999,~500 3 125, '999. -99~, 2 107~ :999. 999. 156. -999. -999, OE~T 5000,0000 SFLU 3, SP -44.5938 GR 96. RHOB -999 2500 NCNL -999. ~RAT -999:~50o R~RA -999. DEPT 4900 0000 8FI. U SP -46,4688 GR WHO8 -999,~500 NCNL, NR~:T -999.2500 RNRA OEPT 4800 0000 SFLLI SP -43,a75o ~ HOB -999.~500 ~ICNL ~R~T -999.2500 RN~A DEPT 4700 O00O SWLU SP -42 9687 G~ ~HOB -999 2500 NCNL ~RAT -999 2500 ~N~ DEPT 4600,0000 SF'LU Sp -45,5938 RHOB -999.~500 NCNL NRaT -99q,2500 DEPT 4500,0000 SP -49,4688 RHOB -999,2500 NRAT -999.~500 DEPT 4400,0000 SiP -51.,0938 RHOB -999,~500 NCNL NRAT -999.25o0 2 110. -999, 2 '999, 2 95, -999. 2 1 o 6 '999' , -a9g, 2 -999, '999, ? -999. -q99o 7'134 7500 2500 2500 3926 t250 25OO 7500 8730 0O25 2500 2500 4238 3750 2500 2500 2891 5625 2500 250o 4141 8125 2500 2500 4258 5000 2500 2500 7012 7500 2500 25OO 4:609 5000 5OO 66al 6875 2500 2500 5098 8125 2500 25OO NPH ! FCNb ~R FCN[: G~ ~:PHI FCNL T ~,;PH l FCNL CR T ][., I~ N P H I FCNL GR NPHI FCNb NPH1 F'CNL I .[,,g NPHI GR ~,,~ P H I FCN[,, GR OR FCNL GR 2.8!05 -~99.2500 -999.2500 -999.2500 3,4238 -999.2500 -999,2500 -999.25n0 2,845'? -999.2500 -999.2500 -999.2500 2,5919 -999.2500 -999.2500 -~99.2500 2.9902 '999.2500 -999.2500 -999,2500 2,4453 -999.2500 -999,2500 -99:9.2500 2,42'38 -99~,2500 -999.~500 -999. 500 2,7168 '999,2500 '999,2500 -999.2500 2.5469 -~99,2500 -999,2500 -999.2500 2.6406 -.999,7500 -9ggo~LO0 -999.~500 2.5254 -999.2500 -999.2500 -999.2500 ~LD DRHO CALl I [, D CA[.,I DR HO CA.~,I CALI ILD DRNO CALl ! LD ORHO C A [.: I ILO D R H 0 CAhI I ,t, CAI.,I I LD CA[,,I I bO DRHO I: b P D R H ~'] 2 8535 -999:2500 -999.2500 3 4434 -.099:2500 -999,2500 2 8848 -099~2500 -999,2500 2,6387 '999.2500 -999,2500 3,0449 -999,2500 -999,2500 2 4473 -999 .2500 -999 2500 2,~531 -999, 500 '999,2500 2,7227 -999,2500 -999,2500 2,6074 ~99,~2500 '-999~2500 2.6855 -999e~500 2,6211 -999.2500 -999.2500 LvP 01o,ho~ vgRIFIC~"~In.',~ LI.$'~ING PAGE OBPT 4100 0000 SFLU SP -52:0000 GR RHOB -999,2500 ~CNb NR~T -999.2500 RNRA D.EPT 4~00,0000 SFLU SP 54,2187 GR RHOB -999 2500 MCNL NRAT -999:2500 RNRA. DEPT 3900,0000 SFT.U SP -52.1.250 ~R RHOB -999,~500 NCF~b NRAT -999,2500 RNRA DEPT 3800 0000 MFLU SP -52:i562 RHOB '999.~500 NCNL NR~T -999,~500 ~E.P~ 3 00,0000 SP 53,3438 GA RHO'B -999 2500 MCN[, NRAT .~500 DEPT 3600.0000 SFLU RHOB -999:2500 NCNL ~RAT -999.~500 R~RA DEPT 3500.0000 SFI.,'0 SP -53.5625 GR RHOB -990.~500 NCNL NRAT -999.~500 RNRA OF, PT 34.0O. 0000 P 56..406~ 3 : HOE} 999,~500 NRAT 999. ~5 )0 DEPT ~300.0000 SFLU SP -57.3125 OR RHO~ 990.~500 NCPb ~,5859 ILu 93.5625 t'.!PHI -999.2500 ~'CNI, -999.~500 ~R 2,8008 106,2500 -999.2500 FCNL -999.~500 2 6699 lb~ 101' ,2500 NPHI -99a.~500 FCNL -999,2500 G~ ~,9902 IbM 92,3750 ~PHI -999,2500 FCNL. -99~,~500 OR 89,1875 NPHI -n99,2500 FCNL -999.~500 ~R ' O' 5 66 2 ILM 87,0625 NP~I -q99.~500 FCNL -999,2500 UR 3 1914 IL~ 118,6875 -999,2500 FCNL '990,2500 3,2891 9375 NPH! 81,, ~'0 -999'25 o 'FCNb o99,, ~50(') GR 3,5215 I b 1~'~- 63,7500 NPHI 099,~500 FCNL .%999'2500 cR 500 ~JPHI -9~9,2500 FCNL -099, ~500 aR 5,5352 lI,.,~! 75,0625 NPH'[ -999.~500 FCNL 2,7324 -999'2500 -999.9500 -999.2500 2.8691 -999.2500 -999.2500 -999.2500 2,6805 -999,2500 -999.2500 '999,2500 3,5527 -999,2500 -999.2500 '999.2500 3.3164 -999.2500 -999 -999: 500 4 3398 -999!2500 -999 2500 -999,~500 3,3086 -999.25O0 -~99.~500 -999,2500 3,8164 -999,25OO -99~,2500 99 .~500 4,1.562 '999,2500 -999,~500 '999,2500 4.~133 -999,..500 -999,2500 -999.~500 5o0898 -999.2500 -999.2500 l L D DR.HO CAL! I LD D R H 0 CALl T. LD CALl I bO DR.L. CAt, I DRHO CA[,'I DRHO CAI.,I I bP DRMO CALI I hD C A I., I I hD ) [ RicO II.,D OR}qO CALI ,1[ bD OR. HO CALl 2,8730 'g99,2500 'g99,2500 2,9492 -099,2500 -999.2500 2,8457 ~,999,2500 999,2500 3,7285 -099,2500 -999,2500 ,] 4570 -o992zsoo -999.25OO 4.6250 %99 , 2560 999' ,2500 3.~6~5 -999, ~00 -99o. i oo -999 O0 -g 99 2500 3,8926 999,.~5~00 ~9q9., 00 :qgg '371'I ,2500 999.2500 5,5234 '999, ~5'00 -999'.~500 LYP OIO,H09_ VER'IFICAT.£O,~ L, TSTI~G PAGE -999.2500 DEPT 3~00.0000 SF!.,U SP 57,5938 GR RHOB -99g,~sno NCNb WRAT -~99.7500 R~RA 5.5977 B6,alP5 ~PHI -999,~50(i FCNL -999.~500 DEPT 3100 0000 SFLU 7 53Ol IbM SP -61i7813 G~ 8~:0000 biPMl RHOB -999 ~500 NC~![., -9q9,2500 FCNI., ~R~T -99q,2500 a~,iR~ -999.2500 G~ DEPT 3007.5000 Sp -18.32~1 RHOB -99~,2500 MRAT -g9~.7500 ~i~iPA 2000,0000 63,6250 -qgg,2500 -99~,~500 GR ** FILE TRAILER ** ~I£,E NAME SERVICE NAME : ~ATE ~ MAXIMU~ LE~GT!.{ : 1.0~4 FILE TYPE MEXT F?bE -~99,~500 5.5469 -99g.2500 8.~203 -9~9.2500 DRHO -990.2500 CALl -o99,~500 2000.0000 -999,2500 DRHO -O~g.?500 -99g.~500 5 6602 -99912500 -g99.2500 8.7266 -999,2500 -999.2500 10,2714 -n99,2500 -~99,2500 ** TAPF TRAIl, Em ** SERVICE NAME :EDIT DATE :B4/03/ 3 ORIGTN ~0000 TAPE MA,~E :9019 CONTINU~TIOm # NEXT TAP~ NAME : COMMENTS :T~PE CO~ENTS CONTINUATION NEXT REEl,