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185-107
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. You don't often get email from jaime.bronga@conocophillips.com. Learn why this is important From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: AOGCC Notification: KRU 2Z-14 (PTD 185-107) Date:Monday, April 21, 2025 9:24:13 AM Attachments:AnnComm Surveillance TIO for 2Z-14.pdf From: Bronga, Jaime <Jaime.Bronga@conocophillips.com> Sent: Monday, April 21, 2025 8:47 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Automation, AK Wells <akwellsautomation@conocophillips.com>; Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: AOGCC Notification: KRU 2Z-14 (PTD 185-107) Well Name: 2Z-14 Facility: CPF2 PTD: 185-107 Well Type: Inj AA Number (if applicable): N/A Internal Waiver (Yes/No if applicable): N/A Type of Issue: IA Exceeded DNE Maximum Pressure (if applicable): 2900 Date of Occurrence (if applicable): 4/19/2025 Hi Chris, As reported last week KRU 2Z-14 (PTD 185-107) is a WAG injection well currently on MI injection. The IA pressure has been increasing, requiring a repeat bleed, indicating a possible integrity issue. Due to Phase 3 weather conditions, the drill site operator was not able to walk down the pad for 2 days and during this time IA pressure increased to 2900 psi, exceeding the Operating Pressure Limit of 2400 psi, before the operator had access to the pad and identified the high pressure. The IA pressure was bled down and the well was shut in. CPAI intends to WAG the well to water injection to monitor for integrity issues on water injection and conduct the diagnostic testing on water injection. The TIO plot, schematic, and bleed log is attached. Please let me know if you have any questions or disagree with the plan. Warmest regards, Jaime Bronga Well Integrity – CPF2 – ConocoPhillips Alaska Cell: 907-229-8282 2Z-14 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 2Z-14 2025-04-14 1900 950 -950 IA 2Z-14 2025-04-16 2350 1300 -1050 IA 2Z-14 2025-04-19 2900 1300 -1600 IA 2Z-14 2025-04-20 2200 1550 -650 IA 2Z-14 2025-04-20 2050 1450 -600 IA Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 8,044.0 2Z-14 6/11/2024 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Update tag depth 2Z-14 6/11/2024 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 1/13/2011 ninam Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 36.0 80.0 80.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 35.2 3,878.0 3,302.6 36.00 J-55 BTC PRODUCTION 7 6.28 32.6 8,277.7 6,300.4 26.00 J-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 32.6 Set Depth … 7,863.3 Set Depth … 6,031.0 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE-8rd ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 32.6 32.6 0.07 HANGER 8.000 FMC GEN III TUBING HANGER 3.500 1,822.1 1,790.2 28.48 SAFETY VLV 5.937 BAKER FVL SSSV (Locked open 7/27/94) BAKER FVL 2.810 7,409.8 5,713.2 44.89 GAS LIFT 5.960 MERLA TDPX MERLA TDPX 2.875 7,448.3 5,740.5 44.73 PBR 5.625 BAKER PBR BAKER 3.000 7,462.0 5,750.2 44.68 PACKER 6.151 BAKER FHL PACKER BAKER FHL 3.000 7,502.6 5,779.1 44.51 GAS LIFT 5.960 MERLA TDPX MERLA TDPX 2.875 7,573.2 5,829.6 44.29 GAS LIFT 5.960 MERLA TDPX MERLA TDPX 2.875 7,612.6 5,857.8 44.38 BLAST RINGS 4.500 CARBIDE BLAST RINGS (5) 2.867 7,789.7 5,981.4 47.19 BLAST JT 4.500 B.O.T STEEL BLAS JT 2.867 7,819.5 6,001.6 47.52 GAS LIFT 5.960 MERLA TDPX W/WI PACKING (Injection Mandrel is leaking) MERLA TDPX 2.875 7,838.9 6,014.6 47.67 LOCATOR 4.563 BAKER LOCATOR sub w/5' seals BAKER 3.000 7,839.7 6,015.2 47.68 PACKER 6.151 BAKER FB-1 PACKER BAKER FB-1 4.000 7,854.0 6,024.8 47.79 NIPPLE 4.520 CAMCO D NIPPLE no go CAMCO D 2.750 7,862.5 6,030.5 47.86 SOS 4.500 CAMCO SHEAR OUT CAMCO 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 7,790.0 5,981.6 47.20 PATCH TTS PARAGON II PATCH LOWER PACKER, MID ELEMENT @ 7833'; UPPER PACKER ASSEMBLY w/PACKER MID ELEMENT @ 7813.7' set 11/10/2006 11/10/2006 1.625 7,819.0 6,001.2 47.52 LEAK Leak below DV 3/4/2000 2.990 7,819.0 6,001.2 47.52 LEAK LEAK AT UPPER PACKER OF TUBING PATCH, VERY LITTLE FLOW TO A-SAND, UNABLE TO GET SPIN COUNTS IN 7" CASING DUE TO LOW FLOW -LEAK IN THE C-SAND SELECTIVE AT 7792' (INSIDE PATCH NEAR UPPER PACKER) 1/8/2016 1.650 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 7,409.8 5,713.2 44.89 1 GAS LIFT DMY T2 1 1/2 0.0 5/24/1990 WI Pkg 0.000 7,502.6 5,779.1 44.51 2 INJ HFCV RM 1 1/2 0.0 11/24/2014 0.250 7,573.2 5,829.6 44.29 3 INJ DMY RM 1 1/2 0.0 7/13/1985 0.000 7,819.5 6,001.6 47.52 4 INJ DMY RM 1 1/2 3/5/2000 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,622.0 7,728.0 5,864.5 5,939.0 UNIT D, C-4, C- 3, C-2, C-1, 2Z- 14 7/13/1985 12.0 IPERF 5 1/2" Schlumberger 7,775.0 7,784.0 5,971.4 5,977.5 UNIT B, 2Z-14 7/13/1985 12.0 IPERF 5 1/2" Schlumberger 7,921.0 7,928.0 6,069.6 6,074.2 A-5, 2Z-14 7/13/1985 4.0 IPERF 90° phasing; 4" Hyper Jet II 7,944.0 7,984.0 6,084.8 6,111.2 A-4, 2Z-14 7/13/1985 4.0 IPERF 90° phasing; 4" Hyper Jet II 8,016.0 8,025.0 6,132.1 6,138.0 A-3, 2Z-14 7/13/1985 4.0 IPERF 90° phasing; 4" Hyper Jet II 2Z-14, 6/13/2024 11:42:56 AM Vertical schematic (actual) PRODUCTION; 32.6-8,277.7 IPERF; 8,016.0-8,025.0 IPERF; 7,944.0-7,984.0 IPERF; 7,921.0-7,928.0 PACKER; 7,839.7 GAS LIFT; 7,819.5 LEAK; 7,819.0 LEAK; 7,819.0 PATCH; 7,790.0 IPERF; 7,775.0-7,784.0 IPERF; 7,622.0-7,728.0 GAS LIFT; 7,573.2 GAS LIFT; 7,502.6 PACKER; 7,462.0 GAS LIFT; 7,409.8 SURFACE; 35.2-3,878.0 SAFETY VLV; 1,822.1 CONDUCTOR; 36.0-80.0 KUP INJ KB-Grd (ft) 42.01 RR Date 6/29/1985 Other Elev… 2Z-14 ... TD Act Btm (ftKB) 8,305.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292136100 Wellbore Status INJ Max Angle & MD Incl (°) 50.15 MD (ftKB) 8,200.00 WELLNAME WELLBORE2Z-14 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: WRDP 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. You don't often get email from jaime.bronga@conocophillips.com. Learn why this is important From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: AOGCC Notification: KRU 2Z-14 (PTD: 185-107) High IA Pressure Date:Thursday, April 17, 2025 11:46:48 AM Attachments:AnnComm Surveillance TIO for 2Z-14.pdf From: Bronga, Jaime <Jaime.Bronga@conocophillips.com> Sent: Thursday, April 17, 2025 11:31 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Automation, AK Wells <akwellsautomation@conocophillips.com>; Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: AOGCC Notification: KRU 2Z-14 (PTD: 185-107) High IA Pressure Well Name: 2Z-14 Facility: CPF2 PTD: 158-107 Well Type: Inj AA Number (if applicable): N/A Internal Waiver (Yes/No if applicable): No Type of Issue: Suspect Integrity Maximum Pressure (if applicable): N/A Date of Occurrence (if applicable): N/A Hi Chris, KRU 2Z-14 (PTD 185-107) is a WAG injection well currently on MI injection. The IA pressure has been increasing, requiring a repeat bleed, indicating a possible integrity issue. CPAI intends to start integrity monitoring and diagnostics to investigate the IA integrity with the well online on gas injection and then on water injection. Please let me know if you have any questions or disagree with the plan. The TIO plot, bleed log, and schematic are attached. Warmest regards, Jaime Bronga Well Integrity – CPF2 – ConocoPhillips Alaska Cell: 907-229-8282 2Z-14 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 2Z-14 2025-04-14 1900 950 -950 IA 2Z-14 2025-04-16 2350 1300 -1050 IA Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 8,044.0 2Z-14 6/11/2024 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Update tag depth 2Z-14 6/11/2024 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 1/13/2011 ninam Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 36.0 80.0 80.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 35.2 3,878.0 3,302.6 36.00 J-55 BTC PRODUCTION 7 6.28 32.6 8,277.7 6,300.4 26.00 J-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 32.6 Set Depth … 7,863.3 Set Depth … 6,031.0 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE-8rd ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 32.6 32.6 0.07 HANGER 8.000 FMC GEN III TUBING HANGER 3.500 1,822.1 1,790.2 28.48 SAFETY VLV 5.937 BAKER FVL SSSV (Locked open 7/27/94) BAKER FVL 2.810 7,409.8 5,713.2 44.89 GAS LIFT 5.960 MERLA TDPX MERLA TDPX 2.875 7,448.3 5,740.5 44.73 PBR 5.625 BAKER PBR BAKER 3.000 7,462.0 5,750.2 44.68 PACKER 6.151 BAKER FHL PACKER BAKER FHL 3.000 7,502.6 5,779.1 44.51 GAS LIFT 5.960 MERLA TDPX MERLA TDPX 2.875 7,573.2 5,829.6 44.29 GAS LIFT 5.960 MERLA TDPX MERLA TDPX 2.875 7,612.6 5,857.8 44.38 BLAST RINGS 4.500 CARBIDE BLAST RINGS (5) 2.867 7,789.7 5,981.4 47.19 BLAST JT 4.500 B.O.T STEEL BLAS JT 2.867 7,819.5 6,001.6 47.52 GAS LIFT 5.960 MERLA TDPX W/WI PACKING (Injection Mandrel is leaking) MERLA TDPX 2.875 7,838.9 6,014.6 47.67 LOCATOR 4.563 BAKER LOCATOR sub w/5' seals BAKER 3.000 7,839.7 6,015.2 47.68 PACKER 6.151 BAKER FB-1 PACKER BAKER FB-1 4.000 7,854.0 6,024.8 47.79 NIPPLE 4.520 CAMCO D NIPPLE no go CAMCO D 2.750 7,862.5 6,030.5 47.86 SOS 4.500 CAMCO SHEAR OUT CAMCO 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 7,790.0 5,981.6 47.20 PATCH TTS PARAGON II PATCH LOWER PACKER, MID ELEMENT @ 7833'; UPPER PACKER ASSEMBLY w/PACKER MID ELEMENT @ 7813.7' set 11/10/2006 11/10/2006 1.625 7,819.0 6,001.2 47.52 LEAK Leak below DV 3/4/2000 2.990 7,819.0 6,001.2 47.52 LEAK LEAK AT UPPER PACKER OF TUBING PATCH, VERY LITTLE FLOW TO A-SAND, UNABLE TO GET SPIN COUNTS IN 7" CASING DUE TO LOW FLOW -LEAK IN THE C-SAND SELECTIVE AT 7792' (INSIDE PATCH NEAR UPPER PACKER) 1/8/2016 1.650 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 7,409.8 5,713.2 44.89 1 GAS LIFT DMY T2 1 1/2 0.0 5/24/1990 WI Pkg 0.000 7,502.6 5,779.1 44.51 2 INJ HFCV RM 1 1/2 0.0 11/24/2014 0.250 7,573.2 5,829.6 44.29 3 INJ DMY RM 1 1/2 0.0 7/13/1985 0.000 7,819.5 6,001.6 47.52 4 INJ DMY RM 1 1/2 3/5/2000 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,622.0 7,728.0 5,864.5 5,939.0 UNIT D, C-4, C- 3, C-2, C-1, 2Z- 14 7/13/1985 12.0 IPERF 5 1/2" Schlumberger 7,775.0 7,784.0 5,971.4 5,977.5 UNIT B, 2Z-14 7/13/1985 12.0 IPERF 5 1/2" Schlumberger 7,921.0 7,928.0 6,069.6 6,074.2 A-5, 2Z-14 7/13/1985 4.0 IPERF 90° phasing; 4" Hyper Jet II 7,944.0 7,984.0 6,084.8 6,111.2 A-4, 2Z-14 7/13/1985 4.0 IPERF 90° phasing; 4" Hyper Jet II 8,016.0 8,025.0 6,132.1 6,138.0 A-3, 2Z-14 7/13/1985 4.0 IPERF 90° phasing; 4" Hyper Jet II 2Z-14, 6/13/2024 11:42:56 AM Vertical schematic (actual) PRODUCTION; 32.6-8,277.7 IPERF; 8,016.0-8,025.0 IPERF; 7,944.0-7,984.0 IPERF; 7,921.0-7,928.0 PACKER; 7,839.7 GAS LIFT; 7,819.5 LEAK; 7,819.0 LEAK; 7,819.0 PATCH; 7,790.0 IPERF; 7,775.0-7,784.0 IPERF; 7,622.0-7,728.0 GAS LIFT; 7,573.2 GAS LIFT; 7,502.6 PACKER; 7,462.0 GAS LIFT; 7,409.8 SURFACE; 35.2-3,878.0 SAFETY VLV; 1,822.1 CONDUCTOR; 36.0-80.0 KUP INJ KB-Grd (ft) 42.01 RR Date 6/29/1985 Other Elev… 2Z-14 ... TD Act Btm (ftKB) 8,305.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292136100 Wellbore Status INJ Max Angle & MD Incl (°) 50.15 MD (ftKB) 8,200.00 WELLNAME WELLBORE2Z-14 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: WRDP 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: 2Z-14 (PTD 185-107) IA Exceeded DNE Date:Monday, September 30, 2024 9:30:52 AM Attachments:AnnComm Surveillance TIO for 2Z-14.pdf From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Monday, September 30, 2024 8:34 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: 2Z-14 (PTD 185-107) IA Exceeded DNE Hi Chris, 2Z-14 (PTD 185-107) is a WAG injector that was swapped from gas injection to produced water injection on 9/26/24. The IA pressure exceeded the water injection DNE of 2000 psi on 9/27/24. The IA pressure rose to 2240 psi as observed by the operator walk down. The IA pressure was bled to 1000 psi on 9/28/24 and has stabilized at 1200 psi. CPAI does not intend to conduct diagnostics at this point as it is believed that the increased IA pressure was due to the increase in injection temperature of water vs gas. CPAI will continue to monitor this well closely and report as required if any additional anomalies are observed. Please let me know if you have any questions or disagree with the plan. Warmest regards, Jaime Bronga Well Integrity – CPF2 – ConocoPhillips Alaska Cell: 907-229-8282 2Z-14 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 2Z-14 2024-08-19 2300 1550 -750 IA 2Z-14 2024-09-26 2400 1000 -1400 IA 2Z-14 2024-09-28 2000 1000 -1000 IA Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 8,044.0 2Z-14 6/11/2024 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Update tag depth 2Z-14 6/11/2024 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 1/13/2011 ninam Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 36.0 80.0 80.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 35.2 3,878.0 3,302.6 36.00 J-55 BTC PRODUCTION 7 6.28 32.6 8,277.7 6,300.4 26.00 J-55 BTC Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 32.6 Set Depth … 7,863.3 Set Depth … 6,031.0 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE-8rd ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 32.6 32.6 0.07 HANGER 8.000 FMC GEN III TUBING HANGER 3.500 1,822.1 1,790.2 28.48 SAFETY VLV 5.937 BAKER FVL SSSV (Locked open 7/27/94) BAKER FVL 2.810 7,409.8 5,713.2 44.89 GAS LIFT 5.960 MERLA TDPX MERLA TDPX 2.875 7,448.3 5,740.5 44.73 PBR 5.625 BAKER PBR BAKER 3.000 7,462.0 5,750.2 44.68 PACKER 6.151 BAKER FHL PACKER BAKER FHL 3.000 7,502.6 5,779.1 44.51 GAS LIFT 5.960 MERLA TDPX MERLA TDPX 2.875 7,573.2 5,829.6 44.29 GAS LIFT 5.960 MERLA TDPX MERLA TDPX 2.875 7,612.6 5,857.8 44.38 BLAST RINGS 4.500 CARBIDE BLAST RINGS (5) 2.867 7,789.7 5,981.4 47.19 BLAST JT 4.500 B.O.T STEEL BLAS JT 2.867 7,819.5 6,001.6 47.52 GAS LIFT 5.960 MERLA TDPX W/WI PACKING (Injection Mandrel is leaking) MERLA TDPX 2.875 7,838.9 6,014.6 47.67 LOCATOR 4.563 BAKER LOCATOR sub w/5' seals BAKER 3.000 7,839.7 6,015.2 47.68 PACKER 6.151 BAKER FB-1 PACKER BAKER FB-1 4.000 7,854.0 6,024.8 47.79 NIPPLE 4.520 CAMCO D NIPPLE no go CAMCO D 2.750 7,862.5 6,030.5 47.86 SOS 4.500 CAMCO SHEAR OUT CAMCO 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 7,790.0 5,981.6 47.20 PATCH TTS PARAGON II PATCH LOWER PACKER, MID ELEMENT @ 7833'; UPPER PACKER ASSEMBLY w/PACKER MID ELEMENT @ 7813.7' set 11/10/2006 11/10/2006 1.625 7,819.0 6,001.2 47.52 LEAK Leak below DV 3/4/2000 2.990 7,819.0 6,001.2 47.52 LEAK LEAK AT UPPER PACKER OF TUBING PATCH, VERY LITTLE FLOW TO A-SAND, UNABLE TO GET SPIN COUNTS IN 7" CASING DUE TO LOW FLOW -LEAK IN THE C-SAND SELECTIVE AT 7792' (INSIDE PATCH NEAR UPPER PACKER) 1/8/2016 1.650 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 7,409.8 5,713.2 44.89 1 GAS LIFT DMY T2 1 1/2 0.0 5/24/1990 WI Pkg 0.000 7,502.6 5,779.1 44.51 2 INJ HFCV RM 1 1/2 0.0 11/24/2014 0.250 7,573.2 5,829.6 44.29 3 INJ DMY RM 1 1/2 0.0 7/13/1985 0.000 7,819.5 6,001.6 47.52 4 INJ DMY RM 1 1/2 3/5/2000 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,622.0 7,728.0 5,864.5 5,939.0 UNIT D, C-4, C- 3, C-2, C-1, 2Z- 14 7/13/1985 12.0 IPERF 5 1/2" Schlumberger 7,775.0 7,784.0 5,971.4 5,977.5 UNIT B, 2Z-14 7/13/1985 12.0 IPERF 5 1/2" Schlumberger 7,921.0 7,928.0 6,069.6 6,074.2 A-5, 2Z-14 7/13/1985 4.0 IPERF 90° phasing; 4" Hyper Jet II 7,944.0 7,984.0 6,084.8 6,111.2 A-4, 2Z-14 7/13/1985 4.0 IPERF 90° phasing; 4" Hyper Jet II 8,016.0 8,025.0 6,132.1 6,138.0 A-3, 2Z-14 7/13/1985 4.0 IPERF 90° phasing; 4" Hyper Jet II 2Z-14, 6/13/2024 11:42:56 AM Vertical schematic (actual) PRODUCTION; 32.6-8,277.7 IPERF; 8,016.0-8,025.0 IPERF; 7,944.0-7,984.0 IPERF; 7,921.0-7,928.0 PACKER; 7,839.7 GAS LIFT; 7,819.5 LEAK; 7,819.0 LEAK; 7,819.0 PATCH; 7,790.0 IPERF; 7,775.0-7,784.0 IPERF; 7,622.0-7,728.0 GAS LIFT; 7,573.2 GAS LIFT; 7,502.6 PACKER; 7,462.0 GAS LIFT; 7,409.8 SURFACE; 35.2-3,878.0 SAFETY VLV; 1,822.1 CONDUCTOR; 36.0-80.0 KUP INJ KB-Grd (ft) 42.01 RR Date 6/29/1985 Other Elev… 2Z-14 ... TD Act Btm (ftKB) 8,305.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292136100 Wellbore Status INJ Max Angle & MD Incl (°) 50.15 MD (ftKB) 8,200.00 WELLNAME WELLBORE2Z-14 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: WRDP MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, October 12, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2Z-14 KUPARUK RIV UNIT 2Z-14 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/12/2023 2Z-14 50-029-21361-00-00 185-107-0 W SPT 5749 1851070 1500 1975 1960 1960 1975 160 410 390 390 4YRTST P Sully Sullivan 8/14/2023 PT to 2800 for 500psi dp 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 2Z-14 Inspection Date: Tubing OA Packer Depth 750 2810 2685 2660IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS230816125010 BBL Pumped:2.6 BBL Returned:2.4 Thursday, October 12, 2023 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To: Jim Regg DATE: Monday, October 21, 2019 ri��`1 P.J. Supervisor l Lt, jQ(?-4(L 1Cq SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 2Z-14 FROM: Lou Laubenstein KUPARUK RIV UNIT 2Z-14 Petroleum Inspector Sre: Inspector Reviewed By: P.I. Supry ' r NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2Z-14 API Well Number 50-029-21361-00-00 Inspector Name: Lou Laubenstein Permit Number: 185-107-0 Inspection Date: 10/14/2019 v IUSp Num: mitLO1,1910I5121343 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2Z-14 Type Inj W -TVD 5749 - Tubing 1540 1540 1550 - 1550 - PTD 1851070 Type Test SPT Test psi 1500 IA 720 2290 2190 180- 2180,-1 T BBL P-umped-.--F BBL 2 BBL Returned: 19 OA oo _ oo - oa 100 Interval 4vRTST P/F P Notes: Monday, October 21, 2019 Page 1 of 1 • -2-4,4Coff' WELL LOG TRANSMITTAL#903044068 To: Alaska Oil and Gas Conservation Comm. February 5, 2016 Attn.: Makana Bender RECEIVED 333 West 7th Avenue, Suite 100 FEB I 0 20167.../ LOGGED2s/20 Anchorage, Alaska 99501 K BENDER AOGCC RE: Injection Profile 2Z-14 Run Date: 1/8/2016 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2Z-14 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-21361-00 Injection Profile Log 1 Color Log 50-029-21361-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 s tAiNfiEtl Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed:Pj,,A.Lit.suk)k)Zzagat, • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 1131/C DATE: Wednesday,August 26,2015 P.I.Supervisor l SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2Z-14 FROM: Johnnie Hill KUPARUK RIV UNIT 2Z-14 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry .iir'= NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2Z-14 API Well Number 50-029-21361-00-00 Inspector Name: Johnnie Hill Permit Number: 185-107-0 Inspection Date: 8/6/2015 Insp Num: mitJWHl50810105029 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2z-14 iType Inj C' TVD 5749 Tubing; 3625 • 3625 - 3625 3625• PTD 1851070 'Type Test SPT Test psi 1500 IA 2300 - 3000 • 3000 3000 • Interval'4YRTST P/F P ✓ OA 490 520 520 520 Notes: SCANS Wednesday,August 26,2015 Page 1 of 1 110 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Friday,January 16,2015 t �e P.I.Supervisor C . 1j &'r I7 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2Z-14 FROM: Bob Noble KUPARUK RIV UNIT 2Z-14 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry 2- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2Z-14 API Well Number 50-029-21361-00-00 Inspector Name: Bob Noble Permit Number: 185-107-0 Inspection Date: 1/8/2015 Insp Num: mitRCNI50108180630 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Wel 1 2Z-14 Type Inj–r WjTVD --,TVD 5749 'Tubing 2550 2550 - 2550 P2s5o I — PTD I 1851070 (Type Testi SPT Test p 1 1500 IA 860 2020= 1960 - 1950 " — -- Interval II4 TST P/F P OA 170 320 310 310 - L Notes: SCANNED ,`.H, sr Friday,January 16,2015 Page 1 of 1 Ima ect Well History File' Cover l~e XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. / ~~/' 07 Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) -~'~Color items: 1~7- ~ [] Diskettes, No. [3 Maps: [] Grayscale items: [] Other. No/Type [] Other items scannable by large scanner [] Poor Quality Originals: '"" OVERSIZED (Non-Scannable) [3 Other: , [] Logs of various kinds NOTES: [] Other BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE:. /S/ Project Proofing BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELl. DATE: Is/ Scanning Preparation BY: BEVERLY E~REN VINCENT SHERYL MARIA LOWELL DATE: /S/ Production Scanning Stage l PAGE COUNT FROM SCANN ED FILE: BY: Stage 2 BY~ (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE SASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) PAGE COUNT.ATC.ES.U..ER,N SCANN,.G P.EPARAT,ON: '/'- YES NO ~BRE. V,NCENT S.ERYL MAR,~ LOWELL DATE:/9,3/.O~,S,~ IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO III Illllllll RESCANNEDBY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /S/ General Notes or Comments about this file: Quality Checked (done) 10/25/02Rev3NOTScanned.wpd • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, September 06, 2011 TO: Jim Regg ) P.I. Supervisor Vg/' 9 l13l t( SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2Z -14 FROM: John Crisp KUPARUK RIV UNIT 2Z -14 Petroleum Inspector Src: Inspector Reviewed By: P.T. Supry 1 NON - CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 2Z -14 API Well Number: 50- 029 - 21361 -00 -00 Inspector Name: John Crisp Insp Num: mitJCr110829094306 Permit Number: 185 -107 -0 Inspection Date: 8/26/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2Z-14 , Type Inj. N TVD 5749 IA 760 2870 2790 2770 - P.T.D 1851070 ' TypeTest SPT Test psi 1500 OA — 10 20 20 20 Interval 4YRTST - P/F P - Tubing 2175 2150 2150 2170 Notes: 2.6 bbls pumped for test. • Tuesday, September 06, 2011 Page 1 of 1 • MEMORANDUM To: Jim Regg ~ c ~ /~,l ro P.I. Supervisor ~ ~ l ` EROivI: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, August 25, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2Z-14 KUPARUK RIV UNIT 2Z-]4 Src: Inspector NON-CONFIDENTIAL L~ Reviewed B P.I. Suprv J Comm Well Name: KUPARUK RIV UNIT 2Z-14 API Well Number: s0-029-21361-00-00 Insp Num: mitCS100823061904 Permit Number: 185-107-0 Rel Insp Num: Inspector Name: Chuck Scheve Inspection Date: 8/22/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I 2z-Ia Type Inj. ~ w ` TVD s~a9 . IA 90o zl6o ' 21ao 21ao . p ~ Iaslo~o TypeTest ' SPT I I Test psi Isoo ~ ~ _1 OA - 6so Aso Aso Aso Interval4YRTST p~-, P ~ Tubing 2600 I 2600 2600 2600 NOtes: pre-test pressures were observed for 30+ minutes and found stable. .._ ...~.. r ~ ~r~ -.! ~ ~,; Wednesday, August 25, 2010 Page 1 of 1 ~ ~ ~ ~ ConocoPh~llips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 3, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~ ~~~~" . ~ ~9 ~~~ sv~~r ~ ~ lo~~ ~~~s~~ ~~~~ ~ ~~~ ~r~n~. ~ammissiun ~nchprag~ ~~`~;~~~' ;~:.fi '~~~j ,1 , ~.~ ~Q~~ ~~`~~~ ~ y ~'~,''/' `~ Enclosed please fmd a spreadsheef with a list of wells from the Kuparulc field (KRL~. 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 September 20~' and October 13~' 2009. The corrosion inhibitor/sealant was pumped October 1 Sth and 31 St + November 1 St and 2°a 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please ca11 MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. ~mcerely, ~ Perry Kle~ ConocoPhillips Well Integrity Projects Supervisor .. . ~ ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 11/3/09 ' 2C. 2D. 2Z & 3K Pad Well Name API # PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2C-01 50029209620000 1830830 17" NA 17" NA 2.12 10/15/2009 2C-02 50029209720000 1830930 12" NA 12" NA 2.97 10/15/2009 2C-03 50029209680000 1830890 10" NA 10" NA 3.82 10/15/2009 2C-04 50029209730000 1830940 17" NA 17" NA 2.12 10l15/2009 2C-05 50029209780000 1830990 18" NA 18" NA 3.4 10/31/2009 2C-06 50029209790000 1831000 28" NA 28" NA 7.65 10/15/2009 2C-08 50029209740000 1830950 27" NA 27" NA 6.8 10/15/2009 2C-09 50029212370000 1842210 22" NA 22" NA 5.1 10/15/2009 2C-10 50029212300000 1842140 54' 5.5 22" 10/13/2009 4.67 10/31/2009 2C-11 50029212310000 1842150 38' 5.3 26" 10/13l2009 5.52 10/31/2009 2C-12 50029212220000 1842060 25' 4.5 26" 10/13/2009 6.8 10/31/2009 2C-13 50029212230000 1842070 20" NA 20" NA 3.4 10/15/2009 2D-01 50029211940000 1841710 38" NA 38" NA 6.8 10/31/2009 2D-07 50029211690000 1841430 20" NA 20" NA 2.12 10/31/2009 2D-09 50029211370000 1841030 28" NA 28" NA 4.67 10/31/2009 2D-10 50029211350000 1841010 21" NA 28" NA 2.97 11/172009 2D-11 50029211340000 1840990 19" NA 19" NA 2.55 11/1/2009 2D-12 50029211310000 1840940 18" NA 18" NA 2.55 11/1/2009 2D-15 50029211840000 1841600 NS NA NS NA 1.7 11/1/2009 2Z-01A 50029209530100 2071110 14" NA 14" NA 1.7 11/1/2009 2Z-02 50029209600000 1830800 18" NA 18" NA 5.1 11 /2/2009 2Z-03 50029209640000 1830850 24" NA 24" NA 5.5 11l2/2009 2Z-06 50029209570000 1830770 10'9" 2.5 7" 9/20/2009 2.12 11/1l2009 2Z-14 50029213610000 1851070 24" NA 24" NA 3.4 11/1/2009 2Z-16 50029213630000 1851090 20" NA 20" NA 1.7 11/1/2009 2Z-18 50029218840000 1881330 37'6" 6.5 39" 9/20/2009 8.9 11/2/2009 2Z-22 50029225240000 1941470 16" NA 16" NA 5.95 11/1/2009 2Z-23 50029225440000 1950100 17" NA 17" NA 3.4 11/1/2009 3K-103 50029233920000 2081150 29" NA 29" NA 11.9 11/2/2009 3K-708 50029233950000 2081300 24" NA 24" NA 4.25 11/2/2009 MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor Ke11' ~>llfrjtJ7 DATE: Wednesday, August 15,2007 SUBJECT: Mechanical Integrity Tests CONOCOPIDLLIPS ALASKA INC 22-14 KUPARUK RIV UNIT 22-14 FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ,1ßr2- Comm NON-CONFIDENTIAL Well Name: KUPARUK RN UNIT 22-14 API Well Number: 50-029-21361-00-00 Inspector Name: Jeff Jones Insp Num: mitJJ0708141 0381 0 Permit Number: 185-107 -0 Inspection Date: 8/13/2007 Rei Insp N urn: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. IType Inj. i N , /[ , I ! I -- Well I 22-14 ITVD I 5750 I IA I 580 I 2450 ! 2370 2360 I ì I P.T. I 1851070 !TypeTest i SPT I Test psi I 1500 '10A i 0 I 0 0 I 0 I i I /P/F Tubing i ! I, ! Interval 4YRTST P v 3300 í 3300 3300 I 3300 ! i Notes: 2.7 BBLS diesel pumped. I well house inspected; no exceptions noted. .. / SCANNED AUG 2. 32007 Wednesday, August 15,2007 Page I of I ) ) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Kefl11¡~o<; DATE: Monday, August 15,2005 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA rNC 2Z-14 KUPARUK. RIV UNIT 22-14 Jim Regg P.I. Supervisor FROM: Jeff Jones Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 22-14 Insp Num: mitJJ05081 I 112119 ReI Insp Num: API Well Number: 50-029-21361-00-00 Permit Number: 185-107-0 Packer Depth Pretest Initial 15 Min. i~~1 +,~::;~~l~~::;:~~ i s;TI~~-;F:::ô~r~:: ~4~~o~~T- 2::: ~:: -- Inte~~-~L__~'0:!S;'---"- p~~-" p .._.__.... ...·_-T~bi~gT··----i250!·---ï25o·_·-·· I_____~:~~_ Notes: 0.9 BBLS diesel pumped. 1 well house inspected, no exceptions noted. '-(1" ~\r\\~~tl; O't¡¡,)iD ,t· ..... 'I' r: ') f\ ns ('CD (.~ \j l_l!lJ~' ,)1-1 Monday, August 15,2005 -"^ \ ~~ ~ I 0 Inspector Name: Jeff Jones Inspection Date: 8/8/2005 Reviewed By: P.I. Suprv :Jt:;r?- Comm 1990 L.u -~o-+ _ 30 Min. 45 Min. 60 Min. "--1"--- ---r".----..-- +-----...-.-- .. --1-. ... Page I of I ) ä~lp·HILlIPSAlaskalnc. : ./t ~ I). ...... ... ... . .... .. ... ..... ........ ......, {~" Á $:.¡b~!d~~r.{<)f PH LUPS PETKOlEU~/1 CÒ~1P.M··¡Y SSSV ( 1822-1823, 00:3.500) Ga s Lift andrei/Dummy Valve 1 (7410-7411, 00:5.960) PBR (7448-7449, 00:3.500) PKR (7462-7463, 00:6.151) Injection andrei/Dummy Valve 1 (7503-7504, 005.960) Injection andrei/Dummy Valve 2 (7573-7574, 00:5960) Perf (7622-7728) Perf (7775-7784) Injection andreI/Dummy Valve 3 (7819-7820, 005960) PKR (7840-7841, 00:6151) NIP (7854-7855. 003500) TUBING ( 0-7863, 003.500. 10'2992) Perf (7921-7928) Perf (7944-7984) Perf (8016-8025) l' r .) ; I I a j I ~ I ¡ ~ ~ i ì ~lÏl: .: .... :~::::" ~ ¡: i i Iii i I i ¡ ~ i I ! ~ i : _..... ....i '.:.' '.:.' : · . . . . II .. ..... ....... : : I : · ,. : I, i · . i Ii ¡, ! \ lJ"'" ¡.i "'......... . . . ... .... .; : t Ii I I j fl·.·. .U: .. . ..... -- ! II::':' II'T ~ -r-- -J- II ':t= -Q- +- ->- ~ · I ~ ~ =t== ~ -r- -:- +- -ö- ....l..- t ... ..... t ~\_...........,...... _...........~, ....... "...I'"õ" i:?< <:::::::I'? ..'. ~ I: .....::, . ....!ii .':'[ ! ~"""."."."....,.."........: .' '.' ~ ,.::'" . .. : "'::" ~ ! Ii I ~ ~::t:~......I\.< i !ili2! ! I "': \......:"'..i I w'·.········.····.···.····..·.···.:......... : . ',",. . '. ,. . . ., . +- ~ -L- ~ ~ ~ --?-- -+ ~ -+ ----+ -+ -+ -4- ---?- -+- -+ ~ :2Z,.14 KRU 2Z-14 API: 500292136100 SSSV Type: Baker 'FVL' (Locked Out) Well Type: INJ Orig Com pletion: 6/29/85 Angle @ TS: 45 deg @ 7626 Angle @ TO: 50 deg @ 8305 Zone :Status Feet SPFi Date I Type UNIT 106 12 ¡PERF -4, C-3, C-2, UNIT B A-5 A-4 A-3 Annular Fluid: Reference Log: Last Tag: 8080 Last Tag Date: 6/23/99 Casing$tring ;.CONDUCTOR Size I Top I 16.000 0 Ca$ihgString . SURFACE Size j Top I 9.625 0 .Casing..String····PRQDUCTtON Size I Top I 7.000 0 Tubing String- TUBING Size I Top r 3.500 0 ~ ¡ Perforations Summary ¡ Interval TVD 7622 - 7728 5864 - 5939 7775 - 7784 5971 - 5977 7921 -7928 6069 - 6074 7944 - 7984 6085 - 6111 8016-8025 6132-6138 ¡Gas Lift MandrelsNalves IStn MD TVD Man Mfr 7410 5713 Merla Man Type TPDX ("WI" Packing) Injeetion··MandrelslVéllves Stn MD TVD Man Man Mfr Type 1 7503 5779 MERLA TPDX 2 7573 5829 MERLA TPDX 3 7819 6001 MERLA I TPDX 1. Injection mandrel is leaking Other (plugs,. èquip., ètc;)~JEWELRY Depth TVD Type 1822 1790 SSSV 7448 5740 PBR 7462 5750 PKR 7840 6015 PKR 7854 6025 NIP 7862 6030 80S 7863 6031 TTL Last W/O: Ref Log Date: TO: 8305 ftKB Max Hole Angle: 50 deg @ 8305 Rev Reason: Set CRX by ImO Last Update: 5/11/00 Bottom 80 TVD 80 Th read Wt 62.50 Grade H-40 Bottom 7863 Comment 5 1/2" Schlumberger 9 7 4~1 IPERF 5 1/2" Schlumberger ¡PERF 90 deg. phasing; 4" Hyper Jet II IPERF 90 deg. phasing; 4" Hyper Jet II IPERF 90 deg phasing: 4" Hyper Jet II 12 4, :1 VMfr V Type V OD Latch Port TRO Date Vlv Run Comment DMY 1.5 T-2? 0.000 0 5/24/90 I V Type VOD Latch Port TRO I Date Vlv Run Commen1 DMY 1.5 RM 0.000 0 7/13/85 DMY 1.5 RM 0.000 0 7/13/85 DMY w/INI 1.5 RM 2.500 0 3/5/00 (1 ) Packing V Mfr Description Baker 'FVL' (Locked Open 7/27/94) MCX INJ Valve Pulled 5/22/95 Baker I Baker 'FHL' Baker'FB-1' Cameo '0' Nipple NO GO - set CRX w/fill ext. 4/25/2000 Cameo ID 2.810 3.000 3.000 4.000 2.750 2.992 2]'§2" ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Tom_Maunder@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us {-Gc!/ \ 01 OPERATOR: ConocoPhillips Alaska Inc. FIELD I UNIT I PAD: Kuparukl KRU/2Z DATE: 08108/05 OPERATOR REP: Arend/Greewood - AES AOGCC REP: Jeff Jones Packer Depth Pretest Initial 15 Min. 30 Min. Well 2Z-02 Type Inj. S TVD 5,812' Tubing 2,850 2,850 2,850 2,850 Interval 4 PT.D. 1830800 Type test P T est psi 1500 Casing 1,200 1,720 1,720 1,710 P/F P Notes: 45 Minute reading 2850/1710 Well 2Z-03 Type Inj. N TVD 5,835' Tubing 1,380 1,380 1,380 1,400 Interval 4 PT. D. 1830850 Type test P T est psi 1500 Casing 610 2,000 1,940 1,920 P/F P Notes: Well 2Z-06 Type Inj. S TVD 5,653' Tubing 1,850 1,850 1,850 1,850 Interval 4 P.T.D. 1830770 Type test P T est psi 1500 Casing 1,250 2,460 2,410 2,380 P/F P Notes: Well 2Z-08 Type Inj. S TVD 5,796' Tubing 2,250 2,250 2,250 2,250 Interval 4 PT.D. 1830380 Type test P Test psi 1500 Casing 900 1,700 1,680 1,660 P/F P Notes: Well 2Z-09 Type Inj. S TVD 5,827' Tubing 850 850 850 850 Interval 4 P.T.D. 1851360 Type test P T est psi 1500 Casing 830 1,760 1,720 1,690 P/F P Notes: Well 2Z-14 Type Inj. S TVD 5,750' Tubing 1,250 1,250 1,250 1,250 Interval 4 P.T.D. 1851070 Type test P Test psi 1500 Casing 1,480 2,030 1,990 1,990 P/F P Notes: Well 2Z-15 rype Inj. S TVD 5,751' Tubing 2,120 2,120 2,120 2,120 Interval 4 P.T.D. 1851080 Type test P T est psi 1500 Casing 840 2,770 2,670 2,650 P/F P Notes: Test Details: SCJ\NNE[\~ AUG 11. 2005 TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) MIT Report Form Revised: 06/19/02 MIT KRU 2Z 08-08-05.xls -FL MEMORANDUM State of Alaska TO: Julie Heusser Chairman Alaska Oil and Gas Conservation Commission DATE: June 24, 2001 THRU: Tom Maunder ~j't,-(t3b Su.erviso . FROM: Chuck Scheve Petroleum Inspector NON- CONFIDENTIAL SUBJECT: Mechanical Integrity Tests Phillips 2Z Pad Kuparuk River Unit Kuparuk Packer Depth Pretest Initial 15 Min. 30 Min. WellI 2Z-02 ITypelnj. I S I T.v.D. I 58i2I Tub ng] 2650 12650 12650 I 26. 0 JlntervalI 4 ' P.T.D.I 1830800 ITypetestl P I Testpsil 1453 ICasingI 1100I 1920 I 19001 19001 P/F ] _P Notes: We, J 2z-03 J Typelnj.I S J T.V.D. 15835 I Tubing I 2700 i 2700 J 2700 I 2700 J lntervalJ 4 P.T.D.I 1830850 ITypetestl P ITestpsil 1459 I CasingI 1220I 1900I 1880I 1880I P/F I --P Notes: WellI 2Z-06 I Typelnj.I S I T.V.D. J 5653 I Tubing 12500 I 2500 I 2500 I 2500 I lntervall 4 P.T.D.I 1830770 ITypetestl P ITestpsil 1413 ICasingI 1700I 2250] 2250I 2250I P/F I -P Notes: WellI 2Z-08 s I ~.v.~. I~,~ I Tubing 12650 12650 12650 I 26.~0 I lnt~rvall '4 P.T.D.I 18303801Type testI P ITestpsil 1449 I Casingl 1000 I 1840 ] 1820 I 1820 I P/F] P Notes: WellI 2Z-09 I Typelnj. I S ! T.V.D. I 5827 I Tubingl 2650 J 2650 I 2650 I 2650 I lntervall 4 P.T.D.I 1851360 ITypetestl P ITestpsil 1457 I Casingl 1650I 2250I 2200I 2200I P/F I P Notes: Well] 2Z-ll P.T.D.I 1851380 Notes: WellI 2Z-14 P.T.D.I 1851070 Notes: WellI 2Z-15 P.T.D.I 1851080 TypetestI P ITestpsil 1691 I Casingl 12251198OI 1980I 1980I P/F I P I Typelnj.I N I T.V.D. 15750 I Tubing I 1400 I 1400 I 1400 I ~,00 I lntervall 4 Type testI P J TestpsiI 1683 JCasingJ 800 I ~875 I 1750l ~750 I .P/FIB I Typelnj.I S I T.V.D. J 5751 I Tubing 12500 I 2500 I 2500 I 2500 I',',rva'l 4 Type testI P I Testpsil '1438 I CasingI 1460I 2240I 2160I 2140I P/F I P Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Intemal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Vadance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to the Philips 2Z pad in the KRU and witnessed the 4-year mechanical integrity tests on 8 injection wells. All pretest pressures were observed and were found to be stable. A standard annulus pressure test was then performed with all 8 wells demonstrating good mechanical integrity. M.I.T.'s Performed: 8 Number of Failures: _0 Total Time during tests: _6 Attachments: cc: MIT report form 5/12/00 L.G. MIT KRU 2Z Pad 6-24-01 CS.xls 6/25/01 Memory Multi-Finger Caliper Log Results Summary Company: ARCO Alaska, Inc. Well: 2Z-14 Log Date: April 24, 2000 Field: Prudhoe Bay Log No.: 4072 State: Alaska Run No.: 1 APl No.: 50-029-21361-00 Pipe Desc.: 3.5" 9.3 lb. J-55 EUE Top Log Intvl: Surface Pipe Use: Tubing Bot. Log Intvl: 7853 Ft. (MD) Inspection Type' Obstruction Evaluation COMMENTS - This survey was run to assess the condition of the tubing with respect to restriction evaluation. The caliper recordings indicate that buckling ranging from slight to severe is recorded throughout the interval logged. The initial moderate buckling appears between 3,700' and 4,000'. There is more moderate buckling in the interval between 4,790' and 5,635'. The most severe buckling is located between 5,763' and 6,455'. The buckling at 5,764', 6,191', 6,302', 6,455' and 7,347' all appear to be so severe that the tubing may have been deformed in respect to ovality. Cross sections of these areas are included in the report. Scattered light deposits were recorded but no indication of substantial scale build-up was indicated. No penetrations were recorded in the logged interval in excess of 15%. The tubing appears to be in good condition in respect to corrosive damage. MAXIMUM RECORDED WALL PENETRATIONS · No significant penetrations (in excess of 15%) were recorded throughout the interval logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS · No area of significant cross-sectional wall loss (in excess of 10%) was recorded throughout the interval logged. MAXIMUM RECORDED ID RESTRICTIONS · No area of significant ID restriction (in excess of 0.10 in.) was recorded throughout the interval logged as a result of scale deposits. The following restrictions appear to be the result of ovality changes 5,764.38 2.78 in. Jr. 187 Ovality change. '"""-' 6,191.44 2.78 in. Jr. 201 Ovality change. 6,301.65 2.85 in. Jt. 204 Ovality change. ~AY '~ :2 2000 6,454.34 2.85 in. Jt. 209 Ovality change. 7,347.18 2.82 in. Jt. 238 Ovality changeAlaska 011 & I Field Engineer' R. Liddelow Analyst: S. Adcock Witness: Keith Ferguson I l. ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (28:t) 565-1369 E-mail: PDS@hmemorylog,com Prudhoe Bay Field Off[ce Phone: (907) 659-2307 Fax: (907) 659-2314 PDS Caliper Overview Body Region Analysis Well: 2Z-14 Survey Date: APRIL 24, 2000 Field: KUPARAK Toot Type: MFC24 812 Company: ARCO ALASKA, INC. Tool Size: I 11/16" iris Country: USA No. of Fingers: 24 Analysed: Steve Adcock Tubing: Size Weight Grade & Thread Nora. OD NomJD Nora. Upset 3.5 ins 9.3 ppf EUE 8RD 3.5 ins 2.992 ins 3.75'6 ins Penetratiol~ and Metal I_oss (% wall) penetration body ~ metal loss body 0 to I to 10 to 20 to 40 to above 1% 10% 20% 40% 85% 85% Number of joir)t.;s_ analysed (total = 257) ..... Pene 204 44 9 0 0 0 Loss 251 6 0 0 0 0 Damage Configuration ( body ) Number of joi..L!ts damaged (total Z5) 5 0 0 0 0 Damage Profile (% wall) penetration body ~ metal loss body 0 5O 5 99 149 199 G[M2 GLM t Bottom of Survey = 251.8 100 Analysis Overview page 2 ?DS C~ER JOINT TABULATION S~T Pipe: 3.5 ins 9.3 ppf EUE 8RD Wall thickness. Body: 0,254ins Upset = 0.382ins Nominal ID: 2,992 ins Penetration Upset Body inches inches [ % Well: 2Zd 4- Field: KUPARAK Company: ARCO ALASKA, INC. Country: USA Date: APRIL 24, 2000 Mininlunl ] D Conlments PUP 2.88 2.89 2.88] penetration body metal loss body Damage profile % wa :50 1 O0 Pipe Tabulations page 1 PDS C~ER .JOINT TABULATION S Pipe: 3.5 ins 9.3 ppf EUE 8RD Wall thickness. Body: 0.254ins Upset = 0.382ins Nominal ID: 2.992 ins Penetration Welt: 2Z-14 Field: KUPARAK Company: ARCO ALASKA, INC. Country: USA Date: APRIL 24, 2000 penetration body metal Foss body SSSV Damage profile (% wall) 50 100 2.84 Pipe Tabulations page 2 R~C~/V~D PDS C~ JOINT TABULATION S T Pipe: 3.5 ins 9.3 ppf EUE 8RD Wall thickness. Body: 0.254ins Upset. = 0.382]ns Nominal ID: 2.992 ins Well: 2Z-14 Field: KUPARAK Conrpany: ARCO ALASKA, INC. Country: USA Date: APRIl. 24, 2000 Cornments penetration body metal loss body Damage profile (% wall) 50 100 Pipe Tabulations page 3 PDS C~ER/O[NT TABULATION S~T Pipe: 3.5 ins 9.3 ppf EUE 8RD Wall thickness. Body: 0,254ins Upset = 0.382ins Nominal ID: 2.992 ins ection Body inches Welt: 2Zq 4 Field: KUPARAK Company: ARCO ALASKA, INC. Country: USA Date: APRIL 24, 2000 CommeItt$ penetration body metal Doss body Damage profile (% wall) 50 100 .06 2.89 0 ~ .O5 .08 .06 .09 Pipe Tabulations page 4 PDS C~ER JOINT TABULATION S Pipe: 3.5 ins 9.3 ppf EUE 8RD Wall thickness. Body: 0.254ins Upset = 0.382ins Nominal ID: 2.992 ins .091 Penetration Upset inches Well: 2Zd 4 Field: KUPARAK Company: ARCO ALASKA, INC. Country: USA Date: APR[[ 24, 2000 2.82 2.85 2.88 2.87 PACKER penetration body metal loss body 1Damage profile (% wall) 50 100 Pipe 'labulations page 5 PDS C~ER JOINT TABULATION Pipe: 3.5 ins 9.3 ppf EUE 8RD Well: 2Z-14 WaJJ thickness. Body: 0,254ins Upset = 0.382ins Field: KUPARAK Nominal ID: 2.992 ins Company: ARCO ALASKA, INC. Country: USA Date: APRIl 24, 2000 Comments PUP PUP PUP PACKER PUP XN Damage Classifications Penetration / projection class, in order of damage severity Hole - penetration exceeds 85% of nominat wait thickness Ring - damage area exceeds 60% of circumference, but depth range does not exceed 2 * pipe ID Line - damage depth range exceeds 4 * pipe ID, but extends less thari 30% of circumference General - damage depth range exceeds 2 * pipe ID and/or extends more than 30% of circumference Isolated ~ damage depth range does not exceed 4 * pipe ID or extend more than 30% of circumference Damage reporting threshold = 30 thou inches deviation in body, 50 thou in upset. Modal line tength = 0.263 feet. penetration body metal loss body Damage profite 50 100 Pipe Tabulations page 6 A ~ci~o age Z (,~5o 'OS, PD!'i :ALIPER JOINTTALLY SHEE-ii Pipe: 3.5 ins 9.3 ppf EUE8RD Wall thickness. Body: 0.254ins Upset = 0.382ins Nominal ID: 2.992 ins Joint Depth Length Measured Type No. ID feet feet inches .1 27.67 4.69 nominal Pup 1 32.36 31.65 nominal 2 64.01 30.72 nominal 3 94.73 30.98 nominal 4 125.71 30.40 nominal 5 156.11 30.43 nominal 6 186.54 30.83 nominal 7 217.37 31.05 nominal 8 248.42 31.52 nominal 9 279.94 30.29 nominal 10 310.23 29.51 nominal 11 339.74 30.31 nominal 12 370.05 31.85 nominal 13 401.90 30.31 nominal 14 432.21 27.91 nominal 15 460.12 31.08 nominal 16 491.20 29.95 nominal 17 521.15 31.07 nominal 18 552.22 31.30 nominal 19 583.52 30.57 nominal 20 614.09 31.62 nominal 21 645.71 31.74 nominal 22 677.45 29.68 nominal 23 707.13 31.73 nominal , , 24 738.86 31.91 nominal 25 770.77 30.55 nominal 26 801.32 30.01 nominal 27 831.33 30.58 nominal 28 861.91 27.56 nominal 29 889.47 30.47 nominal 30 919.94 29.70 nominal , , 31 949.64 31.56 nominal 32 981.20 31.43 nominal , 33 1012.63 30.79 nominal 34 1043.42 32.56 nominal 35 1075.98 3!.12 nominal 36 1107.10 32.30 nominal 37 1.139.40 30.79. nominal 38 1170.19 29.77 nominal 39 1199.96 31.23 nominal 40 1231.19 31.17 nominal 41 .1262.36 30.44 nominal 42 1292.80 31.16 nominal 43 1323.96 31.32 nominal 44 1355.28 30.89 nominal 45 1386.17 29.53 nominal. 46 1415.70 31.85 nominal 47 1447.55 30.42 nominal 48 1477.97 32.04 nominal 49 1510.01 31.32 nominal Well: 2Z-14 Field: KUPARAK Company: ARCO ALASKA, INC. Country: USA Date: APRIL 24, 2000 Joint Depth Length Measured Type No. ID feet feet inches 50 1541.33 30.05 nominal 51 1571.38 32.31 nominal 52 1603.69 31.05 nominal 53 1634.74 29.09 nominal 54 1663.83 31.10 nominal 55 1694.93 29.74 nominal 56 1724.67 31.23 nominal 57 1755.90 30.82 nominal 58 1786.72 31.76 nominal 58.1 1818.48 13.17 nominal Ssv 59 1831.65 30.90 nominal 60 1862.55 30.68 nominal 61 1893.23 30.21 nominal 62 1923.44 31.40 nominal 63 1954.84 31.55 nominal , , 64 1986.39 31.26 nominal 65 201 ,7.65 31.83 nominal 66 2049.48 31.82 nominal 67 2081.30 30.47 nominal 68 2111777 32.13 nominal 69 2143.90 31.69 nominal 70 2175.59 31.74 nominal 71 2207.33 31.44 nominal 72 2.238.77 30.92 nominal 73 2269.69 30.22 nominal 74 2299.91 29.39 nominal 75 2329.30 29.79 nominal 76 2359.09 28.29 nominal 77 2387.38 31.95 nominal 78 2419.33 31.89 nominal 79 2451.22 31.89 nominal 80 2483.11 31.75 nominal .8.1. 2514.86 37.06 nominal 82 2545.92 31.48 nominal 83 2577.40 29.99 nominal 84 2607.39 29.63 nominal 85 2637.02 29.87 nominal 86 2666.89 31.76 nominal 87 2698.65 31.81 nominal 88 2730.46 31.97 nominal 89 276.2.43 31.42 nominal 90 2793.85 30.12 nominal. 91 2823.97. 31.35 nominal 92 2855.3.2 30.39 nominal 93 2885.71 30.27 nominal 94 2915.98 30.96 nominal 95 2946.94 31.72 nominal 96 2978.66 29.55 nominal 97 3008.21 28.66 nominal 98 3036.87 29.10 nominal Joint Tally page 1 RECEIVED 1 2 2000 Alaska Oil & Gas Cons. Oommissio~ Anchorage PDt, :ALIPER JOINTTALLY SHEE Pipe: 3.5 ins 9.3 ppf EUE 8RD Wall thickness. Body: 0.254ins Upset = 0.382ins Nominal ID: 2.992 ins Well: 2Z-14 Field: KUPARAK Company: ARCO ALASKA, INC. Country: USA Date: APRIL 24, 2000 Joint Depth Length Measured Type No. ID feet feet inches 99 3065.97 31.04 nominal 100 3097.01 28.01 nominal 101 3125.02 28.90 nominal 102 3153.92 29.78 nominal 103 3183.70 29.99 nominal 104 3213.69 31.48 nominal 105 3245.17 31.55 nominal 106 3276.72 30.05 nominal 107 3306.77 29.84 nominal 108 3336.61 32.23 nominal 109 3368.84 30.51 nominal 110 3399.35 31.39 nominal 111 3430.74 31.59 nominal 112 3462.33 31.00 nominal 113 3493.33 30.53 nominal 114 3523.86 29.85 nominal 115 3553.71 31.50 nominal 116 3585.21 30.47 nominal 117 3615.68. 30.22 nominal 118 3645.90 30.44 nominal 119 3676.34 31.55 nominal 120 3707.89 28.06 nominal 121 3735.95 30.86 nominal 122 3766.81 30.66 nominal 123 3797.47 30.39 nominal 124 3.827.86 31.69 nominal 125 3859.55 .30.62 nominal 126 3890.17 30.63 nominal , , 1.27 3920.80 32.49 nominal. 128 3953.29 30.33 nominal. 129 3983.62 31.03 nominal 130 4014.65 30.15 nominal 131 4044.80 31.13 nomin.al 132 4075.93 30.50 nominal 133 4106.43 32.22 nominal 134 4138.65 3~.08 nominal 135 4169.73 31.40 nominal 136 4201.~3 31.64 nomi. nal 137 4232.77 30.27 nominal 138 4263.04 30.03 nominal 139 4293.07 31.22 nominal 140 4324.29 33.05 no. minal 141 4357.34 30.73 nominal 142 4388.07 31.00 nominal 143 4419.07 31.30 nominal 144 4450.37 31.26 nominal 145 4481.63 30.96 nominal 146 4512.59 31.31 nominal 147 4543.90 30.52 nominal 148 .4574.42 29.40 nominal Joint Depth Length Measured Type No. ID feet feet inches 149 4603.82 32.70 nominal 150 4636.52 31.44 nominal 151 4667.96 31.01 nominal 152 4698.97 31.65 nominal 153 4730.62 30.46 nominal 154 4761.08 29.59 nominal 155 4790.67 29.59 nominal 156 4820.26 28.65 nominal 157 4848.91 30.23 nominal 158 4879.14 32.41 nominal 159 4911.55 28.88 nominal 160 4940.42 33.17 nominal 161 4973.60 28.77 nominal 162 5002.37 28.32 nominal 163 5030.69 30.76 nominal 164 5061.45 30.36 nominal 165 5091.81 29.37 nominal 166 5121.18 32.14 nominal 167 5153.32 29.32 nominal 168 5182.64 29.14 nominal 169 5211.78 30.71 nominal 170 5242.49 28.72 nominal 171 5271.21 30.00 nominal 172 5301.21 28.95 nominal 173 5330.16 29.34 nominal 174 5359.50 29.95 nominal 175 5389.45 31.28 nominal 176 5420.73 30.58 nominal 177 5451.31 31.55 nominal 178 5482.86 30.97 nominal 179 5513.83 2.9.54 nominal 180 5543.37 29.73 nominal 181 5573.10 31.95 nominal 182 5605.05 29.67 nominal 183 5634.72 31.52 nominal 184 5666.24 30.43 nominal 185 5696.67 31.02 nominal 186 5727.69 29.10 nominal 187 5756.79 30.62 nominal 188 5787.41 31.68 nominal 189 5819.09 32.77 nominal 190 5851.86 27.14. nominal 191 5879.00 32.35 nominal 192 5911.35 31.13 nominal 193 5942.48 29.86 nominal 194 5972.34 31..62 nominal 195 6003.96 29.73 nominal 196 6033.69 30.56 nominal 197 6064.25 32.55 nominal 198 6096.80 30.05 nominal Joint Tally page 2 RECEIVED 1 2 000 Alaska Oil & Gas Cons. Commission Anchorage PDt' iALIPER JOINT TALLY SHEE-I( Pipe: 3.5 ins 9.3 ppf EUE8RD Wall thickness. Body: 0.254ins Upset-- 0.382ins Nominal ID: 2.992 ins Joint Depth Length Measured Type No. ID feet feet inches 199 6126.85 29.86 nominal 200 6156.71 31.20 nominal 201 6187.91 32.44 nominal 202 6220.35 30.95 nominal 203 6251.30 29.86 nominal 204 6281.16 31.82 nominal 205 6312.98 30.88 nominal 206 6343.86 29.18 nominal 207 6373.04 31.80 nominal 208 6404.84 32.64 nominal 209 6437.48 28.27 nominal 210 6465.75 32.60 nominal 211 6498.35 31.08 nominal 212 6529.43 30.61 nominal 213 6560.04 30.68 nominal 214 6590.72 31.95 nominal 215 6622.67 29.67 nominal 216 6652.34 30.56 nominal 217 6682.90 31.08 nominal 218 6713.98 31.75 nominal 219 6745.73 30.89 nominal 220 6776.62 32.75 nominal 221 6809.37 29.45 nominal 222 6838.82 31.48 nominal 223 6870.30 27.29 nominal 224 6897.59 27.98 nominal 225 6925.57 30.27 nominal 226 6955.84 29.31 nominal 227 6985.15 29.32 nominal. 228 7014.47 27.41 nominal 229 7041.88 29.17 nominal 230 7071.05 32.01 nominal 231 7103.06 33.16 nominal 23.2 7136.22 30.64 nominal 233 7166.86 29.96 nominal 234 7196.82 33.99 nominal 235 7230.81 25.87 nominal 236 7'256.68 30.51 nominal 237 7287.19 33.31 nominal 238 7320.50 32.78 nominal 239 7353.28 30.31 nominal 240 7383.59 25.65 nominal 240.1 7409.24 11.92 nominal Glml 241 7421.16 28.14 nominal 241.1 7449.30 20.77 nominal Packer 242 7470.07' 32.73 nominal 242.2 7502.80 8.21 nominal Giro2 243 7511.01 32.22 nominal 244 7543.23 28.07 nominal 244.1 7571.30 9.61 nominal GIm3 Well: 2Z-14 Field: KUPARAK Company: ARCO ALASKA, INC. Country: USA Date: APRIL 24, 2000 Joint Depth Length Measured Type No. ID feet feet inches 245 7580.91 30.89 nominal 246 7611.80 30.71 nominal 247 7642.51 28.60 nominal 248 7671.11 30.87 nominal 249 7701.98 27.33 nominal 250 7729.31 29.93 nominal 251 7759.24 30.82 nominal 251.1 7790.06 20.41 nominal Pup 251.2 7810.47 8.46 n om]n al Pup 251.3 7818.93 8.74 nominal GIm4 251.4 7827.67 12.45 nominal Pup 251.5 7840.12 8.91 nominal Packer 251.6 7849.03 6.45 nominal Pup 251.7 7855.48 1.38 nominal Xn 251.8 7856.86 unknown nominal Pup STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown __ Pull tubing Alter casing Stimulate __ Plugging Repair well Perforate Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 5. Type of Well: Development _ Exploratory _ Stratigraphic _ Service X 1184' FSL, 271' FEL, Sec. 11, T11N, R9E, UM At top of productive interval 1255' FNL, 1468' FWL, Sec. 13, T11N, R9E, UM At effective depth 1508' FNL, 1117' FWL, Sec. 13, T11N, R9E, UM At total depth 1554' FNL, 1052' FWL, Sec. 13, T11N, R9E, UM 6. Datum elevation (DF or KB) RKB-10~)' 7. unit or Property name Kuparuk River Unit feet 8. Well number 2Z-14 9. Permit number 85-107/94-172 10. APl number 50 - 029-21:361 11. Field/Pool KUPARUK RIVER OIL POOL 12. Present well condition summary Total Depth: measured true vertical 8305' feet 6 31 7' feet Effective depth: measured true vertical 81 9 6' feet 6 2 4 7' feet Casing Length Size Structural Conductor 1 I 0' 1 6" Surface 3 8 7 7' 9 5/8" Intermediate Production 8 2 7 8' 7" Liner Perforation depth: measured true vertical Tubing (size, grade, and measured depth) 3-1/2", J-55, 7863' 7622'-7728', 8016'-8025' 5864'-5938', 6130'-6136' (measured) (measured) Cemented 255 Sx P F C 1050 Sx CS III & 450 Sx CS II 300 Sx Class G & 250 Sx CS I 7775'-7784', 5970'-5076', Packers and SSSV (type and measured depth) FVL SSSV @ 1822', FHL PKR @ 7462', FB PKR @ 7840' Measured depth True vertical depth 100' 3877' 8278' 7921'-7928' 6068'-6072' 100' 3301' 6235' 7944'-7984' 6083'-6109' RECEIVED 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Md .../.-- Water-Bbl Casing Pressure 0 6300 0 1700 0 0 3150 /' 1600 TubingPressure 3475 2700 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Water Injector X WAG Oil _ Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 Title Wells Superintendent SUBMIT IN DUPLICATE ARCO Alaska, inc. WELL 2Z-14 DATE 7/27/94 DAY TIME 0700 0730 0745 0800 0915 DESCRIPTION OF WORK Lock oUt SSSV/Run MCX Inj Valve CONTRACTOR / KEY PERSON HES-Kevin Corcoran Unit #70175 OPERATON AT REPORT TIME ~] COMPLETE ~'] INCOMPLETE FIELD EST: $3,675 KUPARUK RIVER UNIT WELL SERVICE REPORT AFC/CC# - SCA# 230DS28ZL/40115 ACCUMULATED COST $3,675 LOG ENTRY SITP: 3750/t 7"CP: 2125# 9-5/8"CP: 200# MIRU HES & Lil Red Held Safety Meeting PT Lub to 4500~-OK! Displaced well w/40 bbls diesel and RIH w/RS, QC, 5' 1-7/8", ICl, 5' 1-7/8", KJ, SSS, QC & Page 1 of 2 Baker LOT while pumping diesel @ 125°-Set LOT @ 1788' WLM-Press tubing to 450Oft-Bled to 2500# and press back up to 3800#-Bled press to 2500g and attempted to pull LOT-Not coming loose-Bled press to 2100g-SD to repair leaking weight indicator hose Cont'd jarring on LOT-S1TP 2200g-Bled to 200off-jarred on tools-pulled LOT free-POOH 1000 RIH w/3-1/2" wire brush-worked brush through SSSV profile from 1860'<->1900'WLM- w/CL press @ 0g-Bled 7"CP to 1500g-Close bleed to CL-press increased rapidly to 2100g & holding/TP 2100g-Unable to tag flapper-valve locked open-POOH 1030 1115 1130 1220 1300 1315 1330 RIH w/2.2 cent, TEL & 1.70 swage-Tag TI' @ 7821' WLM (7862' RKB)-Tag filI@ 8041' WLM (8082' RKB)-POOH RIH w/3"GS, "BR" Lock & MCX Inj Valve (#305 w/1.092 bean)-Set down @ 200' WLM- Unable to move down while pumping-tools sticking??-POOH RIH w/2.76 broach-mn past 200' WLM & broached thru tight spot @ 849' WLM to SSSV-POOH RIH w/Y'GS, "BR"Lock & MCX Inj Valve while pumping @ 1/4 bpm-Set @ 1788' WLM-POOH RIH w/Check Set-Jarred on "BR" Lock @ 1788' WLM & POOH-Check Set sheared-Lock Set SITP 2000g-Bled to 0ff-Held Good-Good Closure Test RDMO to 2Z-12 SUMMARY Locked open SSSV-Tag fill @ 8082' RKB-Bottom perfs @ 8025' RKB-57' of Rathole-Set MCX Inj Valve #307-Good Closure Test Final SITP: 2000g 7"CP: 1500g 9-5/8"CP: 0# ICHECK THIS BLOCK IF SUMMARY IS CONTINUED ON BACK Wind Vel. { knots[ AR3B-7031 298-3486 ARCO Alaska, Inc. Post (gffice Box 100360 ' Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 23, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in triplicate is an Application for Sundry Approval on the following Kuparuk well. Well 2z-14 Action Variance (Inj Valve) If you have any questions, please call me at 263-4241. Sincerely, ~. S. Whito $onior ~nginoor Kuparuk Potroloum En~inoorin~ Attachmonts FIR0~2305 (w/o arch) Gas Cons. Commission', Anchorage AR3B-6003-93 242-2603 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Alter casing _ Repair well _ Change approved program_ Operation Shutdown_ Re-enter suspended well _ Plugging _ Time extension Stimulate Pull tubing _ Variance ~ Perforate _ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 1184' FSL, 271' FEL, Sec. 11, T11N, R9E, UM At top of productive interval 1255' FNL, 1468' FWL, Sec. 13, T11N, R9E, UM At effective depth 1508' FNL, 1117' FWL, Sec. 13, T11N, R9E, UM At total depth 1554' FNL, 1052' FWL, Sec. 13, T11N, R9E, UM 12. Present well condition summary 6, Datum elevation (DF or KB) RKB-lO9' 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2Z-14 9. Permit number 85-107 10. APl number 50 - 029-21361 11, Field/Pool KUPARUK RIVE_R__O]L_ P.O_OJ~ RF£1:IVkU Total Depth: (measured) Effective depth: (measured) measured 8305' feet true vertical 6317' feet JUN 28 1994 measured 8 1 96' feet true vertical 6 24 7' feet ~d~ska (iff & Gas Cons. Commission Casing Length Size Cemented Measured depth A~;~r~ettical depth Structural Conductor 1 I O' I 6" 255 SX PFC I 0 O' 1 0 O' Surface 3877' 9 5/8" 1050 SxCS III & 3877' 3301' Intermediate 450 Sx CS II Production 8 2 7 8' 7" 300 SX Class G & 8 2 7 8' 6 2 3 5' Liner 250 SX CS I Perforation depth: measured 7622'-7728', 7775'-7784', 7921'-7928', 7944'-7984' 8016'-8025' true vertical 5864'-5938', 5970'-5076', 6068'-6072', 6083'-6109' 6130'-6136' Tubing (size, grade, and measured depth) 3-1/2", J-55, 7863' Packers and SSSV (type and measured depth) FVL SSSV @ 1822', FHL PKR @ 7462', FBL PKR @ 7840' 13. Attachments Description summary of proposal ~ Detailed operation program __ BOP sketch _ Install a downhole injection valve in Well 2Z-14 14. Estimated date for commencing operation June 1994 16. If proposal was verbally approved ~ ~--Z.~-'~ Name of approver: Russ Douglass Date approved 15. Status of well classification as: Oil __ Gas __ Suspended _ 6/2O/94 Service WAG Injector 17. I hereby/5;~rtify tl~t the foregoing is true and correct to the best of my knowledge. Signed -'~~/'/'~, ~vt~ Title Senior Encjineer FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test Location clearance Mechanical Integrity Test _ Subsequent form require 10- z/.. ~ ~ IApproval No. Approved by order of the Commission Form 10-403 Rev 06/15/88 -O~U~AL SIGNED BY "'~ELL A. DOUGLA~ Commissioner Date SUBMIT IN TRIPLICATE Approved Copy Returned Attachment 1 Request for Variance Kuparuk Well 2Z-14 As per Conservation Order No. 173, Rule 5, paragraph (a) (2), ARCO Alaska requests Commission approval to replace the failed surface controlled, subsurface safety valve in Injection Well 2Z-14 with a downhole, spring controlled, injection valve. This injection valve will act as a one-way check valve allowing downward injection of water and gas while preventing upward flow of these fluids. The injection valve is capable of preventing uncontrolled flow by automatically closing if such a flow should occur. RECEIVED JUN 2 8 1994 f~)aska (Jil & Gas Cons. C0mmJssJ0n Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI,.~SION REPORT OF SUNDRY WELL OPERATIONS Operations Performed' Operation Shutdown, Stimulate __ Pull tubing Alter casing Repair well 5. Type of Well: Development . , Exploratory _ Stratigraphic 99510 Service X :2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK Plugging Perforate Other O©NVERSlON 6. Datum elevation (DF or KB) RKB-109' 7. Unit or Property name Kuparuk River Unit feet 4, Location of well at surface 1184' FSL, 271' FEL, Sec. 11, T11N, R9E, UM At top of productive interval 1255' FNL, 1468' FWL, Sec. 13, T11N, R9E, UM At effective depth 1508' FNL, 1117' FWL, Sec. 13, T11N, R9E, UM At total depth 1554' FNL, 1052' FWL, Sec. 13, TllN, R9E, UM 8. Well number 2Z-14 9. Permit number 85-107 10. APl number _50 - 029-21361 11. Field/Pool KUPARUK RIVER OIL POOL 12. Present well condition summary Total Depth: measured true vertical 8 3 0 5' feet (measured) 631 7' feet Effective depth: measured 8 1 9 6' feet (measured) true vertical 6 2 4 7' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 1 1 0' 1 6" 255 Sx PFC 1 0 0' 1 0 0' Surface 3877' 9 5/8" 1050 Sx CS III & 3877' 3301' Intermediate 450 Sx CS II Production 8 2 7 8' 7" 300 Sx Class G & 8 2 7 8' 6 2 3 5' Liner 250 Sx CS I Perforation depth: measured 7622'-7728', 7775'-7784', 7921'-7928', 7944'-7984' 8016'-8025' true vertical 5864'-5938', 5970'-5076', 6068'-6072', 6083'-61 09' 6130'-6136' Tubing (size. grade, and measured depth) 3-1/2", J-55, 7863' Packers and SSSV (type and measured depth) FVL SSSV @ 1822', FHL PKR @ 7462', FBL PKR @ 7840' REC, EIV[D 13. Stimulation or cement squeeze summary JUL 2 ,~ ~,99,~ Intervals treated (measured) CONVERTED TO GAS INJECTION 10/88 Alaska Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 22OO 225O Subsequent to operation 0 6100 0 34OO 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Water Injector X WAG Daily Report of Well Operations Oil Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service Si~]ned d, ~0o ~ Title Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ARCO Alaska, Inc. Date: December 30, 19-88 Transmittal #: 7392 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2 Z- 1 4 Kuparuk Fluid Level Report 1 2 - 2 7 - 8 8 1 Y- 0 6 Kuparuk Fluid Level Report 1 2 - 2 6 - 8 8 2A-05 Kuparuk Fluid Level Report 12-26-88 2X-14 Kuparuk Fluid Level Report 1 2-25-88 2Z-13 Kupaurk Fluid Level Report 1 2-26-88 2 C- 0 9 Kuparuk Fluid Level Report 1 2 - 2 2 - 8 8 2 W- 01 Kuparuk Fluid Level Report 1 2 - 2 2 - 8 8 3K-06 Kuparuk Fluid Level Report 1 2-21 -88 3 B - 1 3 Kuparuk Fluid Level Report 1 2 - 2 1 - 8 8 Tubing Casing Tubing Tubing' Tubing Casing Casing Casing Casing Receipt Acknowledged: DISTRIBUTION: D&M State of Alaska Unocal Chevron Mobil SAPC ARCO Alaska, Inc. Post Office B~_.. 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 August 8, 1988 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached in triplicate are multiple Applications for Sundry Approvals on the following Kuparuk wells. Well Action Anticipated Stad Date 2 D-6 Refracture August, 1988 2D-15 Stimulate August, 1988 3J-10 Refracture August, 1988 2 Z - 2 Conversion May, 1 988 2 Z - 8 Conversion May, 1988 2 Z- 1 1 Conversion October, 1988 2Z- 1 4 Conversion September, 1988 If you have any questions, please call me at 265-6840. Sincerely, G. B. Srr~llwood Senior Operations Engineer GBS:kjr Attachments cc: J. Gruber ATO 1478 M. L. Hagood ATO 1120 S. P. Twiggs ATO 1130 KOE1.4-9 ARCO Alaska. Inc. is a Subsidiary of Allan/icRIchfieldCompany STATE OF ALASKA ALAS~,A OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend . ' Operation Shutdown ~ ~ Re-enter suspended well -- Alter cas,ng SI T~me extension Change approved program Plugging 'T Stimulate ~-~ Pull tubing Amend order .r Perforate ~' Other X ! 2 Name of Operator ARC. Il Ala~k~; Tnt. 3 Address P.O. Box 100360, Anchoraqe, Alaska 99510 4. Location of well at surface 1184' FSL, 271' FEL, Sec. 11, T11N, R9E, UM 5. Datum elevation (DF or KB) RKB 109' 6. Unit or Property name Kuparuk River Unit 7. Well number 2Z-14 Injector feet At top of productive ~nterval 1255' FNL, 1468' FWL, Sec. 14, At effective depth 1508' FNL, 1117' FWL, Sec. 14, At total depth 1554' FNL, 1052' FWL, Sec. 14, 11. Present well condition summary Total depth: measured true vertical T11N, R9E, UM T11N, R9E, UM T11N, R9E, UM 8305' feet 6317' feet 8. Permit number 85-107 9. APl number 5o--029213§1 lO. 'P°°kuparu- k Ri ver Oi 1 Pool Plugs (measured) Effective depth: measured true vertical 8196' feet Junk (measured) 6247' feet Casing Length Conductor 110 ' Surface 3877' I~e~~e Production 8278' Perforation depth: measured true vertical Size Cemented Measured depth True Vertical depth 16" 255 Sx PFC 100' 100' 9-5/8" 1050 Sx CS III & 3877' 3301' 450 Sx CS II 7" 300 Sx Class G & 8278' 6235' 250 Sx CS I 7622'-7728', 7775'-7784', 7921'-7928', 7944'-7984', 8016'-8025' MD 5864'-5938' 5970'-5976' 6068 6~)~ 109' 6130' -6136' TVD " Tubing (size, grade and measured depth) 3 1/2" J-55 7863' Packers and SSSV (type and measured depth) 12.Attachments - --Des~ript(on-~mm~ry ~pr0'P0s~l Propose conversion fFom water in.iector to wate~ ~Rd gas injectoF. 13. Estimated date for commencing operation September [988 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the~best of my knowledge Signed ,/'~.~ X,~~_~~~- Title .,,/"A.['/ ~,~..'~.~¢.-,..~,....-"z.-',~, ~_]~"~ Date CommisSion Use Only Conditions of approval Notify commission so representative may witness i-'., Plug integrity [] BOP Test © Location clearance ORIGINAL SIGNED BY LONNIE C. SMITH Approved by Approved Copy \\~Returned Commissioner by order of [ 1 the commission Date ~ ~ ~' Form 10-403 Rev 12-1-85 Submit in triplicate Well 2Z- 14 Application for Sundry Approval August 3, 1988 o . . . Propose conversion from water injector to water alternating miscible gas injector. No BOP equipment will be required. The estimated static BHP is 3400 psi at 6200' SS based on data taken in June of 1987. No workover fluids will be required. ARCO Alaska, Inc. Date: May 26, 1988 Transmittal #: 7171 RETURN TO: ARCO Alaska, Inc. Attn: Sabrina A. McKnuckles Kuparuk Records Clerk ATO-111 9 P.O, Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2D-09 2D-09 2Z-14 5-O9-88 Well Test InterPretation Plots 3-1-3-88 #100639H Bottomhole Pressure/Temp. Printout 4 - 25 -'28 - 8 8 # 100648 Kupaurk Operations Engineering Water Injection Spinner Data Sheet Bolh Sands If you have any questions, concerning this or any other transmittals please call me at 265-6835. , Receipt Acknowledged: Date' DISTRIBUTION: D & M State of Alaska- Chevron Mobil SAPC Unocal ' STATE OF ALASKA "-' ALASKA ulL AND GAS CONSERVATION CO.,.,'MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well REV I SED OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [Z~ WATER INJECTOR 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-107 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 029-21361 4. Location of well at surface 9. Unit or Lease Name 1184' FSL, 271' FEL, Sec.ll, T11N, RgE, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1255' FNL, 1468' FWL, Sec.14, T11N, R9E, UM 2Z-14 At Total Depth 11. Field and Pool 1554' FNL, 1052' FWL, Sec.14, TllN, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk Ri ver 0i 1 Pool RKB 109' ADL 25653 ALK 2579 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 06/21/85 06/28/85 06/29/85* N/A feet MSL 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 8305'MD, 6317'TVD 8196'MD, 6247'TVD YES~] NO [] 1822' feetMDI 1500' (approx) 22. Type Electric or Other Logs Run D IL/SFL/SP/GR/Cal/FDC/CNL, CET, Gyro (GCT) 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 100' 24" 255 sx PFC 9-5/8" 36.0# J-55 Surf 3877' 12-1/4" 1050 sx CS Ill & 450 sx CS II 7" 26.0# J-55 Surf 8278' 8-1/2" 300 sx Class G & 250 sx CS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) Perforated w/12 spf, 120° phasing 3-1/2" 7863' 7462' & 7840' 7622'-7728'MD 5864'-5938'TVD 7775'-7784'MD 5970'-5976'TVD 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED Perforated w/4 spf, 90° phasing See attached Addendum, dated 12/29/87~ 7921'-7928'MD 6068'-6072'TVD for fracture data 7944'-7984'MD 6083'-6109'TVD 8016'-8025'MD 6130'-6136'TVD 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS'OILRATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None *Note: Tubing was run and the well perforated 7/13/85. Fractured well 8/18/85. WC4/Sz~ :DAN I Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29., ~ ... ' . 30... . :.,~._ ~.,! : GEOLOGIC MARI~I~-I:IS ' I ' I' 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 7619' 5861' N/A · Base Upper Sand 7730' 5939' Top Lower Sand , 7907, 6059, . Base Lower Sand 8108' 6190' _. ,. 31. LIST OF ATTACHMENTS Addendum (dated 12/29/87) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~ ~ _~J//~-lJ,_~ Title Associate Engineer Date /-/~'~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. -Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 8/18/85 2Z-14 Frac Kuparuk "A" sand perfs 7921'-7928', 7944'-7984' and 8016'-8025' in 7 stages per procedure dated 7/17/85 as follows: Stage 1: 40 bbls 130° diesel w/5% U-66 @ 5 BPM, 3050 psi Stage 2: 33 bbls gelled diesel @ 17 BPM, 5000 psi Stage 3: 37 bbls gelled diesel .5# 100 mesh @ 17.9 BPM, 5050 psi Stage 4: 70 bbls gelled diesel spacer @ 18.8 BPM, 3800 psi Stage 5: 25 bbls gelled diesel 3# 20/40 @ 18.8 BPM, 3600 psi Stage 6: 52 bbls gelled diesel 8# 20/40 @ 18.8 BPM, 3600 psi Stage 7: 70 bbls gelled diesel flush @ 18.8 BPM, 3300 psi Load to recover: 309 bbls diesel Pumped 756# 100 mesh & 15,540# 20/40 in formation leaving zero in casing. Well released to Production. ate~ Mr~ C. V. Chatterton May 27, 1986 Page 3 Well Number Date 1L-5 1R-3 1Q-13 10/2 .... ~. 3/25/86 11/19/85 3/21/86 11/16/85 3/18/86 Well Number Date of Initial Injection Date of Injection Profile 1Y-2 1Y-8 1Y-12 1Y-15 Well Number 2W-2 2W-8 2W-9 2W-10 2W-14 Well Number 3/30/85 8/7/85 3/30/85 8/8/85 3/30/85 8/10/85 0/28/85 3/23/86 Date of Initial Injection Date of Injection Profile 11/15/85 3/26/86 11/15/85 3/27/86 1/13/86 3/28/86 11/15/85 3/29/86 11/15/85 3/31/86 Date of Initial Injection Date of Injection Profile 2X-1 11/4/85 3/22/86 2X-2 11/19/85 3/14/86 2X-3 11/4/85 3/23/86 2X-6 11/4/85 3/21/86 2X-7 11/4/85 3/23/86 Well Number Date of Initial Injection Date of Injection Profile 2Z-3 !!/4/85 4/3/86 2Z-14 12/2/85 4/2/86 2Z-16 12/1/85 4/6/86 VLF'pg'O051 RECEIVED MAYPO Oil C. V. Chatterton, Chairman Well Action 2W-5 Conversion 2W-8 Conversion 2W-10 Conversion 2W-14 Conversion 2W-16 Conversion' 2X-2 Conversion 2X-4 ~Conversion 2X-5 Conversion 2Z-9 Conversion 2Z-11 Conversion 2Z-14 Conversion 2Z-16 Conversion Date Performed 11/22/85 11/15/85 11/15/85 11/15/85 11/22/85 11/18/85 11/18/85 11118185 11/17/85 11/17/85 11/17/85 11/17/85 Page if you have any questions, please T. M. Drumm Kuparuk Operations Coordinator TMD / kmc Attachment (Duplicate) call me at 263-4212. ARCO Alaska, Inc. ,..---.. Post Office [ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 16, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached in duplicate are subsequent notices following wells at the KupaFuk River Field: Well Action Date Performed on the 1L-1 Conversion 11/ 1L-7 Conversion 11/ lQ-2 Conversion 11/ 1Q-7 Conversion 11/ 1Q-11 Conversion 11/ 1Q-13 Conversion 11/ 2B-5 Conversion 11/ 2B-9 Conversion 11/ 2C-1 Conversion 11/ 2C-3 Conversion 11/ 2C-6 Conversion 11/ 2C-8 Conversion 11/ 2D-2 Conversion 11/ 2D-7 Conversion 11/ 2D-11 Conversion 11/ 2D-14 Conversion 11/ 2F-1 Conversion 11/ 2F-2 Conversion 11/ 2F-13 Conversion 11/ 2F-14 Conversion 11/ 2G-3 Conversion 11/ 2G-3 Conversion 11/ 2G-5 ConverSion 11/ 2G-7 Conversion 11/ 2G-10 Conversion 11/ 2~-12 Conversion 11/ 2G-16 Conversion 11/ 2U-3 Conversion 11/ 2U-4 Conversion 11/ 2U-7 Conversion .11/ 2U-16 Conversion 11/ 2W-2 Conversion 11/ 2W-4 Conversion 11/ 18/85 18/85 17/85 17/85 17185 17/85 23/85 23185 19/85 19/85 19/85 19/85 2O~85 20/85 20~85 20/85 21/85 21/85 2~/85 21185 14185 14/85 14/85 14/85 14/85 14/85 14185 RECEIVED 16/85 .~, 16/85 15/8~ 0B & Gas C0n~ ~mmt~Jo~ 22/85 A~:~o~o~ ARCO Alaska, Inc, is a Subsidiary ol AllanlicRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I-IX OTHER [] 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 85-107 3. Address 8. APl Number P. O. BOX 100360, ANCHORAGE, ALASKA 99510 50- 029-21 361 4. Location of Well SURFACE LOCATION- 1184' FSL, 271 ' FEL, SEC. 11, T11N, RgE, UM 5. Elevation in feet (indicate KB, DF, etc.) 1 09' (RKB) 6. Lease Designation and Serial No. ADL 25653 ALK 2579 9. Unit or Lease Name KUPARUK RIVER I. JNIT 10. Well Number 2Z-14 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL POOL 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On November 17, 1985 Kuparuk well 2Z-14 was converted from a producer to a water injector well as part of the full field waterflood conversion effort. Water is being injected into both "A" and "C" sands. the RECEIVED 2 0 1.985 0il & Ga.~ C0ris. C0mmi:..~J' ....... ~., 5; 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~,~, ,~,~- (~/¢,~~ Title KtJPARtJK Date The space below for Commission use OPERAT ION$ COORD I NATOR Conditions of APproval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 .. .-.' -:-:.:.'.~_:._ ' ~ R~TUP,.N TO.' ARCO-ALASKA, INC. KUPARUK OPERATIONS ENGINEERING P,~COBDS' CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 DATE: 10-31-85 TRANSMITTAL NO: 5421 TRANSMITTED HEPJ~WITH APd~ THE FOLLOWING IT~&4S. RECEIPT AND RETURN ONE SIGNED COPY OF T~IS T~a%NSMITTAL. FINALS/ $CHL/ CEMENT <ONW. * OF EACH> ~lA-3 / C~4ENT. EVALUATION TOOL lB-4~ .CEMENT ~VALdATION TOOL -~lR-9 / CET LOG 1R-10~ _CET LOG -'iR- 11 '/CET/CEL ~lR-12/ CET LOG ~2A-13 - CBL/VDL \2A-13 / C~:T/CEL ~2U-3--- CEMENT EVALUATION TOOL -~J2U-10/ CEMENT EVALUATION TOOL ~2Z-13/ CET LOG 2Z-14~ CET LOG '~2' Z-15~ CET LOG 2 Z- 16- CET LOG ~3B-4/ CEM~:NT EVALUATION TOOL ~'3B-12" CET LOG ~3B-12 ~ CEMENT EVALUATION LOG W/ AC ~3B-16 / CEMENT ~VALUATION TOOL ~3C-9 ~'/ CET LOG 3C-10~' CET LOG PLEASE ACKNOWLEDGE 05-04-85 RUN %1 7468-8287 05-28-85 RUN #1 7200-7995 07-17-85 RUN #1 5990-8084 07-16-85 RUN #1 7500-8632 07-25-85 RUN #1 5744-7129 07-26-85 RUN #1 4992-8144 07-13-85 RUN #1 6388-7554 07-24-85 RUN #1 6382-8032 03-26-85 RUN #2 6100-6600 05-19-85 RUN #1 5450-6950 07-09-~ 5 RUN #1 6000-8411 07-09-85 RUN '#1 5500-8173 07-01-85 RUN #1 2700-6617 07-01-85 RUN #1 6100-8011 05-31-85 RUN #'1 6000-7743 07-!4-85 RUN #2 6139-8089 07-06-85 RUN #1 5500-8096 05-09-85 RUN #1 6186-7762 07-14-85 ~UN #1 7485-8210 07-14-85 RUN #1 8190-8805 RECEIPT ACKNOWLEDGED: DISTRISUTION: BPAE DRILLING*BL W. B. CUt{RIE~{ L. JOhNStON '- bXXON CHEVRON MOBIL PHILLIPS OIL D & M NSK CLEkK*BL J. RAT:n/~ELL ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 24, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- 2Z-14 Dear Mr. Chatterton- Enclosed is a copy of the 2Z-14 Well History (completion details) to include with the Well Completion Report, dated 08/12/85. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU11/L123 Enclosure cc- 2Z-14 Well File ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 24, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi ss ion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- 2Z-14 Dear Mr. Chatterton' Enclosed is a copy of the 2Z-14 Well History to include with the Well Completion Report, dated 7/26/85. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU11/L113 Enclosure RECEIVED OCT O 21985 Alaska Oil & G.:!s Cons. Commission An;;horage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday alter allowable has been assigned or well is Plugged. Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an olficial test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" term may be used lot reporting the entire operation if space is available. Accounting cost center code District Alaska North Slope Borough State Alaska County or Parish Field Lease or Unit ~ Well no. Kuparuk River ADL 25653 I 2Z-14 Auth. or W.O. no. ~Tle AFE 603465 I Completion WWS ~1 API 50-029-21361 Operator A.R.Co. W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun Date Complete 7/11/85 Iotal number of wells (active or inactive) on this Dst center prior to plugging and bandonment of this well our Prior stalus if a W.O. 2400 hrs. Date and depth as of 8:00 a.m. 7/12/85 7/13/85 thru 7/15/85 Complete record for each day reported 7" @ 8278' 8196' PBTD, Tst BOPE 9.7 ppg NaC1/NaBr Accept rig @ 2400 hrs, 7/11/85. 250/5000 psi. ND tree, NU & tst BOPE to 7" @ 8278' 8173' WLM PBTD, RR Crude w/diesel cap Perf "A" sands w/4", 4 SPF, 90° phasing f/7921'-7928', 7944'-7984' & 8016'-8025' Perf "B" sands w/5½", 12 SPF f/7775'-7784' & "C" Sand ~/7622'-7728'. Rn 6-1/8" gage ring/JB to 8173'. Rn 246 its of 9.3#, J-55, 8rd EUE, IPC, 3½" tbg. Baker locator@ 7839', retrv pkr @ 7462', SSSV @ 1822', tbg tail @ 7863'. Stab into pkr, space out, drop ball, lnd tbg. Set FHL pkr. Tst tbg; OK. Shear out PBR. Re-lnd tbg. Tst pkr; OK. ND BOPE. NU & tst tree; OK. Displ well w/crude/diesel. Tst SSSV. Shear out b~ll. RR @ 2030 hfs, 7/13/85. Old TD Released rig 2030 hrs. Classifications (oil, gas, etc.) Oil INewTD IPB Oeplh 8196' PBTD Date Kind of rig 7 / 13/85 Rotary Type completion (single. dual, etc.) Single Producing method Oflicial reservoir namels) Flowing Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected For form preparation aS distribution, see Procedures Manual, Section 10, Drilling. Pages 86 and 87_ The above i ....... t AI~,~ 0~/ & Gas Cons. ,A . Commission n~.horage Number all daily well hislory forms consecutively I Page no. as they are prepared for each we I. 1 AR3B-459-3-C Dlvl~Jon of AIlantlcRIchlleldCompany AtlanticRichfieldCompany Dally Well History-Initial Report Prepare and submit the "lltllllt limit" on the first Wednesday alter a well is spudded or workover operetionl ire Illrtcd. Daily work prior to spudding should be summarized on the form giving inclusive dateg only. North Slope Borough IStale Alaska Dl~trtct I County or Perish I Alaska Field ILease or Unit Kuparuk River I ADL 25653 Auth. or W.O. no. ITItle AFE 603465 I Drill Nabors 26-E JWiII no. 2Z-t4 API 50-029-21361 Operator A.R.Co's W.I. ARCO Alaska, Inc. Spudded or W.O. bsgUnspudded IDate 6/21/85 IH°ur 1330 hrs. Ip'°r''''u'''w'°' Date and depth as of 8:00 a.m. 6/21/85 6/22/85 thru 6/24/85 6/25185 6/26/85 6/27/85 Complete record for each day reported 56.24% 16" @ 100 100', (0') RU NU Diverter & Mix spud mud. 16" @ 100 3905', Wt. 8.9s PV 17, ¥? 23s ~ d~verter, CO Kelly. Acc~p~ r~g 0 0600 hr~, 6-21-85. Spud 0 1330 hr~, 6-2~-85. ~rl t k~ek off to 1620~. ~rl to 2651, tr~p to chg short trip, P~H. ~ 93 Jcs 9-5/8", 36~ J-55, BTC csg, circ. P~ 1050 sx Cold Set III, 450 sx Cold Set II, disp w/wtr. Bmp plug w/1500 psi; OK. CIP ~ 2345 hrs, 6-23-85. ~ diverter, NU BOPE. 1447' 14.9~ S54W, 1442 T~, 50 VS, 34S, E37 1732', 25.5~, S58W, 1709 T~, 148 VS, 86S, El20 2204', 39.7~, S57W, 2103 T~, 406 VS, N219, E341 2550', 43.9~, S53W, 2361 T~, 635 VS, N345, E533 9-5/8" ~ ~ 4230' (325'), D~G Wt. 8.9, PV 17, YP 6, PH 9.5, ~ 14, Sol 3 RIH, tag float ~ 3792', drl cmt +10' new hole. Tst fo~tion to 11.5 ~, drl to 3945', trip f/motor, drl to 4124'. Trip f/new ~tor, drl to 4230'. ' Zil~ ~ '/(c.(~ 9-5/8" ~ ~' _~7~, 6240' (2010'), wt. 9.2, PV 9, YP 5, P~ 9.5, ~ 7.6, Sol 73 Drl f/4230' -6240'. 4590',49~, SSIW, 3767 ~, 2112 VS, [179S, 1753 5065', 45.3~, S54W, 4090 ~, 2400 VS, 1382S, 2035 5592', 48.8~, S58W, 4438 ~, 2856 VS, 1598S, 2367 6062', 46.9~, S55W, 4753 ~, 3205 rS, t789S, 2658 9-5/8" ~ ~ .~~. (20t0'), D~G ~,&' Wt. 9.7, PV 12, YP 8, PH 9, ~ 67.~ Sol 7 Nevi Drl f/6240'-7764'. Trip to the ~. 6528', 44.7~, S54.2W, 5078.3 ~, 3538.9 VS, 2003.0S, 2917.2W - 7223', 46.1~, S55.2W, 5550.2 ~, 4049.0 VS, 2292.1S, 3337.8W ' The above is correct Signature For form preparation and distribution. see Procedures Manual, Sectich 10, Drilling, Pages 86 and 87. AR3B-459-1-8 Alaska Oil & Gas Cons. CorllmJssJon Number all daily well"h'i'~'l~'~./'f~r~conseculivsly as mey are prepare~ for each we . jPagelno. ARCO Oi, and Gas Company Daily Well History-Final Report nstructions: Prepare and submit the "Final Rlport" on the first Wednesday oiler allowable has been assigned or well is Plugged. Abandoned. or Sold. "Final Report" should be submitted also when operations are suspended for an ndef n te or apprec able ength of hme. On workovers when an official tesl ~s not required upon completion, re[~3rt completion and representative test data in blocks provided. The "Final Report" form may be used for reoorting lhe entire operation if space is available. JAccounlmg cost center code District ICountyor , ,..s' "I Alaska North Slope Borough I Alaska Field Lease or Unit Well no. Kuparuk River ADL 25653 2Z-14 Auth. or W.O. no. ~ Title AYE 603465 I Drill Nabors 26E API 50-029-21361 Operator IA.,.co. w.,. Fotal number of wells (active or 'nact've) on thisI ARCO Alaska, Inc. 56,24% Icost center prior to plugging and J abandonment o! this well 6/21/85 1330 hrs. Spudded or W.O. begun Spudded Date and depth as of 8:00 a.m. Old TO Released rig 6/28/85 6/29/85 thru 7/01/85 Complete record for each day reported 9-5/8" @ 8305' TD (541'), TIE Wt. 9.7, PV 10, YP 9, PH 9, W-L 5.8, Sol 10 Drl to 8305' TD, wiper trip. POOH to log. SOS log f/_~-3876~' w/DIL/SFL/SP/GR/CAL/FDC/CNL. TIH w/BHA #8. 7" @ 8278' 8196' PBTD (0'), RR 9.7 Brine TIE to TD. C&C hole. POE, RU & RIH w/205 its 26# J-55 HF ERW, TC csg. Lad @ 8286'. C&C hole. Cmt 7" w/200 sx CL "G", w/3% KC1, 2.5% D-19, 1%, D-31, .25% R-5, & .29% D-6, followed by 300 sx CL "G" w/3% KCL, .7% D-19, 3% D-31. Displ w/9.7 brine. Bmp plug, tst csg to 3000 psi; OK. CIP 0730 hfs, 6-29-85. ND, set slips, cut off, set pkoff, NU tbg spool, tst pkoff @ 3000(~; OK. NU lwr tree. AP w/250 sx Cold Set I, 60 bbl AP. CIP @ 1400 hfs, 6-29-85. RR @ 1500 6-29-85. New TD J PB Oeplh 8305' (6/27/85) 1 8196' PBTD Date Kind of rig 1500 hrs. 6/29/85 Rotary Classifications (oil. gas, etc.) Oil Type combletion (single. dual. etc.) Single Producing method Official reservoir name(si Flowing Kuparuk Sands Potential test data Well no. i Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size TP. C.P. Water % GOR Gravity Allowable Effective date corcecled The above is correct Signature_~d-~ ~j~.__O ~---~ Date~.f,~-- [,t,e I< E C Ll~r~J~r~%/L [j~perintendent For form preparation an(r'aistr~bution. see Procedures Manual. Section 10. Drilling, Pages 86 and 87. AR3B-459-3-C Alaska 0ii & Gas Corm. Commission Olvl~ of All~l~EhfleldC~y ARCO Alaska, Inc.~ ....... Post Office L._^ 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 Kuparuk River Unit. As discussed a single "blanket" sundry notice (form 10-403) has been completed for all well proposed to be converted to water injection. Individual subsequent sundry notices will be filed when the actual well conversions occur. As stated in form 10-403, well conversion to water injection will occur in two primary stages. The first stage will convert approximately four wells per drillsite ~o 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 $ EP o 0~ & G~s Co~s. Co,'nmJssJo~ At, chorale 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 OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well N/A 5. Elevation in feet (indicate KB, DF, etc.) N/A 12. 7. Permit No. see attached 8. APl.Number 50- see attached 9. Unit or Lease Name Kuparuk River Unit 10. Well Number see attached 1 1. Field and Pool Kuparuk River Field I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool see attached 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 X~ 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). Pursuant to form 10-403, it is proposed that the attached list o~^pr0ducing 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. RECEIVED SEP 2 0 19B5 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 Kuparuk Operations Coordinator Date The space below for Commission use 9/18/85 Conditions of Approval, if any: Approved by Form 10-403 Rev. 7-1-80 COMMISSIONER Subsoquent Wo.fl~ R~ By Order of O ,,-, ,-, ~,~ / the Commission Date /- ~ ) ~z~:2 / Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate -1 -1 -1 2X- 1 - 2 - 3 - 4 - 5 - 6 - 7 - 8 2Z- 2 3 6 8 9 11 14 16 223 237 239 83- 84 103 .109 118 107 110 113 114 83- 80 85 77 38 85-138 107 109 21239 21253 21255 029-20963 20982 20987 20995 20985 20988 029-20991 20992 029-20960 20964 20957 20924 21377 21379 21361 21363 25645 I! 25645 25653 25646 25653 25646 2576 2576 2579 2577 2579 I! 2577 10 10 12 10 12 10 12 12 10 12 10 /15 /15 /15 /85 /85 /85 /15/85 /15/85 /15/85 /15/85 /15/85 /15/85 /15/85 115185 lO/15/85 lO/15/85 10/15/86 lO/15/85 12/15/85 12/15/85 12115/85 12/15/85 MARK:0093 RECEIVED S.~'r~' 2 0 Alaska Oil & Gas Corm. Anchora~.~ RETUKN TO: ARCO Alaska, In/~"'~ Post Office 3x 100360 Anchorage/Alaska 99510-0360 Telephone 907 276 1215 DATE: 09-05-85 TRANSMITTAL NO:5332A **CONTINUATION ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED HERE%~ITH ARE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RECEIPT AND RETUR/~ ONE SIGNED COPY OF THIS TRANSNITTAL. FRC~4 ~{ELL SEKVICE ~EPOKTS/PRESSURE DATA SEQUENCE OF EVENTS 2G-9 -"- PBU 08-22-85 2G-9'~'- PDU 08-21-85 2G- 11'"' PBU 08-19-85 2G-16 J SBHP 08-19-85 2h-l-- PBU 08-25-85 2h-l--' PBU 08-24-85 2U-l'~ 'C' SAND PBU 08-23-85 2U-l/ END 'C' SAND PBU & ~iISC. 08-24-85 2W-7 "' 'C~' SA~D PBU 08-17-85 2W-7/ 'C' SAND PBU 08-23-85 2W-7// 'C' SAND PDU 08-22-85 2X-11' _ PBU 08-24-85 2X-ll/ 'C' SAND PBU 08-25-85 2X-ll/ 'C' SAND PBU 0~-26-85 3C-5 / BhP & M1SC. 08-29-85 3C-7--~ BHP & FiISC. 08-30-85 3C-8 / BHP & MISC. 08-31-85 3C-9/- BHP & MISC. 08-09-85 3C-10 /'BHp & MISC. 08-10-85 KUPARUK WELL PRESSURE REPORT ENVELOPE FACES: 3C-12/ STATIC 'A' SAND 07-24-85 3C-10.~- STATIC 'A' SAND 08-10-85 3C-9 / STATIC 'A' SAND 08-09-85 2Z-16-- 07-21-85 2Z-i5 '- STATIC 'A' SAND 07-17-85 2Z-14.- STATIC 07-20-8 5 2Z-13" STATIC 'A' SAND 07-17-85 2X-4~ 'PBU 08-12-85 2X-4" PBU 08-13-85 2U-l'- , 08-24-85 2A-13~ STATIC 08-25-85 iR-10~ STATIC 'A' SAND U8-15-85 1R-9 /' STATIC 'A' SAND 0B-14-85 CAMC 0 OTIS OTIS OTIS OTIS OTIS OTIS CAMCO CAMCO OTIS CAMCO CALICO CAMCO KECEIPT ACKNOWLEDGED: DISTRIDUTION: sPAE* DRILLING W. PAS~ER B. CURRIER L. JOHNSTON EXXON CHEVRON* ~OBIL* PHILLIPS 0IL* ~ & M* NSK CLERK J. RAT~MELL* DATE: '"' ~',,,';;;,z',: . STATE OF ALASKA* '.'.',:,....: ...... ;~ SOHIO* UNION* K.TULIN/VAULT ARCO Alaska. Inc. is a Subsidiary of AtlenticRichfieldCompany ARCO Alaska, Post Off Box 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 DATE: 08-30-~5 TRaNSHITTAL NO: 5313 RE'£U RN TU: aRCO ALASKA, Ii~C. KUPARUK OPERATIONS ENGINEERING -- RECOkDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 9951'0 TRAHSMITTED HEREWITil ARE THE RECEIPT AND iddTURN ONE bIGNED COPY OF THIS TRANSMITTAL. '~LE FINALS/SCHL/OI'Ii~ * OF EACH PLEASE NOTE--. THIS LOG IS A "TWO IN ONt~". ONLY THE THIRD FOLLOWING ITEMS. PLEASE ACKNO%~LEDGE DE USED FOR 'fRANSI~IITTING. DIL/SFL 06-04-8 INTERVAL %VILL COMP. NEU/LITi~O. DEa-PURO COMP. N~.'U/LITIiO. DEN-PORO CO[.i P. NEU/L I'fhO. DEN-RAW CUI,IP. NLU / LITHE. DEN-RAW LONG SPACING SONIC-GR LONG SPACING SONIC-GR cPTR PRuCLSSLD LUG DU~ DIPMETER MICROLOG-GR PU RO PORO t{A~ 5 iiUN #3 2864-7090 06-04-85 RUN #3 2864-7090 06-04-85 RUN #3 2866-7162 06-04-85 RUN #3 2866-7162 06-04-85 i/UN #3 2866-7162 06-04-85 RUN #3 2866-7162 06-04-85 RUN #3 2864-7057 06-04-85 RUN #3 2864-7057 06-0 4-~ 5 RUN #3 2~66-7049 06-04-85 RUN #3 2864-7100 06-04-85 RUN #3 2~64-7059 DIL/SFL-GR DIL/SFL-GR DEN/NEU DEN/NEU DEN/NEU DEN/NEU CYCEtcLOUK 06-28-85 RUN #1 3876-B285 06-28-85 RUN #1 3876-~285 06-28-U 5 RUN #1 4000-8259 06-28-85 RUN #1 4000-8259 06-28-~5 RUN ~1 4000-0259 06-28-85 RUN #1 4000-8259 06-28-85 RUN #1 7400-8236 RLCEIPT ACKNO~¢LEDGED: t3. CUKRIEt{ CIiEVI{uN D & a*BL DI~'f~iIBUTiUN: DkILLING*BL W. PASHEk L' JuHNb'fUN EXXON MOBIL PHILLIPS OIL NSK CL Ei~K*BL J. "-"'DATa,taka 0ii 8, Gas 0OHS. STATI~ OF ALASKA*BL SOHIU /SE UNION RATt¢iELL*BL K .TUbIN/VAULT*FILM ARCO Alaska. Inc. is a Subsidiary of AllanlicRichfieldCompany STATE OF ALASKA ALAS¥~ OIL AND GAS CONSERVATION CONMISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 TO: AJ.a~ Oil and Cas Conservation ~'~ ' ' ~'O~ASSIO~ SO01 Porcupine Drive ,Z,..,"h,-,':. s. · Receipt of the following material /4~; / which was transmitted via is hereby acknowledged: ~UANTiTY /~g/~ ~. ~J~_ DESCRIPTION ' /~. ~ ~_ /~ ~ ~ ~ ~ f - s -often_ q/ ~ _ 0~~ ~ I~ -- ~ z-If m~?~ e~/~ ~?~ ~. DATED: Copy sent to sender YES . NO _~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COaMISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 State of Alaska T'~l:a 0ii and Cas' Consen,a~cn Co~isdo~ 2001 Porcupine Drive Pmchorage, Alaska 5~501 Receipt of the following material whiCh was transmitted via ~i/ is hereby acknowledged: ,QUANTITY .... Copy sent to sender YES NO ~_ ARCO Alaska, Inc. Post Office Bo., ,00360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 14, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi ssi on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- 2Z-14 Dear Mr. Chatterton' Enclosed are the Well Completion Report and gyroscopic survey for 2Z-14. I have not yet received the Well Histories. When I do, I will fOrward copies to you. If you have any questions, please call me at 263-4944. Sincerely, d. ~ruber ^ssoc~ate Fn~neer JG/tw GRU10/L121 Enclosure RECEIVED 2 0 1985 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA£ .AND GAS CONSERVATION CO "i~ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL I~IX GAS [] SUSPENDED [] ABANDONED [] SERVICE [] · :~. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-107 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21361 4. Location of well at surface 9. Unit or Lease Name 1184, Fs,, 271, FE,, Seo.11, TllN, RgE, UM i~^T,0N~' Kuparuk River Unit , At Top Producing Interval VERIF~D ~ 10. Well Number 1255' FNL, 1468' FWL, Sec.14, T11N, RgE, UM· ,-.. -..-~,%ur~ ~' i 2Z-14 At Total Depth ~,B-'-~'~I 11. Field and Po°l 1554' FNL, 1052' FWL, Sec.14, T11N, R9E, UM ........... Kuparuk River Field '5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 109' RKBJ ADL 25653 ALK 2579 12. DateSpudded 13. DateT.D. Reached 14. DateComp.,Susp. orAband. 115. WaterDepth, ifoffshore 116:'No. of Completions 06/21/85 06/28/85 06/29/85*I IN/A feet MSL 1 17. Total Depth (MD+TVD) 18.Plug Back Depth(MD+I'VD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 8305'MD,6317'TVD 8196'MD,6247'TVD YES [~X NO [] 1822 feet MDI 1500' (Approx) 22. Type Electric or Other Logs Run D IL/SFL/SP/GR/Cal/FDC/CNL, CET, Gyro (GCT) 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# ' H'-40 Surf 100' 24" 255 sx PF "C" 9-5/8" 36.0# J-55 Surf 3877' 12-1/4" 1050 sx CS III & 450 s; CS II 7" 26.0# J-55 Surf 8278' 8-1/2" 300 sx Class G & 250 s~ CS I ,, 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7921' - 7928' w/4 spf, 90° phasing 3-1/2" 7863' 7462' & 7840' 7944' - 7984' 8016' - 8025' 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 7775' - 7784' N/A 7622' - 7728' w/12 spf, 120° phasing . . 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL~BBL GAS-MCF WATER-BBI' OIL GRAVITY-APl (corr) Press. 124-HOUR RATE I~ 28. CORE DATA K I" ( I" I \/ F r~ Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips.- -- NONE AUG 2 0 1985 Alaska 0il & Gas Cons. C0mrnissi0n ~ Anch0ra,ge Form 10-407 * NOTE: Tubing was run and the well perforated 7/13/85, TEMP/WC81 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE · · 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 7619' 5861' N/A Base Upper Sand 7730' 5939' Top Lower Sand . . 7907' 6059' Base Lower Sand 81-08' 6190' _ , . · 31. LIST OF ATTACHMENTS Gyroscopic Survey (2 copies) :32. I hereby certify that the foregoing is true and correct to the best of my knowledge 'Signed ///(~~ _~-'_ Title Associate Engineer Date. INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate Whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27.' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". ARCO Alaska, Inc. Posl Oflice Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 08-0 8-85 TRANSMITTAL NO: 5285 ~TURN TO: - 2KANSMITTED ~(ECEIPT AND iN BOX 1 OF 3PEN ~OLE LI 3C-11 06-2 ARCO ALASKA, INC. KUPAIv, UK OPERATIONS ENGINEEkING t(ECOixD~ CLEkK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 HI..'RE~4ITH ARE THE FOLLOWING ITEMS. ACKNO~¢LEDGE RETURN ONE SIGNED COPY OF THIS TKANSMITT/~L. 2: S TAPES PLUS 3.-85 RUN # LISTINGS (ONE COPY OF EACH) 1 4427.5-8881.5 REF #70597 RUN ~1 1785.0-8987.5 ~EF #70620 RUN #1 3920.0-8332.5 REF #70642 RUN #1 4617.5-8747.5 REF #7U706 RUN #2 3280.0-6803.5 EEF #70229 RUN #1 4021.5-8261.5 REF #70641 RUN ~1 2190.5-9257.0 REF #70598 RUN ~1 3273.0-7270.5 REF #70555 RUN #1 2092.0-8415.0 REF #70634 RUN #1 2658.0-6620.0 REF #70562 RUN #1 3876.0-8334.0 REF #70600 RUN #1 4180.0-8538.5 REF #70639 RUN ~1 4409.0-9412.5 REF #70661 RUN #1 3531.5-7534.0 REF #70704 ~C-10/ 07-02-85 3C-9~-- 07-10-85 ~C-7~ 07-31-85 3B-14- 03-20-85 3B-12' 07-03-85 3B-11~ 06-26-85 3B-10~ 06-17-85 3B-9"'- 06-10-85 21-15" 06-19-85 21-14/ 06-28-85 !Z-13' 07-05-85 iZ-12-- 07-20-85 iZ-11~ 07-27-85 _N BOX 2 OF 2: · ~PJ/N_,.HOLE LIS TAPES PLUS LISTI :W-16.~/" 01-28-85 RUN #1 31 ~:V-14~/ 05-16-85 !V-12 u/ 04-22-85 U-lO~ 04-11-85 U-7 ~,¥~ 03-1.9-85 A- 13-,'-' 07-16-85 R-13'';~ 07-27-85 R-12 '~''' 07-20-85 R-ii/,' 07-13-85 _R-10~''''' 07-06-85 R-9// 06-28-85 'R-7// 06-04-85 RUN #1 RUN #1 RUN #1 }(UN #1 kUN #i RUN #1 i~UN ~1 t~UN #1 RUN #1 RUN #1 &3 NGS (ONE 16.0-7038.5 3047. 0-7086. 5 3960.0-9265.0 2972.0-7063.0 3594..5-8179.5 7649.5-8160.0 3940.0-8578.0 3935.0-8277..5 3810.0-7213.5 2991.0-8738.0 399'1.5-8131.0 0045.5-7103.0 COPY OF EACH) P, EF ~ 70436---REVISED F, EF ~ 7 U 614---1-LEVI SED REF #70613---kEVISED ~- F, EF # 70612---kEVI :SED -- P, EF # 70505---i-(EVISED -'" P,~F #70645 REF #70702 KEF # 70660 REF #70643 I{EF #70640 REF #70601 kEF 970509 ECEIPT ACKNO%~LEDGED: PAR · CURRIER iEVRON & ~4 D~IbLING L. JOHNSTON MOBIL NSK CLERK DISTFd[BUTION: W. PASHER EXXON PHILLIPS OIL J. RATHMELL DATE: ~1~<; 9? ~ ~-~.~'"~ Cons. Commission STATE OF ALA~I{A*- '~ SOHIO UNION K.TULIN/VAULT TO: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO¥~MISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 transmitted via is hereby acknowledged: A]aslra Oil and Gas Consen',~tion CommlsMon ,e .. Porcup~;~e Drive Anchorage, ~' .. ~,.s~... 90501 Receipt of the following material which was QUANTITY /~. DESCRIPTION ~-_ ¢¢~g /F--~-¢e~ - 3~¢/-~73/ . . RECEIVED: DATED: Copy sent to sender YES NO ~ STATE OF ALASKA ALASKA 0IL AND GAS CONSERVATION CO~iMISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 TO: State of _~Maska Alaska Oil and Gaz Conservation Commi~sio~ 3001 Porcupine Drive knchorage, 7alaska §9501 RE: transmitted via Receipt of the following material whiCh was / is hereby acknowledged: QUANTITY DES CRI PTION __ _ ~v .--~ ~ ~ ,__ Copy sent YES __ to sender ~0 ~t ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 30, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- 2Z-14 Dear Mr. Chatterton- Enclosed is the Well Completion Report for 2Z-14. I have not yet received the Well Histories. When I do, I will forward copies to you. Also, the bottomhole location and TVDs will be submitted when the gyroscopic survey is received. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRUIO/LIO0 Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA~. -ANDGAS CONSERVATION CC ~,IlSSION 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. 85-107 ,. 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21361 4. Location of well at surface 9. Unit or Lease Name 1184' FSL, 271' FEL, Sec.ll, TllN, RgE, UM Kuparuk River Unit At Top Producing Interval 10. Well Number To be submitted when gyro is run. 2Z-14 At Total Depth 11. Field and Pool To be submitted when gyro is run. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 109' RKBI ADL 25653 ALK 2579 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 06/21/85 06/28/85 06/29/85*I N/A feet MSL] 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 8305'MD 8196'MD YES [] NO D~ 1822 feet MDI 1500' (Approx.! 22. Type Electric or Other Logs Run D I L/SFL/SP/GR/Ca 1/FDC/CNL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESlZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 100' 24" 255 sx PF "C" 9-5/8" 36.0# J-55 Surf 3877' 12-1/4" 1050 sx CS III & 450 sd CS II 7" 26.0# J-55 Surf 8278' 8-1/2" 300 sx Class G & 250 s) CS I ., . , 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) -, 7921' - 7928' w/4 spf, 90° phasing 3-1/2" 7863' 7462' ~ 7~40' 7944' - 7984' 8016' - 8025' 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 7775' - 7784' N/A 7622' - 7728' w/12 spf, 120° phasing --. 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED,~ OIL-BBL GAS-MCF WATER-BBL OIL GRAvITY-APl (corr) Press. :24-HOUR RATE "IF 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 * NOTE: Tubing was run and the well perforated 7/13/85. TEMP/WC63 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GoR, and time of each phase. . . . ... To be submitted w~ ~n gyro is run. N/A . . 31.'LIST OF ATTACHMENTS ' . . ' . None 32. I hereby certify that the.foregoing is true and correct to the ~st ot my knowledge . 7- 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. i:tem 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 fror~ ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". SUB.SURFACE DIRECTIONAL SURVEY ['~ UIDANCE [~JONTINUOUS '['~OOL Company Well Name Field/Location ATLANTIC RICHFIELD COMPANY -- 2Z-l~ /~184' FSL. 271' FEL..~1l. T11N. RqE- ,KUPA~,UK~ NORTH SL,OPE~ ALASKA -- Job Reference No~. 70665 Loaaed Bye: MURTLAND RECEIVED Alaska 0i! & (]as Cons. ~rage Oat__~e 24-JULY-1985 Computed B~.' BOLAM * 8CHEU~B£RG£R e CUSTOMER FOR ARCO AbASKA, [NC, 2Z-14 KUPARUK NORTH SEOPE~AbASKA SURVEY DR?El 9 dub 85 ENGINEERI MUR?bAND METHODS OF COMPUTATION ?OOb bOCATIONI TANGENT[Ab- averaged devtatlon and azimuth ~NTERPOLaTIONI I, INEAR VERTZCAb SECIIONI HORTZ, DIST, PROJECTED ONTO A TARGET AZIMUTH OF &OU?H 55 DEG SO HIN WES? ARCO 2Z-14 KUPARUK NORTH SbOPE~ALASKA COMPUTATION DATEI 24-dUb-B5 DATE OF SURVEY 9 JUb 85 KEbb¥ BUSHZNG Ib£VATZONI ENGIN£ERI MURTbAND INTERPObATEO VAbU£$ FOR [VEN 100 FEET OF MEASURED DEFTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERT)CA DEVIATION AZIMUTH DEPTH D~PTH DEPTHb DEG MIN D£G MIN 0 O0 '109,00 lO0 O0 '9,00 0 0 N 0 0 E 0 14 N 22 52 W 0 6 S 8O 54 ,W 0 6 lq 36 577, W 0 13 N 29 177 W 014 N '7926 W 0 '7 N lO 23 W 0 20 N 33 5i W 0 5 N 15 52 W 0 13 N 15 19 E 0 O0 100 O0 ~00 O0 30O O0 40O O0 50O O0 60O O0 ?00 O0 800 O0 900 O0 1000 O0 2OO 3O0 4OO 5OO 6OO 7OO 799 899 O0 O0 O0 O0 O0 O0 99 99 S 39 i? W 835 77 W S 46 2 W 8 52 3 W 8 54 15 .W 8 59 22 W S 37 W 8 56 577 W 1100 1200 1300 1400 1500 1600 I?00 1800 1900 O0 1099 O0 1199 O0 1298 O0 I397 O0 t493 O0 1588 O0 1680 O0 17770 O0 i857 91,00 19! O0 29! O0 391 O0 491 O0 59i O0 690 99 7790 99 999 99 890 99 0 96 99096 236 68 1090 68 5 38 84 1189 84 9 001,8800132 54 1,84 54 i7 o 14779 30 20 16 75 ~77 38 63 177748 63 31 29 O0 2~00 2300 2400 2500 2800 2900 50 34 3! S ~9 377 W 39 $ 5~25 W 62 39 48 S 5 13 W 39 4 ~ 55 15 W 35 44 41 $ 52 ~ 44 53 8 54 11W ? 4 45 0 $ 54 44 W 62 45 3 8 55 16 W oo O0 oo O0 21 O0 2253 O0 2328 ,00 2400 O0 O0254{ O0 2612 50 1812 42 19 3 63 9 ! 62 1068 39 214~' 04 35 229! 243~ · 250'3 3000 O0 2683 38 2574.38 44 577 3100 O0 2754 18 2~45.i8 44 577 3200 O0 2824~ 2715,85 45 11 3300 O0 2895 2786,18 45 20 3400 O0 2965 40 2856,40 45 26 3500 O0 3035 55 2926,55 45 30 3600 O0 3105 66 2996,66 45 26 37700 O0 3~75 96 3066,96 45 14 3800 O0 3 46 63 31377.63 44 48 3900 O0 33177 68 3208,68 44 29 8 55 38 W 8 55 51 W 856 9W 856 9 W 856 9 W i 8 S6 X9 W $ 56 23 W 856 31W 8 56 2~. W 8 S6 ~5 W PAGE 109,00 r~ 951 60 48 94 0 0 0 0 0 0 0 0 0 I 0 O0 O0 0 O0 0,00 N 0 06 0 06 0,08 N 43 5 w o,, oo , 0 21 O~ 22 .N, 0 35. 0,41 a 59 ~3 0 73 53 N i 68 ~,27 N 49 I 50 ~ 4.9 W 2,39 N 39 2,56 2,58 N 3 30 2~ ~ 7.47 9.~4 46 66 3 46 '9 II i ~4.~ ~ 66.8940'9i sS 98 4 5 80,72 98.74 50 136 40t 29 ~ ~ S 4 ~t3.,80 136,48 , o, .o 3.04 600 3'31 508 08 600;40 8o0.e3 0,3i 8 i S 56 W E TR TCAL, DOGbEG RECTANGUbAR COORDINATE& HORIZ, DEPARTURE V,~ECTION SEVERI?¥ NORTH/SOUTH EAST/WEST DIST, AZIMUTH r EET DEG/iO0 FEET FEET FEET DEC MIN ARCO ALASKA, [NC. KUPARUK NORTH SLOPE,ALASKA TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG M~N COMPUTATION DATE~ 24-JUL-85 PAGE 2 DATE Or SURV£YI 9 JUL 85 KELLY BUSHTNG EbEVATIONI ENGINEERI MUR?bAND INTERPOLATED VALUES FOR EVEN 100 FEET or MEASURED DEPTH VERTICAL DOGLEG RECTANGULAR COORDTNATE$ HORIZ, DEPARTURE S£CTIflN SEVERITY NORTH/SOUTH EAST/WEST DI8~:,: AZIMUTH FEET DEG/.IO0 FEET FEE~ rE~l DEC MIN 109,00 PT 4000 O0 4i00 O0 3460 4~00 O0 3530 4300 O0 3599 4400 O0 3665 4500 O0 3730 460O O0 3796 4700 O0 3862 4800 O0 3928 4900 O0 3997 33.89 34 3280.34 43 58 75 3351.75 45 15 64 3421.64 45 55 42 3490,42 47 41 47 3556,47 49 7 67 3687.67 48 50 5~ 3753,53 48 44 87 3819,87 47 35 17 3888,17 46 38 5000 O0 4066 23 5~00,00 4!36 SO 5200. 4206 94 .00 47 5{ 3957 4027 4097 4163 O0 5300 O0 5400 600,00 4468 5700,00 4534 5800.004601 S900,00 4669 23 4359 6! 44 57 4560 50 44 4 47 49 39 48 39 6~ 48 7 74 47 30 57 47 6 6000 O0 6i00 6200 6300 640O 6500 6600 6700 680O 6900 4737 76 4628 76 46 48 O0 4806 38 4697 38 46 31 O0 4875 37 4766 37 46 16 48 O0 4944 O0 5014 O0 5085 oo O0 O0 52~2 O0 5359 71 483~ 90 490 90 4976 20 5048 5~8~ 99 5250 71 45 90 44 58 90 44 38 ~0 44 39 64 47 45 96 48 19 99 47 39 7000,00 5427 7100.00 5495 200,00 5564 300,00 5634 7400.00 5704 500 O0 5775 800 O0 5847. 700 O0 5918 7800 O0 59n7 7900 O0 6054 67 5318 845386 87 5455 47 5525 94 5595 91 5666 65 5738 5809 54 23 587~ 36 594 87 4610 47 45 32 944456 91 44 1 6544 ~2 54 4540 234722 36 48 9 S'56 3 W 165q.79 S 5723 W 1729.79 S 6022 W 1801.17 S 57 43 W 1873.58 S 55 6 W 1948,65 $ 52 4a ~ 2024.19 S 5223 W 2099,43 S 52 3 W 2!74.54 S 53 2 W 2249,20 $ 54 22 W 2322,21 $ 54 33 W 2394.51 S 54 37 W 2465.65 S 55 26 W 2764,06 S 55 30 W 2839.43 8'55 15 W :80 SS 5555 5 W 3~34,.94 S 54 55 W 07 $ 54 56 ~ S 55 32 ~ ~? $ 55 2 W 37~ 54 74 54 44 W 3858 54 3t W 393{ 54 6 W 4003 53 44 W 4075 53 3O w 4146 53 i W 4216 53 17 W 4286 54 14 W 4356 53 53 W 4429 53.59 ~ 4503 35 94 57 64 0,44 91856 1382.54 1659 87 5624 0.53 99383 1502,32 ~ 1801.30 30 W 5,07 i03050 a i564,95 1873 0.96 i07250S 1627,17 194883 0'9i i11688 $ 1688.35 ~2024 33 3,990,560'2i ii62;7,1254,651208,79 ~ 1748,18t807,68W~ 2174~0995359 1925,94 W 2322 23 56 I W !,06 1339,54 i984,78 2394,52 55 59 2042,80 2465,65 55 2i62,60 261i,79 0,32 1507,39$ 22~5,$7 W 2688.X0 0.37 1550.3! 8 2288,25 w 2764,06 S 0,43 1593.09 2350,4t 28]9,43 55 52 w 0.540,69 1635,37Il ~ ~5* ~t W 1677,32 ~ 2412,09 2914,23 0,54 1719'10 2533,64 w 3061,80 5 W 0'68 1760,'90 2593,6? 3134,94 49 0,58 1802,65 ~ ~ i 55 2653,23 3207.68 4 W 0,75 1885,53 ~ 0,'9~ 1926'6! 2829,72 3423 32 2886.98 3493 72 ~ 4216' 61W 4357 55 W 28 W 4503, COHPUTATION' DATEI 24-JUL-85 PAGE 3 ARCO AbASKAt THC. DATE OF SURVEY1 9 JUL 85 2Z-t4 KELLY BUSHING EbEVATZONI KUPARUK NORTH SLOPEtALASKA ENG~NEERI MURTbAND INTERPOLATED VALUES FOR EVEN 100 FEET or MEASURED DEPTH TRUE SUB-SEA COURSE VERTZCAL DOGLEG RECTANGULAR COORD~NATES HORIZ, DEPARTURE MEASURED VERTICAIJ VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST D[$T, AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/iO0 FEE~ FEET FEET DEG MIN Bt00 O0 $185 23 6076,23 50 5 S 54 27 W 4654,80 1 0) 264?,35 $ 38 ,8? W 46~4,{!? $ 55 20 W ~200,00 29 6 ,29 ~0 9 S 54 ~3 W 473~ 56 0 O0 269[~7~ $ ~8 , 8~00,00 36 6 ,36 50 9 S 54 43 W 4808.33 0 O0 2736,09 S 395 W , S SS t9 ~ 8305,00 6316 57 6~07,57 50 9 S 54 ~3 W 4812,~? 0 O0 2738,3[ S 395 ~ 48t2, $ 55 t9 ~ 109,00 r~ COHPUTA?ZON DATEI 24-JUL-85 PAGE 4 ARCO ALASKA, KUPARUK NORTH SLOPE,ALASKA ENGZNEERI MURTbAND 10g,o0 PT iNTERPOLATED VALUES FOR EVEN tO00 FEET DF MEASURED DEPT TRU£ SUB-SEA COURSE MEASURED VERTICAL VERTTCAb DEV2ATION AZIMUTH DEPTH DEPTH DEPTH DEG MZN DEG M2N VERTICAL DOGLEG RECTANGULAR COORDINATES SECTION SEVERITY NORTH/SOUTH EAST/WEST FEET DEG/IO0 fEET FEET HOR~Z,~ DEPARTURE DIST AZIMUTH FEET 0 O0 000 000 4OOO 5000 6000 70OO O0 999 O0 t941 O0 26~3 O0 33R9 O0 4066 O0 4737 O0 5'427 O0 6120 O0 6316 0 O0 -109 O0 0 8 44 5? 34 3280 34 43 58 23 3957 23 45 54 76 4628 76 46 48 67 5318 67 47 49 601t 49 49 8 57 620? 57 50 9 N 0 0 E 0,00 S 39 17 W 0,29 S 59 37 W 283,9! S 55 38 W 95!,60 S 56 3 w 1659,79 S 55 S W ,94 S 54 44 W 58,35 $ 54 6 W 4578.62 S 54 43 W 4812 0,00 O' 0 ,25 ,44 1,06 0.68 0,~! 1, 2 0,00 ARCO AbASKA, XNC, 2Z'14 KUPARUK NORTH SLOPE~ALASKA TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAb DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MTN 0.00 9,00 209.o0 209 309,00 309 409.00 409 509,00 509 609.00 609 ?09,00 709 809,01 809 909,01 909 COMPUTATION DATE{ 24-JU6-85 PAGE 5 DATE OF SURVEYI 9 JUb 85 KELhY BUSH{NO EbEVAT{ON{ ENGINEERI MUR?bAND INTERPOLATED VALUES FOR EVEN 100 FEET OF SUBmSEA DEPTH VERT{CAh DOGbEG R£CTANGUbAR COORO2NAT£~ HOR2Z,- DEPARTURE SECTION SEVERITY NORTH/&OUTH EAST/WEST DIST, AZIMUTH FEET DEG/IO0 FEET FEET rE~T OEO MIN 0 O0 -109,00 9 O0 -100,00 100 O0 200 O0 300 O0 400 O0 500 O0 600 O0 7 O0 oo 0 0 N 0 o E 0 ! N 3 47 W 0 6 S 83 54 W 0 7 N 29 28 W 0 ~4 N~3 26 W 0 13 N 83 51 W 0 9 N 0 ~ W 0 20 M 42 49. W 0 , N 10 3 E 0 13 Il 3 9 Z i O0 O0 O0 O0 O0 O0 O0 O0 900 O0 O0 iO00 O0 100 O0 2O0 O0 1300 gg 1400 1500 gg 170o o0 1800 0 i6 S 24 59 W O0 2 59 S 36 30 W O0 5 S5 S 47 23 W O0 9 22 8 52 37 W O0 -133) 8 5556 W O0 17 3:. 8 54 38 W O0 2 6 $ 60 17 W O0 ~9 S 16 W O0 33 21 S 58 26 W 0i i009 O0 34 1409 ~9 1~09 ~4 ~609 04 1709 54 1809 081 1909 0,00 Oo 9 0o~4 0 41 0 0 $2 o ~ o~ 71 65 106 54 149 42 200 86 262 06 0,00 8 0,20 0 t 35 358 _ 0 O0 N 0 N 0 $~ 0 ~SN 0 O0 E 0 O0 W 0 .36 W O53W 067W 04W · W I 67W 150W 109,00 FT 93 N 03 IS 2 92 S 8 0 O0 N 00 E ~ ~ N w 69 S 54 I W 55 S SS !t 43 '509 O0 2400 O0 44 54 25 ~ 7;~ 4 l~ 366 :'1' ~ i i" 'i' ! 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KUPARUK NORTH SLOPE,ALASKA COMPUTATIDN DATE= 24-JUb-85 PAGE 6 DATE OF SURVEY1 9 JUb 85 KEbb¥ BUSHING 109.00 FT ENGINEERI NURTbAND INTERPObAT£D VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA CDUPSE MEASURED VER?ICAb V£RTZCAb DEVIATION DEPTH DEPTH DEPTH DEG'M~N COORDINAT£& HORZZ. DE 'ARTURE AZ I~UTH 4q17 22 4009 O0 3900 O0 46 32 06 410 O0 O0 3 42099 O0 40 45 1 5 581,~ 595 6103 6248 O0 O0 4309 91 4409 54 4509 74 4609 84 4709 81 4809 63 4909 O0 4100 O0 46 38 O0 420O 49 44 oo 0 4400 O0 4 20 000 4500 O0 4 27 4600 O0 47 2 O0 4700 O0 46 31 O0 4800 O0 46 9 639i,64 5009 O0 4900 O0 45 2' 6532.44 5109 O0 5000 O0 44 33. O0 5100 O0 46 4? 6673 97 5209 6824 05 5309 6979 47 5409 7119 16 ~509 7263 51 5609 7405 94 5709 7546 25 5809 7686 38 5909 O0 5200 O0 5300 O0 54 oo O0 5600 O0 5700 O0 5800 O0 48 5 O0 47 8 O0 46 tO O0 45 51 O0 44 5~ O0 44 O0 45 24 7832 26 6009,00 5900 O0 44 7982 7 6109, O0 6100 O0 50 9 8~93.19 6309,00 6~00 O0 50 9 ]o ;oo VERTZCAb DOGb£G RrCTANGUbAR AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST D£G ~IN FEET DEG/IO0 FEET FEET FEET DE $ 54 22 W 2334.72 0.62 1304 79 $ 19~6 11 W 2334.74 S 56 517 W W $ 54 38 W 2438 08 0 64 1364 78 $ 2020. 3~ W 2438.09 & 5~ S 55 I w 2538 78 5 32 1423 01' S 2102.49 W 2538,?$~ ~i 54 S 55 46 W 2654 54 0 5t 1488 52 S 2i97 94 W 2654,55 5 S 55 24 W 2771 55 0 3t 1554 97 S 2294 52 W 2771,55 52 s ,5 3, w 2,8, 52 o 41 i6,9 15 s 2388 4, w 2885.52 S 55 25 W ~996 24 0 59 i681 80S 2499 71 W 2996.24 ~ 55 ~ w 3!o4 13 0 41 1743 2? $ 2568 39 w 3104,13 50 ~ 54 55 w 3210 44 0 ~I i804 24 $ 2655 49 w 32!0,44 o S 54 I W 3516 48 ~ 54 21W 3616 56 0 934 4 ~ 61 2039 86 8 ~986 40 W 3616,59 39 2103 48 S 30Ts 47 W 3726'46 S 55 2? W 3728 46 $ 54 46 ~ 38~8 12 0 8 2166 25 $ 3168 39 ~ !ii 38 S 53 48 W 4049 47 2289 34 $ 3340 28 W 4049.5, $ 55 8 53 29 W 4!50 S4 2349 25 8 3421 97 W 4150.60 S 52 43 W 4;49 13 2408 46 $ 3500 73 "4249.2! 445~.37 8 54 43 tV 481 6 OO 0,00 ARCO AbASKA, INC. 2~'14 KUPARUK NORTH SLDPg,ALASKA HARKER TOP UPPER 5AND BASE UPPER SAND TOP bOWER SAND BASE bOWER SAND P~?D TD COMPUTATION DATEI 24-JU6-65 DAT£ OF SURVEY1 9 JUL 85 KEbbY BUSHING Eb£VATION! I0~,00 FT ENG[NEERI HUR?bAND [NTERPObATED VALUE5 FOR CHOSEN HORX[ONS MEASURED DEPTH BELOW KB SURFACE: bOCATZON ORIGIN= 1184' FSb~ 291' ~'Eb. SEC t. TtlN. ROE TVD RECTANGUbAR COORDZNATES FROM KB SUB-,SEA NORTH/SOUTH ZAST/~EST 7619.00 7730.00 7907,00 8 .00 8305.00 586! 24 5939 39 6059 O2 6t90 36 6 57 COMPUTATION' DATE~ 24-JU5-85 ARCO ALASKA, ~NC. 2Z-t4 KUPARUK NORTH SLOPE,ALASKA DATE OF 8URVE¥t 9 JUL 85 KELLY BUSHTNG ELEVAT!ONI ENGTNEERI MURTLAND i09,00 rT MARKER MEASURED DEPTH BELOW KB SURFACE bOCATZON · " ret. SEC N R9E I TvDORZGIN= t184 FSb, 27~ECTANGULAR~ ~RDI~A{ES ' TOP UPPER SAND BASE tIPPER SAND TOP LOWER SAND BASE LOWER SAND PBTD TD 7619,00 ?730,00 .00 8196,00 8305,00 5861,24 5752,24 2438 5939.39 ~B30.39 6059.02 5950.02 )~8S6t 6t90,36 6081,36 ~ ~46.73 6~37.73 ~ 50 89 16.57 6207.5? 2 38 FINAt, WELL LOCATZON AT MEASURED VERTICAL VERTICAL. DEPTH DEPTH DEPTH HORIZONTAL DEPARTURE DISTANCE FEET DEG B305,00 6316,57 6207,57 4812,36 S 55 19 W SCHLUMBERGER O I RECT I ONAL SURVEY COMPANY ARCO ALASKA INC WELL 2Z- 14 FIELD KUPARUK COUNTRY USA RUN ONE DATE LOOOEO 9 JUL 8S REFERENCE 00007066S WELL NAMg.: -2Z-14 SURFACE LO:.~-~.ON: 1184' FSL, 271' FEL, Sll, iN, R9E, UM VERTICAL PROJECTION -~000 - ! 000 ' 0 0 ! 000 ~000 3000 ~000 ~000 ........ : : ! , : : : : : : ; : : : ; : i ~ ; : ; - -4 ~:; : ,~-~ '~CF~ : i-i?'%~i::: '"j':t:~::h~-hf-h'-'tm~ %bt% ~-t:%~'tfi~' '-?'~-'t":-?'t-'t-" ::t-'fi't-'t-: i%f"ff- '~'"fTt::;' ??%: -i i ~ ~ '~% i % Ft'TT-%F~'~-~ i i i i i i i iT~"T : : : "%' TI i ~ i ~%'"? %-'~%'''I- '-I-?'?'~- "i ~ i i I ~ ~ i ~ ~-~:~' ~'-?'~Y't-i i i ~ ~ ~ i l C~ ~fft'~]~/"Fff ~-'t"t-t-~"t~'~'"f'' "'f'-T'T-t--t 't~'"~ .... :'"?'r"t ,~~,~L~'~~~.Et'':rT'=-~]~~ C ~ ~ ~:~:~Z.~~j~]E 1171" '77 :;~T~i:T:FF x;;~~::: ::r::rzr:::~z.. ~ ! ~% ::;~:EJ~:z:~:::;: mxxx: ::x;:r;::x ::::::::::::::::::::::::::::::~ :~:::~...~...;..~ ...;...T .;...;... ~ ***~. * ~ * !-~c.~4..4-~..-.4 ¢* * * ~: ,~. !?-*< ' ~L' '~-4-4...;---~4...&-;~;...;4 ..... ;.4...L.; ...... ~4..;4-.4.4-.;..~.-...;-;..*..4... ~~+.~.~-~4-4..4--~-.~.-,-~.-.;--..;..~.-~-~- ~ ;~ i ii~ ,.~.k~4-4-.kk. 4444 ~.~-.;.. ,,.~...~,..;..,;.-j,,.~..-~,..~,..~.,.,-.~-~,..~.-.~...j.,,~...~...~.,.+.., ~H~+-.--~-~..~4--~.-~-~%~-.~-~-~--+~+H++-f+--.~f-H t.+.r-g-f---.~.-.f-.-~.--~--t.--~-.-~-.-,...~.--.-..~---~-..~--.~.-.,..-t...~ ........... .-~.~-~..~. -.~-~z..4-.~.~-~-~. - ~. z _~ 4 , ~- ~:-~ -~...~- ~ l ~ ~-4~-- ...~...4...~...z...~._:..; ....... ~.-4 -4 _~..-~..$ .~.. $ .&...$...,...~ .j.; ..~...~...~ ...... ~.. $...$...~...j...~... ~...~...4. ~;4 '~'~.-.~.~...~-4..-~..~..¢;,-~-.--;...~-.-~..-; k.&'~4-...4.~ ~-~-I. ~-k.~-....-~.~.--;---; i-.-~...;...~--;--....-;...;...;...4 .J---~...;-..;...;...:-..;.--;...~ ' ~.--~...~-..;--~ ..-;...;.,.~-.~..~-.;...; _ ~ ~ : . : : : : : ] ~: . : ~ · ; : . , ~~ ? ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ -T'%~'T-?~-T-T-~ ~~~-'~'~'T-FT-~T'T'T'IT-"T'T'IT'~TT"T-T-~ ...... 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LL.L.L.L.L..L1...i ...... L.L.L.~_L.k~. !!!! !!!! !! ~_L.M...L.L._..L.L.--'._L.L.LL.L.L.:_L.i...L.L.L.L.L.L.i ..... L.LL.L.k.L.L.L.1 i i i i i i i -i-.i-..:-.i...--~-Hb---b--4.:-.-b-.~-4-.-i----.".---H~,-H:---H::--i---b--~-i-} i -.~i i il i [ i i i .:'4-.+-+-+-H+.-+--H--i-f-f"-..'.--.+--'f-'? ....... f'+'+"H-'i"+'+"~ ..... ?..'"'?."-';"'i'"+'+"i'"~ .... --.H---!--H--H-+-i ....... H---H-'+-H-+-?-I---t'--H--i-t-+-H-t'----½-+-+-t--+-H--+---H--t--H-+-H--'~ ...... i---:i'--t-t--!"-!--f"?-i ....... 5.f...-..'.--t..T-+..?.'+ ...... i"'.-'"".i"'!Tf'!'"?"'~ .... -- .-H+-4.--F-i.---b-4- .-b-4 ...... -.-'---H-H.-F--H-~-H-?'---H.yH--b--F--~---½----~---H-k--f- -+-..P--?'-.-~-.r-F--H-5.-.H-. ---?'--F--?---.? -½..-H-t-.-.-,.---F... ---~...-?---.m.r-..t-...,.--?.--,...? ........... *-.-',..-?.-.'t...-,...? ....... ? ..... ?...?-..-,...?-...t .................. ..?-t...?".i..[-.k1-t?..~-~..?.-:~..?..~-1-~.l~i.+.t..?...:..-~-.i-lt-~;.-t.-...~..?~-~..~-~.?-..?..f+..?.l:".[l..t-t...?....f.ll-t~.t...t".~'l'? ........... : ....~..1,~...,~ ....... I....,..., -4000 -3000 -2000 -1000 0 I000 2000 3000 E~ST Suggested form to be inserted in each "Active" Well folder to check for timely compliance with our regulations. OPERATOR, W~LL~[~M]~ 'AND- NU~ER Reports and Materials to be received by: - Dffte ,, Required Date Received Remarks , Completion Report Core Chips Core Description , ~egistered Survey Plat Inclination Survey .. , Drill Stem Test Reports ,, ~ , Production Test Reports Log Run _ ~ , . , STATE OF ALASKA ~ ALASKA C _ AND GAS CONSERVATION CO, .¢IlSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well [] X Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-107 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21361 4. Location of Well atsurface 1184' FSL, 271' FEL, Sec.ll, .T11N, RgE, UM 5. Elevation in feet (indicate KB, DF, etc.) 109' RKB 6. Lease Designation and Serial No. ADL 25653 ALK 2579 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 2Z-14 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of. June , 19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 1330 hfs, 06/21/85. Drld 12-1/4" hole to 3905'. Ran, cmtd & tstd csg. Drld 8-1/2" hole to 8305'TD (6/28/85). Ran logs. Ran, cmtd, & tstd 7" csg. = 8196'. Arctic packed. Secured well & RR ~ 1500 hfs, 6/29/85. 9-5/8" PBTD 13. Casing or liner rgn and quantities of cement, results of pressure tests 16" 62 5#/ft, H-40, weld conductor set ~ 100' Cmtd w/255 sx P~ "C" 9-5/8", 36.0#/ft, J-55, BTC csg w/shoe ~ 3877'. Cmtd w/1050 sx CS Ill & 450 sx CS 7" 26 O#/ft, J-55, BTC csg w/shoe @ 8278' Cmtd w/300 sx Class G & 250 sx CS I II. 14. Coring resume and brief description NONE 15. Logs run and depth where run DIL/SFL/SP/GR/Cal/FDC/CNL f/WL TD 8293' - 3876'. 6. DST data, perforating data, shows of H2S, miscellaneous data NONE 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--ReportCon this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10~404 TEMP/MR69 R.hmit in dunlie~t~ STATE OF ALASKA Or~ 'Corn.. ALASKA Oil, & GAS CONSERVATION COMMISS ON B.O,P.E, Inspection Report Location'. Drillln~ 'dell Locat iot'~ Generel.. ....... Re~rve Trip Tank Pit Gauge ............ Fl~w Monitor ~ De~ec~or~ ....... Pree~ur~[A{tet Cloeure P,t8 Pump incr. clo,. pre~. Full Char'ge Pressure At~ [ned:~~_mtn~_~ec. Blind Ct,ok~ Line Valve~.,~~-- ~, c,' ~, ~_.~. ,:-.-./:: ...... Kill :~'alve~ Check ~lve_ Repair or Replacement Com~fseion office not' Remark~ ~ ~~ Inside ~OP '' ~~ .... ~ Adjustable Cl~oke~O ~f failed equipment to be made wlthi~ e ~' ~.~r~ ' .~q.~ ~a..~ ...................... aye and Inspector/ Distribution cc - Op~ratoi' cc - Sup~rvi~;,,'. - ', May 24, 1985 ~. J. B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Kuparuk River Unit 2Z-14 ARCO Alaska, Inc. Permit No. 85-107 Sur. Loc. l184'FSL, 271'FEL, Sec. 11, TllN, R9E, b~. Btmhole Loc. !493'FNL, 1065'FWL, Sec. !4, TllN, RgE, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a brief description of each core and a one cubic inch size chip from each foot of recovered core is required. Samples of drill cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their, drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. Mr. Jeffrey B. Kewin Kuparuk River Unit 2Z-14 -2- May 24, 1985 To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly ~s, C. V. ChattertOn Chairman o f Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION be Enclosure CC' Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowe~y ARCO Alaska, Inc. Post Office Bo~..00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 17, 1985 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2Z-14 Dear Mr. Chatterton: Enclosed are: o An application for Permit to Drill Kuparuk 2Z-14, along with a $100 application fee ° Diagrams showing the proposed horizontal and vertical projections of the wellbore o A proximity plat o A diagram and description of the surface hole diverter system o A diagram and description of the BOP equipment We estimate spudding this well on June 13, 1985. If you have any questions, please call me at 263-4970. Sincerely, /~rea Drilling Engineer JBK/LST/tw PD/L92 Enclosures RECEIVED Alaska ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany STATE OF ALASKA "-' ALASKA OiL AND GAS CONSERVATION CO~,,~vllSSlON PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DR ILL 13(IX REDRILL [] DEEPEN [] lb. Type of well EXPLORATORY [] DEVELOPMENT OIL I~[X DEVELOPMENT GAS [] SERVICE [] ST~ATIGRAPHIC I_~ SINGLE ZONE ~D( MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Irc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 1184' FSL, 271' FEL, Sec;11, T11N, RgE, UM At top of proposed producing interval 1235' FNL, 1445' FWL, Sec.14, TllN, R9E, UM At total depth 1493' FNL, 1065' FWL, Sec.14, TllN, RgE, UM 5. Elevation in feet (indicate KB, DF etc.) RKB 109', PAD 72' 6. Lease designation and serial no. ADL 25653 ALK 2579 Kuparuk River Unit 10. Well number 2Z-14 11. Field and pool Kuparuk River Field Kuparuk River Oil 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 1065 feet 2Z-15weII 60' ~ surface feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 8264' MD, 6291' TVD feet 2560 06/13/85 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures 2759 psig@ 80°F Surface KICKOFF POINT 1000 feet. MAXIMUM HOLEANGLE 47 oI (see 20 AAC 25.035 (c) (2) :3168 psig@ 6154 ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SIZE Hole 24" 2-1/4" i8-1/2" Casing Weight 16" 62.5# 9-5/8" 36.0# 7" 26. O# 22. Describe proposed program: CASING AND LINER Grade Coupling H-40 Weld J-55 BTC HF-ERW J-55 BTC HF-ERW Length SETTING DEPTH MD TOP TVD 80' 36' I 36' I 3865' 36' 36' I I 35' I 35' 8229' MD BOTTOM TVD 1161 116' 39011 3309' 82644 6291' QUANTITY OF CEMENT (include stage data) + 200 cf 1050 sx Cold Set III & 450 sx Cold Set II 300 sx Class G blend ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 8264' MD (6291' 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 (.~0~OOpsi for annular). Expected maximum surface pressure is 2759 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 3000 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 2Z-14 will be 60' away from 2Z-15 at surface. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any interruptions in the disposal process~The well will be completed (see attached sheet) ,, ,~,.. 23. I hereby certi~Lv~that the foregoing ~s true and correct to the best ~no~¢~ tl¢~ O~ ~1~¢~ I ~ ~RN¢~v~ ~~ SIGNED / /~~b r/~~~ T'ITLE Area Drill in En ineer DATE ~~~ CONDITIONS OF APPROVAL Samples required []YES ~ Permit number APPROVED BY f Form 10401 (LST) PD/PD92 Dh., Mud log required []YES Approval date Directional Survey required I APl number .~V-ES :NO [ 50- o'~-,~-13 SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE May 24, 198.5 by order of the Commission Submit in triplicate PERMIT TO DRILL 2Z-14 by the workover rig using 3-1/2", 9.2#/ft, J-55, 8rd tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. R£CE! , n v £U MA Ye 0 ]9~5 Alaska Oil & Gas Cons, Commission Anchorage 4000 DEI~d4459 SOUTH VEST i :3~80~ ~ ii;l.i .[, .: ! I (TO!T AR 320',--. $. RECEIVED Anchorags 7 6 I. 18' - 2000 PSI T/ll~ ~'I'AR'I'II~ I, EAD ACO,,M.L~TOR CAPACITY TI~S'r I. CLEO( /~D FZLL ACCLM. LATO~ RE~IE TO ~ LEVEL WITH ~IC FLUID, 2. ~ THAT ACClJ&LATCR PRESSU~ IS 30(X) P~I W3TH 1500 PSI DON~TEF, A~ CF THE REGIJ. ATCI~. 3. ~BSF. EV~ TII~., TkEN ~ ALL UNITS SZMJLT/U~EOLISLY AN)-RE:~ 'rl-E TIkE ~ ~ R~'M~INI~ AFTER ALL LIMITS AI~ ~ R3TH 04AR~II~ ~ CFF. 4. i~CCI~ ON ~ R~PCI~To TI4~ ACCEPT~ L.C~R LIMIT IS 45 -~=*C(34~ CLOSINS TIbE At~ 1200 PSI ~kl~INING , -I:.'.'~/~* BOP ~TACK TEST I. FILL BCP_~ ~ O0(E lV~EFCI. D W'ITH ARCTIC DIESEL. 2. O-ECK THAT ALL LOCX: ~ ~ IN V~:I.L~ ARE FLLLY ;~--I'RACTED. SEAT TEST PLUG IN W~TH ;~..NYlI~G JT ~ RLId IN L~ L:/I~E: V/~L. VES ADJ~ TO ~ STAQC ALL 4. I:~ESSI.RE UP TO 250 PSI ~ ~ FD~ I0 MI:N. IN- CREASE I=RE~ TO 3(X/3 PSI ~ 143.D ~ I0 r, ~:'r~_ ~ TO 0 1:=3I. LIllE: V/~.VES. 0.0~ TCP PIPE P. AM~ ~ HCR VALVES ~ Kill ~ C3-1CKE L]:I~E:~. 6, TEST -TO 250 PSI AI~D 5(3:X) PSI AS IN STEP 4. ?. 03~IIq. E ~II~J3 ALL W~J. VE~ LII~.S. ~ WI:TH A ~50 PS! LOW AJ~D ~ 1='3I HIGH. TEST AS IN ~ 4. ~ ~ I:~F~J~' TF'~"T ~ ~ TI-I~T ]'~ ~ A FULL O..OSII~3 POSITIVE S~:AL O.ICI<~. CI~LY 8. 0:3EN TO~ PIPE ~ ~ CLOSE BOT"rCM PIPE TEST BOTTCM PIPE RAk6 TO 250 PSI ~ 34:XX3 PSI. . ARCO Alaska, In(. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 1, 1985 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Conductor As-Built Location Plat - 2Z Pad Wells 9-16 Dear Elaine- Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU6/L75 Enclosure If " 'ECEIVED ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany II 12 LOCATED IN PROTRACTED Sec. 11 ~ 12, T tl N, RgE, U.M. COORDINATES A.S.R, ZONE4. SECTION LINE DISTANCES ARE TRUE. NOTE: BASIS OF POSITION AND ELEVATION IS - MONUMENTATION 2Z SOUTH,2Z MIDDLE 8 2Z I~C~'H PER LHD 8~ ASSOC. O.G. ELEVATIONS ~[NTERPOLATED FROM S/R DRWG. CED-BZO0-$OOI /-IX .~- SURVEY , WE LL 9 WELL 1 0 WELL I 1 WELL t2 WELL 13 WELL 14 WELL 15 WELL 16 Y: 5,966,216.984 X: 529,701.611 0.$. Elev. 66.0' 1,458' FSL Y = 5,966, 163.969 X= 529,729.559 O.G. Elev. 66.1' 1 t 404~FSL Y = 5,966,11t.065 X= 529,757.539 O.G. Elev. 66.t' 1,:551' FSL Y =5,966,057.960 X= 529,785.556 O.G Elev. 66.~' 1 , 298' F S L Y = 5, 965,889.662 x = 529, 467. 207 O.G. Elev. 66.9' 1,1:51' FSL Y: 5,965,942.773 ~).~. 529, 459.,85 Elev. 67.0' 1 t184' FSL Y =5,965,995.892 X= 529,4t1.136 O.G. E lev. 67.0' 1,237' FS L Y= 5,966,048.87B X = 529,383.~t2 O.G. Elev. 67.5' I 1,291 FSL Int. 70°49'07.5806'' Long. 149°45' 33.228'' Pad Elev. 71.9' 8'FEL Sec. 11 Lat. 70° 19'07.058i" Lon~ 149° 45'$2.419'' Pact Elev. 7~.8' 20' FWL Sec. 12 Lot. 70° 19'06.5366" Long. 149o45' $t. 609" Pod Elev. 71.9' 48' FWL Sec. 12 70° 19'06.0131" Long. 149° 45' 30.797" I~ad Elev. 7~.5' 75' FWL Sec.1 2 Lot 70° ~9' 04.~702" Long. t49O45'40.106" Pad Elev. 7t.9' 244' FEL Sec. 11 Lot. 70° 19' 04.89:56" Long. ~49°45' 40.9~8" Pod Elev. 7~.8' 2:71' F EL Secl~ Lot 70° ~9'C5.4~7t" Long. 149°45' 41.730" Pod Elev. 72.~' ?_99' FEL Sec. 11 Lat. 70°'19' 05.9595" Long.~49°45' 42542" Pnd Ele v. 72.~ :527' FEL Sec.11 I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED & LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA & THAT THIS PLAT REPRESENTS A SURVEY MADE UNDER MY DIRECT SUPERVISION & THAT ALL DETALS ARE CORRECT AS OF FEB. 17,1985 FOR: WELLS 9-16 ~,~L~W~~.,~' ARCO Alaska, Inc. Kuporuk Project DRILL CONDUCTOR LOCAT Date: FEB. 23, 1985 Drown By: D-J.W. North Slope Drilling SITE 2Z AS- BUILT ONS Scale: N.T.S. Dwg. no.: NSK 9.05.226<i3 CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE YES NO REMARKS · e 3. 4. 5. 6. 7. · (8) ~ / (3) Admin ~ A'-~'~ ~'~ 9. (~ thru 12) 10. (~l~0~and 12. thru ~21Y (s) (22 thru/ 2~) (6) Add: /f// ~-/~//$3'~' , ~ / 13. 14. 15. 16. 17. 18. 19. 20. 21. 22¸. 23. 24. 25. 26. 27. Is the permit fee attached ,.~~ · eeeeeeee·eeee eeeeeeeeeeeeeee·~eeeee~®e . Is well to be located ~n a defined pool ...................... ts well located proper distance from property line ...... .. ' ~ '~ " Is well located proper distance from other wells ...... ...'..'1. · Is sufficient undedicated acreage available in this P°°i!iii ii i' Is well to be deviated and is iwellbore plat included .. Is operator the only affected party ..... '..' .......... Can permit be approved before ten-day wait ............ ' ] Does operator have a bond in force .................................. ~- Is a conservation order needed-. .................. . ................... Is administrative approval needed ................................... · Is the lease number appropriate ..................................... Is conductor string provided .................. , ......... ~ ...... Is enough cement used to circulate'on conductor and surface~ii ii.i Will cement tie in surface and intermediate or production s n . 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 wellbore separation proposed · ......................... Is a diverter system required . ......... ' . . .. Are necessary diagrams of diverter ~nd ~'e~i;~;~t~h~ii~. i!' ~ Does BOPE have sufficient pressure rating - Test to ~D-Z~Z) ' ~2F~ Does the choke manifold comply w/API RP-53 (Feb.78)..~.."'~...".' ~ Is the presence of H2S gas probable ....... ~ .............. _.. ......... __ .. Additional requirements ............................................. Additional Remar s: .g)~/~2. ~,~.-1~ //3ll.~,, ~ g~ ./:RD/v] ~-~ -/,Y FF~M Geo logy: En gi3~er in~: k WVA ' MTM ',~"' HJH?z2-~ ~__~JAL ~.. rev: 03/13/85 6.011 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE I Il Well Histo.ry 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 APPENDIXl .. No special'effort has been made to chronologically ' .. organize this category of information. L ,T S T ~ ~ ;~ FP ~1~.H02 V~RI~.,=iCA'TiJN LZSTING ?Aide i · INFJRMATIJN RE.CSRDS ~-'~'~ N,-M N : AR N : ZZ N : KU ANG: ,ECT: ,DUN.' .T~Y: US ~N~M PA~UK SL3P; ~ S ~ .~ CO~T:NTS ~R=S: ~. :~r. C]MVtENTS ~::=r- UNZT JNiT TYP[ 000 OOO 000 000 TYP~ C~TE 000 OOO GOO OOO O3O OOO 000 CATE S Z ,Z E Ol 5 OO5 OOT O ~ 7. 0 J 3. 002 007 006 0O3 SiZE 0~ 5 O65 A S I N G YPE FL.U,i D t:E N S Z 'T ¥ 'ISCgSZT¥ 'H :LUlD LOSS 67O 62.0 DF 62.0 JF .141. DF IATRZX SANDS'TON5 .VP ~iO.HOZ VERiFICAT,ZJN LJS'T~NG ,P.AjE 3 SC~tL~JMiSERGt!R LOGS INCLUD!hL[~ WITH THIS M~,GNE'TIC TAPE: ATbM SPrZCIFiCATZGN 5LOC'KS NEM SER'ViZE SERVICE UNIT APl L ~ S: L ~ H N M 00 L M 3 ,I b 3 H ~ M 00 R 0 .i L G A P .i ~ 0 'R FON ~APi ~ 0 ALi FDN .ZN O0 H 3 B F D N ~ /C 3 00 RH~ F~N G/C3 O0 RAT FON 30 NRA FDN O0 PHI ,:~N ~ 2U OC CNL FDN CPS O0 S I S PL REPR PROCESS CJOf (OCTAL) 53 O0000OO0000OO3 :~8 O00OOOOOO00OO0 58,00000000000000 · 68 OgOO,OOOOOOOgOg 58 OOO000000OO000 ,58 O00OO0000000OO 58 OOO00OO000000O 58 OOO00OO000000O 58 O0~OOOOOO000OO 6~ O000000OODO000 ~,8 O0000000O$OOO$ 5B O000000000000O 68 0~000000000000 68 O0000000OOOgOO ~8 O0000OO0000OO0 DATA ,P ,H 3 B 833~. OOOO SFLU -5~.0000 -ZT55.OO00 DRHG 35.56'39 NCNL 8300.0000 SFLU -41.Z500 Z.48,53 DRHO 36.66'99 NCNL 8200.0000 SFCU -37.7,5 O0 5R ,~.~160 ORHO ~3. ? 500 NC NL 8!ors. 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