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Home My WebLink About198-117CAUTION: 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: CPAI 2N-331 (PTD 198-117) Completion of IAxOA monitor period. Date:Monday, April 22, 2024 3:13:57 PM Attachments:image001.png AnnComm Surveillance TIO for 2N-331.pdf From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Monday, April 22, 2024 10:53 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; Well Integrity Specialist CPF2 <n2549@conocophillips.com> Subject: CPAI 2N-331 (PTD 198-117) Completion of IAxOA monitor period. Chris- Tarn WAG injector 2N-331 (PTD #198-117) has completed the additional 30 day monitor period for a suspected pressure dependent IAxOA leak. During the 30 day monitor period the IA and OA showed no indications of pressure convergence with the reduced pressure differential. CPAI intends to return the well to normal injection status. If the well experiences any further suspect communication, the well will be reported as required. Attached is a current 90 day TIO plot and well bore schematic. Please let me know if you have any questions or disagree with the plan. Dusty Freeborn Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Wednesday, March 13, 2024 11:00 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; Well Integrity Specialist CPF2 <n2549@conocophillips.com> Subject: RE: CPAI 2N-331 (PTD 198-117) Report of IAxOA convergence. Chris- Tarn WAG injector 2N-331 (PTD #198-117) has completed the 30 day monitor period for a suspected pressure dependent IAxOA leak. During the initial diagnostics the inner casing pack off failed the testing and was suspected to be the cause of the IAxOA communication. The lock down pins were torqued and the inner casing pack offs have now proven integrity. The IA and OA have maintained a substantial differential pressure during the initial 30 day monitor period. However, CPAI intends to extends the monitor period an additional 30 days to investigate the continued presence of a pressure dependent leak. CPAI will reduce the IAxOA differential pressure and resume the monitor period. Depending on the results of the additional monitor period, the proper notifications for continued injection or repair will be submitted as required. Attached is a current 90 day TIO plot and well bore schematic. Please let me know if you have any questions or disagree with the plan. Dusty Freeborn Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Monday, February 5, 2024 3:04 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>; Well Integrity Specialist CPF2 <n2549@conocophillips.com> Subject: CPAI 2N-331 (PTD 198-117) Report of IAxOA convergence. Chris- Tarn WAG injector 2N-331 (PTD #198-117) has once again shown indications of IAxOA pressure convergence. CPAI completed an AOGCC approved 30 day monitor period last month in which no IAxOA communication was observed. After the 30 day monitor period was completed the IA pressure was relieved to re-establish a 500 psi differential pressure between the tubing and IA which reduced the IA and OA pressure differential. Shortly after the reduced IAxOA differential pressure was established, the slow IAxOA convergence appears to have resumed. It is suspected that the IAxOA pressure convergence maybe a pressure sensitive leak through the IC PO since the initial diagnostics suggested that the upper seal of the pack off has become compromised. CPAI intends to investigate the suspected IAxOA communication as a pressure sensitive leak and will re-establish a substantial IAxOA differential pressure, verify the IC pack off integrity and monitor the well for 30 days. Depending on the results of the monitor period, the proper notifications for continued injection or repair will be submitted as required. Attached is a current 90 day TIO plot and well bore schematic. Please let me know if you have any questions or disagree with the plan. Dusty Freeborn Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Thursday, December 14, 2023 2:51 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>; Well Integrity Specialist CPF2 <n2549@conocophillips.com> Subject: RE: CPAI 2N-331 (PTD 198-117) completion of 30 day monitor period. Chris- Tarn WAG injector 2N-331 (PTD #198-117) has completed the 30 day AOGCC approved monitor period for suspected IAxOA pressure convergence. DHD conducted the initial set of diagnostics which passed an MIT-IA, tubing pack off tests and the inner casing positive pressure pack off test. The negative inner casing pack off test failed but suggested that only the upper seal has lost integrity. During the 30 day monitor the IA and OA did not show pressure convergence and maintained a pressure differential suggesting there is no communication between the IA and OA. CPAI intends to return the well to normal injection status and will report any additional suspect pressure anomalies as required. Please let me know if you have any questions or disagree with the plan. Attached is a current 90 day TIO plot and well bore schematic. Dusty Freeborn Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 From: Well Integrity Specialist CPF2 Sent: Wednesday, November 8, 2023 11:15 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>; Well Integrity Specialist CPF2 <n2549@conocophillips.com> Subject: CPAI 2N-331 (PTD 198-117) report of suspect IA & OA pressure convergence. Chris, Tarn WAG injector 2N-331 (PTD 198-117) is experiencing a suspect IA and OA pressure convergence. CPAI intends to conduct a series of initial diagnostic testing and depending on the results, establish an IA and OA pressure differential for a 30 day monitor period. At the completion of the 30 day monitor period the proper notifications for repair or continued injection will be submitted as required. Please let me know if you have any questions or disagree with the plan. Attached is the well bore schematic and a current 90 day TIO plot. Dusty Freeborn Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.062 Top (ftKB) 28.9 Set Depth (ftKB) 108.0 Set Depth (TVD) … 108.0 Wt/Len (l… 62.58 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 7 5/8 ID (in) 6.875 Top (ftKB) 28.9 Set Depth (ftKB) 3,841.4 Set Depth (TVD) … 2,305.7 Wt/Len (l… 29.70 Grade L-80 Top Thread BTC-MOD Casing Description PRODUCTION 5.5"x3.5" @ 10384" OD (in) 5 1/2 ID (in) 4.950 Top (ftKB) 26.0 Set Depth (ftKB) 11,215.9 Set Depth (TVD) … 5,247.0 Wt/Len (l… 15.50 Grade L-80 Top Thread LTC MOD Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.992 Top (ftKB) 23.9 Set Depth (ft… 10,379.4 Set Depth (TVD) (… 4,778.6 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 23.9 23.9 0.08 HANGER FMC GEN V 5M TUBING HANGER 3.500 494.0 493.4 7.08 NIPPLE CAMCO DS NIPPLE 2.875 10,251.8 4,712.9 61.20 SLEEVE-C BAKER CMU SLIDING SLEEVE - CLOSED 11/30/98 2.813 10,354.2 4,765.2 58.48 NIPPLE CAMCO D NIPPLE 2.750 10,361.3 4,768.9 58.20 LOCATOR BAKER LOCATOR 2.985 10,362.8 4,769.7 58.14 SEAL ASSY BAKER 80-40 CASING SEAL ASSEMBLY 3.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Zone Date Shot Dens (shots/f t)Type Com 10,715.0 10,752.0 4,968.7 4,989.3 S-8, 2N-331 11/30/1998 6.0 IPERF 2.5" HC/DP, 60 Deg Ph 10,762.0 10,782.0 4,994.9 5,006.0 S-7, 2N-331 11/29/1998 6.0 IPERF 2.5" HC/DP, 60 Deg Ph 10,792.0 10,812.0 5,011.6 5,022.7 S-5, 2N-331 11/29/1998 6.0 IPERF 2.5" HC/DP, 60 Deg Ph 10,870.0 10,880.0 5,055.1 5,060.7 S-3, 2N-331 11/29/1998 6.0 IPERF 2.5" HC/DP, 60 Deg Ph 10,888.0 10,897.0 5,065.2 5,070.3 S-3, 2N-331 11/29/1998 6.0 IPERF 2.5" HC/DP, 60 Deg Ph 10,908.0 10,916.0 5,076.5 5,081.0 S-3, 2N-331 11/28/1998 6.0 IPERF 2.5" HC/DP, 60 Deg Ph 10,922.0 10,937.0 5,084.4 5,092.9 S-3, T-2, 2N- 331 11/26/1998 6.0 IPERF 2.5" HC/DP, 60 Deg Ph 10,991.0 11,004.0 5,123.2 5,130.5 K-3, 2N-331 11/26/1998 6.0 IPERF 2.5" HC/DP, 60 Deg Ph 11,010.0 11,029.0 5,133.9 5,144.6 K-3, 2N-331 11/28/1998 6.0 IPERF 2.5" HC/DP, 60 Deg Ph Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB)Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi)Run Date Com 1 10,301.9 4,738.0 CAMCO KBG29 1 GAS LIFT DMY INT 0.000 0.0 9/11/1998 Notes: General & Safety End Date Annotation 6/3/2009 NOTE: ZONES NOT LOADED TO WELLVIEW YET 11/23/2010 NOTE: View Schematic w/ Alaska Schematic9.0 Comment SSSV: NIPPLE2N-331, 10/21/2014 10:17:27 AM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 10384"; 26.0-11,215.9 IPERF; 11,010.0-11,029.0 IPERF; 10,991.0-11,004.0 IPERF; 10,922.0-10,937.0 IPERF; 10,908.0-10,916.0 IPERF; 10,888.0-10,897.0 IPERF; 10,870.0-10,880.0 IPERF; 10,792.0-10,812.0 IPERF; 10,762.0-10,782.0 IPERF; 10,715.0-10,752.0 SEAL ASSY; 10,362.8 LOCATOR; 10,361.3 NIPPLE; 10,354.2 GAS LIFT; 10,301.9 SLEEVE-C; 10,251.8 SURFACE; 28.9-3,841.4 NIPPLE; 494.0 CONDUCTOR; 28.9-108.0 HANGER; 23.9 Annotation Last Tag: SLM Depth (ftKB) 10,999.0 End Date 10/17/2014 Annotation Rev Reason: TAG Last Mod By hipshkf End Date 10/21/2014 KUP INJ KB-Grd (ft) 34.99 Rig Release Date 9/11/1998 Annotation Last WO: End Date 2N-331 H2S (ppm) Date ... TD Act Btm (ftKB) 11,225.0 Well Attributes Wellbore API/UWI 501032026500 Field Name TARN PARTICIPATING AREA Wellbore Status INJ Max Angle & MD Incl (°) 71.41 MD (ftKB) 8,800.00 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: CPAI 2N-331 (PTD 198-117) Report of IAxOA convergence. Date:Wednesday, March 13, 2024 11:23:14 AM Attachments:image001.png AnnComm Surveillance TIO for 2N-331.pdf From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Wednesday, March 13, 2024 11:00 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com>; Well Integrity Specialist CPF2 <n2549@conocophillips.com> Subject: RE: CPAI 2N-331 (PTD 198-117) Report of IAxOA convergence. Chris- Tarn WAG injector 2N-331 (PTD #198-117) has completed the 30 day monitor period for a suspected pressure dependent IAxOA leak. During the initial diagnostics the inner casing pack off failed the testing and was suspected to be the cause of the IAxOA communication. The lock down pins were torqued and the inner casing pack offs have now proven integrity. The IA and OA have maintained a substantial differential pressure during the initial 30 day monitor period. However, CPAI intends to extends the monitor period an additional 30 days to investigate the continued presence of a pressure dependent leak. CPAI will reduce the IAxOA differential pressure and resume the monitor period. Depending on the results of the additional monitor period, the proper notifications for continued injection or repair will be submitted as required. Attached is a current 90 day TIO plot and well bore schematic. Please let me know if you have any questions or disagree with the plan. Dusty Freeborn Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Monday, February 5, 2024 3:04 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>; Well Integrity Specialist CPF2 <n2549@conocophillips.com> Subject: CPAI 2N-331 (PTD 198-117) Report of IAxOA convergence. Chris- Tarn WAG injector 2N-331 (PTD #198-117) has once again shown indications of IAxOA pressure convergence. CPAI completed an AOGCC approved 30 day monitor period last month in which no IAxOA communication was observed. After the 30 day monitor period was completed the IA pressure was relieved to re-establish a 500 psi differential pressure between the tubing and IA which reduced the IA and OA pressure differential. Shortly after the reduced IAxOA differential pressure was established, the slow IAxOA convergence appears to have resumed. It is suspected that the IAxOA pressure convergence maybe a pressure sensitive leak through the IC PO since the initial diagnostics suggested that the upper seal of the pack off has become compromised. CPAI intends to investigate the suspected IAxOA communication as a pressure sensitive leak and will re-establish a substantial IAxOA differential pressure, verify the IC pack off integrity and monitor the well for 30 days. Depending on the results of the monitor period, the proper notifications for continued injection or repair will be submitted as required. Attached is a current 90 day TIO plot and well bore schematic. Please let me know if you have any questions or disagree with the plan. Dusty Freeborn Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Thursday, December 14, 2023 2:51 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>; Well Integrity Specialist CPF2 <n2549@conocophillips.com> Subject: RE: CPAI 2N-331 (PTD 198-117) completion of 30 day monitor period. Chris- Tarn WAG injector 2N-331 (PTD #198-117) has completed the 30 day AOGCC approved monitor period for suspected IAxOA pressure convergence. DHD conducted the initial set of diagnostics which passed an MIT-IA, tubing pack off tests and the inner casing positive pressure pack off test. The negative inner casing pack off test failed but suggested that only the upper seal has lost integrity. During the 30 day monitor the IA and OA did not show pressure convergence and maintained a pressure differential suggesting there is no communication between the IA and OA. CPAI intends to return the well to normal injection status and will report any additional suspect pressure anomalies as required. Please let me know if you have any questions or disagree with the plan. Attached is a current 90 day TIO plot and well bore schematic. Dusty Freeborn Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 From: Well Integrity Specialist CPF2 Sent: Wednesday, November 8, 2023 11:15 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>; Well Integrity Specialist CPF2 <n2549@conocophillips.com> Subject: CPAI 2N-331 (PTD 198-117) report of suspect IA & OA pressure convergence. Chris, Tarn WAG injector 2N-331 (PTD 198-117) is experiencing a suspect IA and OA pressure convergence. CPAI intends to conduct a series of initial diagnostic testing and depending on the results, establish an IA and OA pressure differential for a 30 day monitor period. At the completion of the 30 day monitor period the proper notifications for repair or continued injection will be submitted as required. Please let me know if you have any questions or disagree with the plan. Attached is the well bore schematic and a current 90 day TIO plot. Dusty Freeborn Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.062 Top (ftKB) 28.9 Set Depth (ftKB) 108.0 Set Depth (TVD) … 108.0 Wt/Len (l… 62.58 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 7 5/8 ID (in) 6.875 Top (ftKB) 28.9 Set Depth (ftKB) 3,841.4 Set Depth (TVD) … 2,305.7 Wt/Len (l… 29.70 Grade L-80 Top Thread BTC-MOD Casing Description PRODUCTION 5.5"x3.5" @ 10384" OD (in) 5 1/2 ID (in) 4.950 Top (ftKB) 26.0 Set Depth (ftKB) 11,215.9 Set Depth (TVD) … 5,247.0 Wt/Len (l… 15.50 Grade L-80 Top Thread LTC MOD Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.992 Top (ftKB) 23.9 Set Depth (ft… 10,379.4 Set Depth (TVD) (… 4,778.6 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 23.9 23.9 0.08 HANGER FMC GEN V 5M TUBING HANGER 3.500 494.0 493.4 7.08 NIPPLE CAMCO DS NIPPLE 2.875 10,251.8 4,712.9 61.20 SLEEVE-C BAKER CMU SLIDING SLEEVE - CLOSED 11/30/98 2.813 10,354.2 4,765.2 58.48 NIPPLE CAMCO D NIPPLE 2.750 10,361.3 4,768.9 58.20 LOCATOR BAKER LOCATOR 2.985 10,362.8 4,769.7 58.14 SEAL ASSY BAKER 80-40 CASING SEAL ASSEMBLY 3.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Zone Date Shot Dens (shots/f t)Type Com 10,715.0 10,752.0 4,968.7 4,989.3 S-8, 2N-331 11/30/1998 6.0 IPERF 2.5" HC/DP, 60 Deg Ph 10,762.0 10,782.0 4,994.9 5,006.0 S-7, 2N-331 11/29/1998 6.0 IPERF 2.5" HC/DP, 60 Deg Ph 10,792.0 10,812.0 5,011.6 5,022.7 S-5, 2N-331 11/29/1998 6.0 IPERF 2.5" HC/DP, 60 Deg Ph 10,870.0 10,880.0 5,055.1 5,060.7 S-3, 2N-331 11/29/1998 6.0 IPERF 2.5" HC/DP, 60 Deg Ph 10,888.0 10,897.0 5,065.2 5,070.3 S-3, 2N-331 11/29/1998 6.0 IPERF 2.5" HC/DP, 60 Deg Ph 10,908.0 10,916.0 5,076.5 5,081.0 S-3, 2N-331 11/28/1998 6.0 IPERF 2.5" HC/DP, 60 Deg Ph 10,922.0 10,937.0 5,084.4 5,092.9 S-3, T-2, 2N- 331 11/26/1998 6.0 IPERF 2.5" HC/DP, 60 Deg Ph 10,991.0 11,004.0 5,123.2 5,130.5 K-3, 2N-331 11/26/1998 6.0 IPERF 2.5" HC/DP, 60 Deg Ph 11,010.0 11,029.0 5,133.9 5,144.6 K-3, 2N-331 11/28/1998 6.0 IPERF 2.5" HC/DP, 60 Deg Ph Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB)Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi)Run Date Com 1 10,301.9 4,738.0 CAMCO KBG29 1 GAS LIFT DMY INT 0.000 0.0 9/11/1998 Notes: General & Safety End Date Annotation 6/3/2009 NOTE: ZONES NOT LOADED TO WELLVIEW YET 11/23/2010 NOTE: View Schematic w/ Alaska Schematic9.0 Comment SSSV: NIPPLE2N-331, 10/21/2014 10:17:27 AM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 10384"; 26.0-11,215.9 IPERF; 11,010.0-11,029.0 IPERF; 10,991.0-11,004.0 IPERF; 10,922.0-10,937.0 IPERF; 10,908.0-10,916.0 IPERF; 10,888.0-10,897.0 IPERF; 10,870.0-10,880.0 IPERF; 10,792.0-10,812.0 IPERF; 10,762.0-10,782.0 IPERF; 10,715.0-10,752.0 SEAL ASSY; 10,362.8 LOCATOR; 10,361.3 NIPPLE; 10,354.2 GAS LIFT; 10,301.9 SLEEVE-C; 10,251.8 SURFACE; 28.9-3,841.4 NIPPLE; 494.0 CONDUCTOR; 28.9-108.0 HANGER; 23.9 Annotation Last Tag: SLM Depth (ftKB) 10,999.0 End Date 10/17/2014 Annotation Rev Reason: TAG Last Mod By hipshkf End Date 10/21/2014 KUP INJ KB-Grd (ft) 34.99 Rig Release Date 9/11/1998 Annotation Last WO: End Date 2N-331 H2S (ppm) Date ... TD Act Btm (ftKB) 11,225.0 Well Attributes Wellbore API/UWI 501032026500 Field Name TARN PARTICIPATING AREA Wellbore Status INJ Max Angle & MD Incl (°) 71.41 MD (ftKB) 8,800.00 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: CPAI 2N-331 (PTD 198-117) Report of IAxOA convergence. Date:Monday, February 5, 2024 3:53:51 PM Attachments:image001.png AnnComm Surveillance TIO for 2N-331.pdf Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Monday, February 5, 2024 3:04 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>; Well Integrity Specialist CPF2 <n2549@conocophillips.com> Subject: CPAI 2N-331 (PTD 198-117) Report of IAxOA convergence. Chris- Tarn WAG injector 2N-331 (PTD #198-117) has once again shown indications of IAxOA pressure convergence. CPAI completed an AOGCC approved 30 day monitor period last month in which no IAxOA communication was observed. After the 30 day monitor period was completed the IA pressure was relieved to re-establish a 500 psi differential pressure between the tubing and IA which reduced the IA and OA pressure differential. Shortly after the reduced IAxOA differential pressure was established, the slow IAxOA convergence appears to have resumed. It is suspected that the IAxOA pressure convergence maybe a pressure sensitive leak through the IC PO since the initial diagnostics suggested that the upper seal of the pack off has become compromised. CPAI intends to investigate the suspected IAxOA communication as a pressure sensitive leak and will re-establish a substantial IAxOA differential pressure, verify the IC pack off integrity and monitor the well for 30 days. Depending on the results of the monitor period, the proper notifications for continued injection or repair will be submitted as required. Attached is a current 90 day TIO plot and well bore schematic. Please let me know if you have any questions or disagree with the plan. Dusty Freeborn Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Thursday, December 14, 2023 2:51 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>; Well Integrity Specialist CPF2 <n2549@conocophillips.com> Subject: RE: CPAI 2N-331 (PTD 198-117) completion of 30 day monitor period. Chris- Tarn WAG injector 2N-331 (PTD #198-117) has completed the 30 day AOGCC approved monitor period for suspected IAxOA pressure convergence. DHD conducted the initial set of diagnostics which passed an MIT-IA, tubing pack off tests and the inner casing positive pressure pack off test. The negative inner casing pack off test failed but suggested that only the upper seal has lost integrity. During the 30 day monitor the IA and OA did not show pressure convergence and maintained a pressure differential suggesting there is no communication between the IA and OA. CPAI intends to return the well to normal injection status and will report any additional suspect pressure anomalies as required. Please let me know if you have any questions or disagree with the plan. Attached is a current 90 day TIO plot and well bore schematic. Dusty Freeborn Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 From: Well Integrity Specialist CPF2 Sent: Wednesday, November 8, 2023 11:15 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>; Well Integrity Specialist CPF2 <n2549@conocophillips.com> Subject: CPAI 2N-331 (PTD 198-117) report of suspect IA & OA pressure convergence. Chris, Tarn WAG injector 2N-331 (PTD 198-117) is experiencing a suspect IA and OA pressure convergence. CPAI intends to conduct a series of initial diagnostic testing and depending on the results, establish an IA and OA pressure differential for a 30 day monitor period. At the completion of the 30 day monitor period the proper notifications for repair or continued injection will be submitted as required. Please let me know if you have any questions or disagree with the plan. Attached is the well bore schematic and a current 90 day TIO plot. Dusty Freeborn Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.062 Top (ftKB) 28.9 Set Depth (ftKB) 108.0 Set Depth (TVD) … 108.0 Wt/Len (l… 62.58 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 7 5/8 ID (in) 6.875 Top (ftKB) 28.9 Set Depth (ftKB) 3,841.4 Set Depth (TVD) … 2,305.7 Wt/Len (l… 29.70 Grade L-80 Top Thread BTC-MOD Casing Description PRODUCTION 5.5"x3.5" @ 10384" OD (in) 5 1/2 ID (in) 4.950 Top (ftKB) 26.0 Set Depth (ftKB) 11,215.9 Set Depth (TVD) … 5,247.0 Wt/Len (l… 15.50 Grade L-80 Top Thread LTC MOD Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.992 Top (ftKB) 23.9 Set Depth (ft… 10,379.4 Set Depth (TVD) (… 4,778.6 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 23.9 23.9 0.08 HANGER FMC GEN V 5M TUBING HANGER 3.500 494.0 493.4 7.08 NIPPLE CAMCO DS NIPPLE 2.875 10,251.8 4,712.9 61.20 SLEEVE-C BAKER CMU SLIDING SLEEVE - CLOSED 11/30/98 2.813 10,354.2 4,765.2 58.48 NIPPLE CAMCO D NIPPLE 2.750 10,361.3 4,768.9 58.20 LOCATOR BAKER LOCATOR 2.985 10,362.8 4,769.7 58.14 SEAL ASSY BAKER 80-40 CASING SEAL ASSEMBLY 3.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Zone Date Shot Dens (shots/f t)Type Com 10,715.0 10,752.0 4,968.7 4,989.3 S-8, 2N-331 11/30/1998 6.0 IPERF 2.5" HC/DP, 60 Deg Ph 10,762.0 10,782.0 4,994.9 5,006.0 S-7, 2N-331 11/29/1998 6.0 IPERF 2.5" HC/DP, 60 Deg Ph 10,792.0 10,812.0 5,011.6 5,022.7 S-5, 2N-331 11/29/1998 6.0 IPERF 2.5" HC/DP, 60 Deg Ph 10,870.0 10,880.0 5,055.1 5,060.7 S-3, 2N-331 11/29/1998 6.0 IPERF 2.5" HC/DP, 60 Deg Ph 10,888.0 10,897.0 5,065.2 5,070.3 S-3, 2N-331 11/29/1998 6.0 IPERF 2.5" HC/DP, 60 Deg Ph 10,908.0 10,916.0 5,076.5 5,081.0 S-3, 2N-331 11/28/1998 6.0 IPERF 2.5" HC/DP, 60 Deg Ph 10,922.0 10,937.0 5,084.4 5,092.9 S-3, T-2, 2N- 331 11/26/1998 6.0 IPERF 2.5" HC/DP, 60 Deg Ph 10,991.0 11,004.0 5,123.2 5,130.5 K-3, 2N-331 11/26/1998 6.0 IPERF 2.5" HC/DP, 60 Deg Ph 11,010.0 11,029.0 5,133.9 5,144.6 K-3, 2N-331 11/28/1998 6.0 IPERF 2.5" HC/DP, 60 Deg Ph Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB)Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi)Run Date Com 1 10,301.9 4,738.0 CAMCO KBG29 1 GAS LIFT DMY INT 0.000 0.0 9/11/1998 Notes: General & Safety End Date Annotation 6/3/2009 NOTE: ZONES NOT LOADED TO WELLVIEW YET 11/23/2010 NOTE: View Schematic w/ Alaska Schematic9.0 Comment SSSV: NIPPLE2N-331, 10/21/2014 10:17:27 AM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 10384"; 26.0-11,215.9 IPERF; 11,010.0-11,029.0 IPERF; 10,991.0-11,004.0 IPERF; 10,922.0-10,937.0 IPERF; 10,908.0-10,916.0 IPERF; 10,888.0-10,897.0 IPERF; 10,870.0-10,880.0 IPERF; 10,792.0-10,812.0 IPERF; 10,762.0-10,782.0 IPERF; 10,715.0-10,752.0 SEAL ASSY; 10,362.8 LOCATOR; 10,361.3 NIPPLE; 10,354.2 GAS LIFT; 10,301.9 SLEEVE-C; 10,251.8 SURFACE; 28.9-3,841.4 NIPPLE; 494.0 CONDUCTOR; 28.9-108.0 HANGER; 23.9 Annotation Last Tag: SLM Depth (ftKB) 10,999.0 End Date 10/17/2014 Annotation Rev Reason: TAG Last Mod By hipshkf End Date 10/21/2014 KUP INJ KB-Grd (ft) 34.99 Rig Release Date 9/11/1998 Annotation Last WO: End Date 2N-331 H2S (ppm) Date ... TD Act Btm (ftKB) 11,225.0 Well Attributes Wellbore API/UWI 501032026500 Field Name TARN PARTICIPATING AREA Wellbore Status INJ Max Angle & MD Incl (°) 71.41 MD (ftKB) 8,800.00 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: CPAI 2N-331 (PTD 198-117) completion of 30 day monitor period. Date:Thursday, December 14, 2023 3:36:42 PM Attachments:image001.png AnnComm Surveillance TIO for 2N-331.pdf From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Thursday, December 14, 2023 2:51 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>; Well Integrity Specialist CPF2 <n2549@conocophillips.com> Subject: RE: CPAI 2N-331 (PTD 198-117) completion of 30 day monitor period. Chris- Tarn WAG injector 2N-331 (PTD #198-117) has completed the 30 day AOGCC approved monitor period for suspected IAxOA pressure convergence. DHD conducted the initial set of diagnostics which passed an MIT-IA, tubing pack off tests and the inner casing positive pressure pack off test. The negative inner casing pack off test failed but suggested that only the upper seal has lost integrity. During the 30 day monitor the IA and OA did not show pressure convergence and maintained a pressure differential suggesting there is no communication between the IA and OA. CPAI intends to return the well to normal injection status and will report any additional suspect pressure anomalies as required. Please let me know if you have any questions or disagree with the plan. Attached is a current 90 day TIO plot and well bore schematic. Dusty Freeborn Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 From: Well Integrity Specialist CPF2 Sent: Wednesday, November 8, 2023 11:15 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>; Well Integrity Specialist CPF2 <n2549@conocophillips.com> Subject: CPAI 2N-331 (PTD 198-117) report of suspect IA & OA pressure convergence. Chris, Tarn WAG injector 2N-331 (PTD 198-117) is experiencing a suspect IA and OA pressure convergence. CPAI intends to conduct a series of initial diagnostic testing and depending on the results, establish an IA and OA pressure differential for a 30 day monitor period. At the completion of the 30 day monitor period the proper notifications for repair or continued injection will be submitted as required. Please let me know if you have any questions or disagree with the plan. Attached is the well bore schematic and a current 90 day TIO plot. Dusty Freeborn Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.062 Top (ftKB) 28.9 Set Depth (ftKB) 108.0 Set Depth (TVD) … 108.0 Wt/Len (l… 62.58 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 7 5/8 ID (in) 6.875 Top (ftKB) 28.9 Set Depth (ftKB) 3,841.4 Set Depth (TVD) … 2,305.7 Wt/Len (l… 29.70 Grade L-80 Top Thread BTC-MOD Casing Description PRODUCTION 5.5"x3.5" @ 10384" OD (in) 5 1/2 ID (in) 4.950 Top (ftKB) 26.0 Set Depth (ftKB) 11,215.9 Set Depth (TVD) … 5,247.0 Wt/Len (l… 15.50 Grade L-80 Top Thread LTC MOD Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.992 Top (ftKB) 23.9 Set Depth (ft… 10,379.4 Set Depth (TVD) (… 4,778.6 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 23.9 23.9 0.08 HANGER FMC GEN V 5M TUBING HANGER 3.500 494.0 493.4 7.08 NIPPLE CAMCO DS NIPPLE 2.875 10,251.8 4,712.9 61.20 SLEEVE-C BAKER CMU SLIDING SLEEVE - CLOSED 11/30/98 2.813 10,354.2 4,765.2 58.48 NIPPLE CAMCO D NIPPLE 2.750 10,361.3 4,768.9 58.20 LOCATOR BAKER LOCATOR 2.985 10,362.8 4,769.7 58.14 SEAL ASSY BAKER 80-40 CASING SEAL ASSEMBLY 3.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Zone Date Shot Dens (shots/f t)Type Com 10,715.0 10,752.0 4,968.7 4,989.3 S-8, 2N-331 11/30/1998 6.0 IPERF 2.5" HC/DP, 60 Deg Ph 10,762.0 10,782.0 4,994.9 5,006.0 S-7, 2N-331 11/29/1998 6.0 IPERF 2.5" HC/DP, 60 Deg Ph 10,792.0 10,812.0 5,011.6 5,022.7 S-5, 2N-331 11/29/1998 6.0 IPERF 2.5" HC/DP, 60 Deg Ph 10,870.0 10,880.0 5,055.1 5,060.7 S-3, 2N-331 11/29/1998 6.0 IPERF 2.5" HC/DP, 60 Deg Ph 10,888.0 10,897.0 5,065.2 5,070.3 S-3, 2N-331 11/29/1998 6.0 IPERF 2.5" HC/DP, 60 Deg Ph 10,908.0 10,916.0 5,076.5 5,081.0 S-3, 2N-331 11/28/1998 6.0 IPERF 2.5" HC/DP, 60 Deg Ph 10,922.0 10,937.0 5,084.4 5,092.9 S-3, T-2, 2N- 331 11/26/1998 6.0 IPERF 2.5" HC/DP, 60 Deg Ph 10,991.0 11,004.0 5,123.2 5,130.5 K-3, 2N-331 11/26/1998 6.0 IPERF 2.5" HC/DP, 60 Deg Ph 11,010.0 11,029.0 5,133.9 5,144.6 K-3, 2N-331 11/28/1998 6.0 IPERF 2.5" HC/DP, 60 Deg Ph Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB)Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi)Run Date Com 1 10,301.9 4,738.0 CAMCO KBG29 1 GAS LIFT DMY INT 0.000 0.0 9/11/1998 Notes: General & Safety End Date Annotation 6/3/2009 NOTE: ZONES NOT LOADED TO WELLVIEW YET 11/23/2010 NOTE: View Schematic w/ Alaska Schematic9.0 Comment SSSV: NIPPLE2N-331, 10/21/2014 10:17:27 AM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 10384"; 26.0-11,215.9 IPERF; 11,010.0-11,029.0 IPERF; 10,991.0-11,004.0 IPERF; 10,922.0-10,937.0 IPERF; 10,908.0-10,916.0 IPERF; 10,888.0-10,897.0 IPERF; 10,870.0-10,880.0 IPERF; 10,792.0-10,812.0 IPERF; 10,762.0-10,782.0 IPERF; 10,715.0-10,752.0 SEAL ASSY; 10,362.8 LOCATOR; 10,361.3 NIPPLE; 10,354.2 GAS LIFT; 10,301.9 SLEEVE-C; 10,251.8 SURFACE; 28.9-3,841.4 NIPPLE; 494.0 CONDUCTOR; 28.9-108.0 HANGER; 23.9 Annotation Last Tag: SLM Depth (ftKB) 10,999.0 End Date 10/17/2014 Annotation Rev Reason: TAG Last Mod By hipshkf End Date 10/21/2014 KUP INJ KB-Grd (ft) 34.99 Rig Release Date 9/11/1998 Annotation Last WO: End Date 2N-331 H2S (ppm) Date ... TD Act Btm (ftKB) 11,225.0 Well Attributes Wellbore API/UWI 501032026500 Field Name TARN PARTICIPATING AREA Wellbore Status INJ Max Angle & MD Incl (°) 71.41 MD (ftKB) 8,800.00 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: CPAI 2N-331 (PTD 198-117) report of suspect IA & OA pressure convergence. Date:Tuesday, November 28, 2023 2:04:48 PM Attachments:image001.png AnnComm Surveillance TIO for 2N-331.pdf From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Wednesday, November 8, 2023 11:15 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com>; Well Integrity Specialist CPF2 <n2549@conocophillips.com> Subject: CPAI 2N-331 (PTD 198-117) report of suspect IA & OA pressure convergence. Chris, Tarn WAG injector 2N-331 (PTD 198-117) is experiencing a suspect IA and OA pressure convergence. CPAI intends to conduct a series of initial diagnostic testing and depending on the results, establish an IA and OA pressure differential for a 30 day monitor period. At the completion of the 30 day monitor period the proper notifications for repair or continued injection will be submitted as required. Please let me know if you have any questions or disagree with the plan. Attached is the well bore schematic and a current 90 day TIO plot. Dusty Freeborn Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.062 Top (ftKB) 28.9 Set Depth (ftKB) 108.0 Set Depth (TVD) … 108.0 Wt/Len (l… 62.58 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 7 5/8 ID (in) 6.875 Top (ftKB) 28.9 Set Depth (ftKB) 3,841.4 Set Depth (TVD) … 2,305.7 Wt/Len (l… 29.70 Grade L-80 Top Thread BTC-MOD Casing Description PRODUCTION 5.5"x3.5" @ 10384" OD (in) 5 1/2 ID (in) 4.950 Top (ftKB) 26.0 Set Depth (ftKB) 11,215.9 Set Depth (TVD) … 5,247.0 Wt/Len (l… 15.50 Grade L-80 Top Thread LTC MOD Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.992 Top (ftKB) 23.9 Set Depth (ft… 10,379.4 Set Depth (TVD) (… 4,778.6 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 23.9 23.9 0.08 HANGER FMC GEN V 5M TUBING HANGER 3.500 494.0 493.4 7.08 NIPPLE CAMCO DS NIPPLE 2.875 10,251.8 4,712.9 61.20 SLEEVE-C BAKER CMU SLIDING SLEEVE - CLOSED 11/30/98 2.813 10,354.2 4,765.2 58.48 NIPPLE CAMCO D NIPPLE 2.750 10,361.3 4,768.9 58.20 LOCATOR BAKER LOCATOR 2.985 10,362.8 4,769.7 58.14 SEAL ASSY BAKER 80-40 CASING SEAL ASSEMBLY 3.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Zone Date Shot Dens (shots/f t)Type Com 10,715.0 10,752.0 4,968.7 4,989.3 S-8, 2N-331 11/30/1998 6.0 IPERF 2.5" HC/DP, 60 Deg Ph 10,762.0 10,782.0 4,994.9 5,006.0 S-7, 2N-331 11/29/1998 6.0 IPERF 2.5" HC/DP, 60 Deg Ph 10,792.0 10,812.0 5,011.6 5,022.7 S-5, 2N-331 11/29/1998 6.0 IPERF 2.5" HC/DP, 60 Deg Ph 10,870.0 10,880.0 5,055.1 5,060.7 S-3, 2N-331 11/29/1998 6.0 IPERF 2.5" HC/DP, 60 Deg Ph 10,888.0 10,897.0 5,065.2 5,070.3 S-3, 2N-331 11/29/1998 6.0 IPERF 2.5" HC/DP, 60 Deg Ph 10,908.0 10,916.0 5,076.5 5,081.0 S-3, 2N-331 11/28/1998 6.0 IPERF 2.5" HC/DP, 60 Deg Ph 10,922.0 10,937.0 5,084.4 5,092.9 S-3, T-2, 2N- 331 11/26/1998 6.0 IPERF 2.5" HC/DP, 60 Deg Ph 10,991.0 11,004.0 5,123.2 5,130.5 K-3, 2N-331 11/26/1998 6.0 IPERF 2.5" HC/DP, 60 Deg Ph 11,010.0 11,029.0 5,133.9 5,144.6 K-3, 2N-331 11/28/1998 6.0 IPERF 2.5" HC/DP, 60 Deg Ph Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB)Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi)Run Date Com 1 10,301.9 4,738.0 CAMCO KBG29 1 GAS LIFT DMY INT 0.000 0.0 9/11/1998 Notes: General & Safety End Date Annotation 6/3/2009 NOTE: ZONES NOT LOADED TO WELLVIEW YET 11/23/2010 NOTE: View Schematic w/ Alaska Schematic9.0 Comment SSSV: NIPPLE2N-331, 10/21/2014 10:17:27 AM Vertical schematic (actual) PRODUCTION 5.5"x3.5" @ 10384"; 26.0-11,215.9 IPERF; 11,010.0-11,029.0 IPERF; 10,991.0-11,004.0 IPERF; 10,922.0-10,937.0 IPERF; 10,908.0-10,916.0 IPERF; 10,888.0-10,897.0 IPERF; 10,870.0-10,880.0 IPERF; 10,792.0-10,812.0 IPERF; 10,762.0-10,782.0 IPERF; 10,715.0-10,752.0 SEAL ASSY; 10,362.8 LOCATOR; 10,361.3 NIPPLE; 10,354.2 GAS LIFT; 10,301.9 SLEEVE-C; 10,251.8 SURFACE; 28.9-3,841.4 NIPPLE; 494.0 CONDUCTOR; 28.9-108.0 HANGER; 23.9 Annotation Last Tag: SLM Depth (ftKB) 10,999.0 End Date 10/17/2014 Annotation Rev Reason: TAG Last Mod By hipshkf End Date 10/21/2014 KUP INJ KB-Grd (ft) 34.99 Rig Release Date 9/11/1998 Annotation Last WO: End Date 2N-331 H2S (ppm) Date ... TD Act Btm (ftKB) 11,225.0 Well Attributes Wellbore API/UWI 501032026500 Field Name TARN PARTICIPATING AREA Wellbore Status INJ Max Angle & MD Incl (°) 71.41 MD (ftKB) 8,800.00 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, April 5, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2N-331 KUPARUK RIV U TARN 2N-331 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/05/2023 2N-331 50-103-20265-00-00 198-117-0 W SPT 4770 1981170 1500 1200 1200 1200 1200 350 500 500 500 4YRTST P Austin McLeod 3/1/2023 MITIA 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 U TARN 2N-331 Inspection Date: Tubing OA Packer Depth 540 1920 1870 1870IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM230302112032 BBL Pumped:1.2 BBL Returned:1.2 Wednesday, April 5, 2023 Page 1 of 1          5HJJ-DPHV%2*& )URP:HOO,QWHJULW\6SHFLDOLVW&3)Q#FRQRFRSKLOOLSVFRP! 6HQW:HGQHVGD\$XJXVW30 7R5HJJ-DPHV%2*&:DOODFH&KULV'2*&%URRNV3KRHEH/2*&'2$$2*&&3UXGKRH%D\ 6XEMHFW&3$,IRUPVIRU6,LQMHFWRUVRQ$XJ $WWDFKPHQWV0,7.5813$'6,7(676[OV[0,7.58/$6,7(67[OV[0,7.588 6,7(67[OV[ ůůͲWůĞĂƐĞƐĞĞƚŚĞϭϬͲϰϮϲĨŽƌŵƐĨŽƌƚŚĞƐŚƵƚŝŶ͕ŶŽŶͲǁŝƚŶĞƐƐĞĚD/dͲ/ƐƉĞƌĨŽƌŵĞĚŽŶϮƵŐϮϬϮϮ͘WůĞĂƐĞůĞƚŵĞŬŶŽǁŝĨ ǇŽƵŚĂǀĞĂŶǇƋƵĞƐƚŝŽŶƐŽƌĐŽŶĐĞƌŶƐ͘ 'XVW\)UHHERUQ :HOO,QWHJULW\6SHFLDOLVW &RQRFR3KLOOLSV$ODVND,QF 2IILFHSKRQH &HOOSKRQH &$87,217KLVHPDLORULJLQDWHGIURPRXWVLGHWKH6WDWHRI$ODVNDPDLOV\VWHP'RQRWFOLFNOLQNVRURSHQ DWWDFKPHQWVXQOHVV\RXUHFRJQL]HWKHVHQGHUDQGNQRZWKHFRQWHQWLVVDIH .581 37' Submit to: OOPERATOR: FIEL DD // UNITT // PAD: DATE: OPERATORR REP: AOGCCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2070900 Type Inj N Tubing 10 140 140 140 Type Test P Packer TVD 5004 BBL Pump 1.9 IA 85 1800 1750 1750 Interval 4 Test psi 1500 BBL Return 1.9 OA 0 0 0 0 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1981730 Type Inj N Tubing 1645 1650 1645 1645 Type Test P Packer TVD 4903 BBL Pump 2.4 IA 225 2510 2460 2440 Interval 4 Test psi 1500 BBL Return 1.7 OA 140 150 150 150 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1981170 Type Inj N Tubing 1460 1450 1450 1430 Type Test P Packer TVD 4770 BBL Pump 1.4 IA 360 2200 2140 2130 Interval 4 Test psi 1500 BBL Return 1.4 OA 240 430 430 430 Result P Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2011420 Type Inj N Tubing 650 650 650 650 Type Test P Packer TVD 4375 BBL Pump 2.1 IA 410 1800 1750 1740 Interval 4 Test psi 1500 BBL Return 2.1 OA 230 360 350 350 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMec h an i c all In t eg r ityy Tes t jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: Notes: 2N-310 2N-321A 2N-348 Notes: 2N-331 Notes: ConocoPhillips Alaska Inc, Kuparuk / KRU / 2N Pad N/A Hembree / Hills 08/02/22 Form 10-426 (Revised 01/2017)2022-0802_MIT_KRU_2N-pad_4wells 9 9 9 9 9 9 9 - 5HJJ 2N-331 Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Tuesday, January 29, 2019 12:27 PM To: Wallace, Chris D (DOA) Cc: CPA Wells Supt Subject: RE: Report of unexplained IA anomaly 2N-331 (PTD 198-117) update 1-29-19 Attachments: 2N-331 90 day TIO 1-29-19.PNG Chris, 2N-331 is nearing the end of its 30 -day monitor period and the previously -observed, questionable IA behavior is no longer in evidence. No external leak was identified when the IA was pressured up with N2 on January 2, 2019 and the annulus has maintained pressure during the monitor, amidst minor thermal fluctuations. It appears that the IA phenomenon of a slow pressure fall off was strictly due to a thermal response. The well will now be returned to 'normal' WAG injection status, to be governed under Tarn's AIO. Please let us know if you disagree with the path forward. Attached is an updated 90 day TIO plot. Kelly Lyons/ Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 From: NSK Well Integrity Supv CPF1 and 2 Sent: Monday, December 31, 2018 9:53 AM To: Wallace, Chris D (DOA) <chris.wallace@alaska.gov> Cc: Senden, R. Tyler <R.Tyler.Senden@conocophillips.com> Subject: Report of unexplained IA anomaly 2N-331 (PTD 198-117) Chris, Tarn WAG injector 2N-331 (PTD 198-117) is experiencing an unexplained very slow IA pressure decline (-130 psi per month). Our plans are initially to pressure up the IA using N2 and look for either a surface or packoff gas leak and repair if possible. If neither of those appear to be the culprit, we will put the well on a 30 day monitor. If the pressure continues to act suspiciously, we will then roll into an MITIA using diesel. An update will be provided at the conclusion of the monitor/diagnostics. Please let us know if you disagree with the path forward. Attached are the schematic and 90 day TIO plot. Kelly Lyons/ Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 • aN 331 Iv' RECEIVED ConocoPhillips APR 0 6 2016 Alaska P.O. BOX 100360 AOGGC ANCHORAGE,ALASKA 99510-0360 April 4, 2016 Commissioner Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 SCAM, APR 0 8 2016 Commissioner Cathy Foerster: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement 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. No cement was pumped. The corrosion inhibitor/sealant was pumped March 25, 2016 &March 28, 2016. The attached spread sheet presents the well name, top of cement depth prior to filling and volumes used on each conductor. Please call MJ Loveland at 907-659-7043, if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor 0 • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10-404) Kuparuk Field Date 4/4/2016 10-10,2N-302,2N-331, 2N-335,2N-243&2X-1 Corrosion Initial top of Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal 1D-10 50029228700000 1980490 11" NA 11" NA 4.00 3/25/2016 2N-302 50103203800000 2011150 10" NA 10" NA 5.90 3/25/2016 2N-331 50103202650000 1981170 20" NA 20" NA 10.00 3/28/2016 2N-335 50103202740000 1982040 23" NA 23" NA 15.50 3/28/2016 2N-343 50103202600000 1980920 26" NA 26" NA 15.50 3/25/2016 2X-01 50029209630000 1830840 25" NA 25" NA 9.00 3/25/2016 . • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Performed: Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other: Conductor Extend Fl 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 198-117 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service 50-103-20265-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0380054 KRU Tarn 2N-331 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): Kuparuk River Field/Tarn Oil Pool 11.Present Well Condition Summary: Total Depth measured 11225 feet Plugs(measured) None true vertical 5252 feet Junk(measured) None Effective Depth measured 11118 feet Packer(measured) 10363 true vertical 5206 feet (true vertical) 4770 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 108 108' SURFACE 3813 12 3841 2305' PRODUCTION 11190 10 11216 4779' PROD Liner 832 3.5 11216 5247' RECEIVED Perforation depth: Measured depth: 10715-11029 p� �y APR MAR 2 9 2016 True Vertical Depth: 4981-5157 SCANNED A R 2 i. Lot (�(� AOGCC Tubing(size,grade,MD,and TVD) 3.5, L-80, 10361 MD,4769 TVD Packers&SSSV(type,MD,and TVD) NIPPLE-CAMCO DS NIPPLE @ 494 MD and 493 TVD SEAL ASSY-BAKER 80-40 CASING SEAL ASSEMBLY @ 10363 MD and 4770 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): NA Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 14.Attachments(required per 20 AAC 25.070,25.071,&25.213) 15.Well Class after work: Daily Report of Well Operations p Exploratory r Development r Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r— Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG P GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-101 Contact MJ Loveland Email: n1878( conocophillips.com Printed Name MJ Loveland Title: NSK Well Integrity Project Supervisor Signature Phone:659-7043 Date ,2 c�_� 5704/2/(., VTI- 4j/iilk 2"'/4 Form Form 10-404 Revised 5/2015 �` RBDMS 1.V MAR 31 2016 Submit Original Only • • `r' . . RECEIVED ConocoPhilhps MAR 2 9 2016 Alaska P.O. BOX 100360 /OG(�(� ANCHORAGE,ALASKA 99510-0360 vv Vv March 25, 2016 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Foerster: Enclosed please find the 10-404 Sundry for ConocoPhillips Alaska, Inc. well 2N-331, PTD 198-117, Sundry#316-101 conductor extension. Please contact me at 659-7043 if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • S 2N-331 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 03/15/16 Prep and weld 20" long extension on conductor made with 16" .375 wall pipe. • z e kN i i \ 14. �,^ 9 wr' x ei ti t ' sr a 140 j�A a A'y kt,..' ' ,o, . � s * 2N-331 PTD 198-117 "Copyright 2016 All rights res - ed . This � photograph is� provided to the AOGCC with permission to copy for its own use. Copying for any other. purpose or by any other pa is prohibited wthout the express consent of s • r 8 a s s *3k �Ek!,,�,R.." , l� `t `: S f 44, ; R. S ,x ' /''� r :// ,f ''''''': ' ,.. :/::': ' d ID • 02)4r- "1 OF Flit gwQ\�� ii , 4), THE STATE Alaska Oil and Gas ti ,; OfALASKA Conservation Commission fife: i, 333 West Seventh Avenue O ' 7' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 " Main: 907.279.1433 ALAsIP Fax: 907.276.7542 www.aogcc.alaska.gov MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. F r001) i}I(3 P.O. Box 100360 5S Anchorage, AK 99510 Re: Kuparuk River Field, Tarn Oil Pool, KRU Tarn 2N-331 Permit to Drill Number: 198-117 Sundry Number: 316-101 Dear Ms. Loveland: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster .��// Chair DATED this Jd ty of February, 2016. RBDMS Lr_ FEB 1 1 2016 0 0 RECEIVED STATE OF ALASKA FEB 5 2016 ' ALASKA OIL AND GAS CONSERVATION COMMISSION Z!// �� APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon r Rug Perforations r Fracture Stimulate r Repair Well r Operations shutdown r Suspend r Perforate r Other Stimulate r Pull Tubing r Change Approved Program r Rug for Redrill r Perforate New Pool r Re-enter Susp Well r Alter Casing F.7• Other: Conductor Extend R 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc.. Exploratory r Development r 198-117 3.Address: Stratigraphic r Service (;r 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-103-20265-00 • 7. If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?_NA Will planned perforations require spacing exception? Yes r No p J KRU Tarn 2N-331 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0380054 , Kuparuk River Field/Tarn Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): • 11225 5252 • 11118' 5206' 3400' Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 108' 108' SURFACE 3813 7 5/8 3841' 2305' PRODUCTION 10355 51/2 10384' 4779' PROD Liner 832 3 1/2 11216' 5247' Perforation Depth MD(ft): "co3.9l -PO Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10715-1100 4981-5157 3.5 L-80 10361 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) NIPPLE-CAMCO DS NIPPLE i MD=494 TVD=493 SEAL ASSY-BAKER 80-40 CASING SEAL ASSEMBLY . MD=10363 TVD=4770 12.Attachments: Proposal Summary r WeilBore Schematic r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service r. 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 02/25/16 OIL r WINJ r WDSPL r Suspended r 16.Verbal Approval: Date: GAS r WAG F.7, GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdow n r Abandoned r 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact: MJ Loveland Printed Name MJ Loveland Phone:659-7043 Email: n1878@c0n0Cophillips.Com Title: NSK Well Integrity Project Supervisor / Signature ,Z1/77/14/ '' ''' � 1/77 ��/'� Date: 2/3/// / / tJ 3 // Commission Use Only JJ Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Rug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: p h o tb cI o c v J-1.,1 7 r.,'f-- Sv b-5 1-1,`oft yr c c ct, � ci 1-7-Pa1 r- Post Initial Injection MIT Req'd? Yes r No Spacing Exception Required? Yes r No J7' Subsequent Form Required: /0 —40 et._ APPROVED BY Approved by: 54- - COMMISSIONER THE COMMISSION Date:2-10_/4 V r /zii ii -?f 2J2)5'4RBDMS 1, ' FEB 1 1 201f1ubmit Form and Form 10-403 Revised 11/2015 0 R4,6�' 1p A Land for 12 months from the date of approval. Attachments in Duplicate • • ConocoPhillips RECEWED Alaska P.O. BOX 100360 FEB 0 5 2016 ANCHORAGE,ALASKA 99510-0360 AOGCC February 3, 2016 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Foerster: Enclosed please find the 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 2N-331, PTD 198-117 conductor extension. Please contact me at 659-7043 if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska,Inc. Kuparuk Well 2N-331 (PTD 198-117) SUNDRY NOTICE 10-403 APPROVAL REQUEST 02-03-16 This application for Sundry approval for Kuparuk well 2N-331 is to extend the conductor to original height so as to stabilize tree and prevent any corrosion to the surface casing. At some point during normal operations the conductor subsided about 20". With approval, the conductor extension will require the following general steps: 1. Remove landing ring from conductor if necessary. 2. Examine surface casing for any corrosion damage if it is exposed. 3. Extend the conductor to starter head. 4. File 10-404 with the AOGCC post repair. NSK Well Integrity Projects Supervisor KUP INJ • 2N-331 ConocoPh1 ips9 Well Attributes Max Angle&MD TD 0 Alaska,Inc. Wellbore APIIUWI Field Name Wellbore Status Inc!(") MD IftKB) Act Btm(ftKB) C c.vrrJhA,p 501032026500 TARN PARTICIPATING AREA INJ 71.41 8,800.00 11,225.0 -.. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2N-331,10/21/20141017;27 AM SSSV:NIPPLE Last WO: 34.99 9/11/1998 Vertical schematic(actual Annotation Depth(ft613) End Date Annotation Last Mod By End Date 'Last Tag:SLM 10,999.0 10/17/2014 Rev Reason:TAG hipshkf 10/21/2014 a.- HANGER;23.9 Casing Strings Casing Description OD(in) ID(in) Top IrtKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I_Grade Top Thread i , CONDUCTOR 16 15.062 28.9 108.0 108.0 62.58 H-40 WELDED Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 75/8 6.875 28.9 3,841.4 2,305.7 29.70 L-80 BTC-MOD Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 5.5"x3.5" 51/2 4.950 26.0 11,215.9 5,247.0 15.50 L-80 LTC MOD i%- @ 10384" 1 "'/Tubing Strings AA.,CONDUCTOR;28.9-108.0 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..,Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING 31/2 2.992 23.9 10,379.4 4,778.6 9.30 L-80 EUEBRDMOD Completion Details NIPPLE;494.0 ate} Nominal ID Top(ftKB) Top(TVD)(1tKB) Top Incl I") Item Des Com (in) 23.9 23.9 0.08 HANGER FMC GEN V 5M TUBING HANGER 3.500 494.0 493.4 7.08 NIPPLE 'CAMCO DS NIPPLE 2.875 10,251.8 4,712.9 61.20 SLEEVE-C BAKER CMU SLIDING SLEEVE-CLOSED 11/30/98 2.813 10,354.2 4,765.2 58.48 NIPPLE 'CAMCO D NIPPLE 2.750 10,361.3 4,768.9 5820 LOCATOR BAKER LOCATOR 2.985 10,362.8 4,769.7 58.14 SEAL ASSY BAKER 80-40 CASING SEAL ASSEMBLY 3.000 Perforations&Slots shot Dens Top(TVD) Btm(TVD) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com SURFACE;28.91,841.4- 10,715.0 10,752.0 4,968.7 4,989.3'S-8,2N-331 11/30/1998 6.0 IPERF 2.5"HC/DP,60 Deg Ph 1 r 10,762.0 10,782.0 4,994.9 5,006.0 S-7,2N-331 11/29/1998 6.0 IPERF 2.5"HC/DP,60 Deg Ph SLEEVE-C;10,251.8 10,792.0 10,812.0 5,011.6 5,022.7'S-5,2N-331 11/29/1998 6.0 IPERF 2.5"HC/DP,60 Deg Ph 10,870.0 10,880.0 5,055.1 5,060.7 S-3,2N-331 11/29/1998 6.0 IPERF 2.5"HC/DP,60 Deg Ph GAS LIFT;10,301.9II 10,888.0 10,897.0 5,065.2 5,070.3 S-3,2N-331 11/29/1998 6.0 IPERF 2.5"HC/DP,60 Deg Ph 10,908.0 10,916.0, 5,076.5 5,081.0 S-3,2N-331 '11/28/1998 6.0 IPERF 2.5"HC/DP,60 Deg Ph 10,922.0 10,937.0� 5,084.4 5,092.9 S-3,T-2,2N- '11/26/1998 6.0 IPERF 2.5"HC/DP,60 Deg Ph 331 NIPPLE;10,354.2 f F 10,991.0 11,004.0' 5,123.2 5,130.5'K-3,2N-331 11/26/1998' 6.0 IPERF 2.5"HC/DP,60 Deg Ph LOCATOR;10,361.3 11,010.0 11,029.0' 5,133.9 5,144.6 K-3,2N-331 11/28/1998 6.0 (PERF 2.5"HC/DP,60 Deg Ph 1g:1 Mandrel Inserts SEAL ASSY;10,362.8 - St f as M on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sent Type Type (In) (psi) Run Date Com -. 1 10,301.9 4,738.0 CAMCO KBG29 1 GAS LIFT DMY INT 0.000 0.0 9/11/1998 L - Notes:General&Safety End Date Annotation 6/3/2009 NOTE:ZONES NOT LOADED TO WELLVIEW YET _ 11/23/2010 NOTE:View Schematic w/Alaska Schematic9.0 (PERF;10,715.0-10,752.0 IPERF;10,782.0.10,782.0 IPERF;10,792.0-10,812.0 (PERF;10,870.0-10,890.0 (PERF;10,888.0.10,097.0 (PERF;10,908.0-10,916.0 IPERF;10922.0-10.937.0 IPERF;10,991.0-11,004.0 (PERF;11,010.0.11,029.0 PRODUCTION 5.5',43.5"M 10384";26.0-11,215.9 II . Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. ;9 t -1/7 File Number of Well History File PAGES TO DELETE Complete RES CAN o Color items - Pages: Grayscale, halftones, pictures, graphs, charts - Pages: o Poor Quality Original - Pages: o Other - Pages: DIGITAL DATA o Diskettes, No. o Other, Noffype OVERSIZED o Logs of various kinds o Other COMMENTS: I OC) f>~ Scanned by: Beverly Mildred Dareth@Lowell Date,: :::?/::z I Isl ¡Í( o TO RE-SCAN Notes: Re-Scanned by: Beveriy Mildred Daretha Nathan Lowell Date: Isl • • Page 1 of 1 Regg, James B (DOA) From: Phillips, Jim (ASRC Energy Services) [Jim.Phillips@contractor.conocophillips.com] Sent: Wednesday, August 25, 2010 3:57 PM To: Regg, James B (DOA) 2~~ z~ ~~ ~~ f" Subject: RE: State MITIA test results for 2N pad on 8/24/10 ~1,~~ Follow Up Flag: Follow up -'~'-~ )~ ~ .~ ] ( 7 Flag Status: Red ~~ Z!~ _ 3 ~ ~ Attachments: MIT KRU 2N Pad DRAFT.xIs Jim, I apologize for the mix up I am filling in for Brent this week and by mistake 1 did not double check the form before sending it off. Therefore I did not notice that it was showing 12 water injectors SI. I have attached the correct copy and again I am sorry about this mistake on my part. If you have any more questions please feel free to contact me. Jim Phillips Acting Problem Well Supervisor Email: N1617 @conocophillips.com Office: 659-7224 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Wednesday, August 25, 2010 2:36 PM To: Phillips, Jim (ASRC Energy Services) Subject: RE: State MITIA test results for 2N pad on 8/24/10 Why were all the wells SI except the gas injector? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 ~..: Ss t`~uu rr ~~~.~ w ~> if f f~{~4 From: Phillips, Jim (ASRC Energy Services) [mailto:Jim.Phillips@contractor.conocophillips.com] Sent: Wednesday, August 25, 2010 8:57 AM To: Regg, James B (DOA); Brooks, Phoebe L (DOA); Maunder, Thomas E (DOA); DOA AOGCC Prudhoe Bay Subject: State MITIA test results for 2N pad on 8/24/10 All, Attached is the MITIA tests for 2N pad that were waived by Chuck Shieve on 08/24/10. Jim Phillips Acting Problem Well Supervisor Email: N1617 @conocophillips.com Office: 659-7224 8/26/2010 Email to:jim.regg@alaska.gov; phoebe.brooks@alaska.gov; tom.maunderr~alaska.gov; doa.aogcc.prudhoe.bay@alaska.gov STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: r~ u ConocoPhillips Alaska Inc. ~Q~/' ~;~I/~ Kuparuk /KRU / 2N Z 08/24/10 Ives/Mouser AES Packer De th Pretest Initial 15 Min. 30 Min. Well 2N-302 T e In'. W ND 5,185' Tubin 1,860 1,860 1,860 1,860 Interval 4 P.T.D. 2011150 T etest P Test si 1500 Casin 1,210 2,540 2,520 2,520 P/F P Notes: OA 235 265 260 260 Well 2N-306 T e In'. W ND 5,174' Tubin 2,150 2,150 2,150 2,150 Interval 4 P.T.D. 2040620 T etest P Test si 1500 Casin 1,245 2,820 2,760 2,760 P/F P Notes: OA 375 550 520 520 Well 2N-307 T e In'. W TVD 5,141' Tubin 1,500 1,500 1,500 1,500 Interval 4 P.T.D. 1990170 T etest P Test si 1500 Casin 810 2,180 2,150 2,150 P/F P Notes: OA 250 350 300 300 Well 2N-309 T e In'. W TVD 5,042' Tubin 1,600 1,600 1,600 1,600 Interval 4 P.T.D. 1990210 T e test P Test si 1500 Casin 775 2,225 2,100 2,080 P/F P Notes: OA 300 365 340 340 Well 2N-310 T e In'. W TVD 5,004' Tubin 1,550 1,550 1,550 1,550 Interval 4 P.T.D. 2070900 T e test P Test si 1500 Casin 440 2,300 2,250 2,250 P/F P Notes: OA 270 390 350 350 Well 2N-314 T e In'. W ND 5,046' Tubin 1,600 1,600 1,600 1,600 Interval 4 P.T.D. 2001930 T e test P Test si 1500 Casin 600 2,300 2,270 2,270 P/F P Notes: OA 225 240 240 240 Well 2N-321A T e In'. W ND 4,915' Tubin 1,500 1,500 1,500 1,500 Interval 4 P.T.D. 1981730 T e test P Test si 1500 Casin 575 2,280 2,250 2,250 P/F P Notes: OA 250 450 450 450 Well 2N-326 T e In'. W ND 4,821' Tubin 1,860 1,860 1,860 1,860 Interval 4 P.T.D. 2001550 T etest P Test si 1500 Casin 1,150 2,760 2,720 2,710 P/F P Notes: OA 360 460 460 460 Well 2N-331 T e In'. W ND 4,770' Tubin 1,460 1,460 1,460 1,460 Interval 4 P.T.D. 1981170 T etest P Test si 1500 Casin 460 2,200 2,150 2,150 P/F P Notes: OA 300 480 480 480 Well 2N-335 T e In'. W ND 4,966' Tubin 1,950 1,950 1,950 1,950 Interval 4 P.T.D. 1982040 T e test P Test si 1500 Casin 560 2,800 2,600 2,590 P/F P Notes: OA 200 430 430 430 Well 2N-343 T e In'. G ND 4,937' Tubin 3,350 3,350 3,350 3,350 Interval 4 P.T.D. 1980920 T e test P Test si 1500 Casin 850 2,780 2,630 2,620 P/F P Notes: OA 400 420 420 420 Well 2N-348 T e In'. W ND 4,374' Tubin 1,500 1,500 1,500 1,500 Interval 4 P.T.D. 2011420 T e test P Test si 1500 Casin 630 2,280 2,240 2,240 P/F P Notes: OA 190 320 320 320 Well 2N-349A T e In'. G TVD 5,078' Tubin 1,625 1,625 1,625 1,625 Interval 4 P.T.D. 2001390 T e test P Test si 1500 Casin 280 2,320 2,250 2,250 P/F P Notes: OA 150 250 250 250 Well 2N-325 T e In'. W ND 5015' Tubin 1,975 1,975 1,975 1,975 Interval 4 P.T.D. 1981630 T e test P Test si 1500 Casin 750 2,675 2,630 2,630 P/F P Notes: OA 220 250 240 240 TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R = Intemal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11!27/07 MIT KRU 2N Pad 08-24-10 Revised1.xls . . Conoc~illips Alaska RECEIVED SEP 1 2 Z007 "tMk. 0" & Gas Cons. Commission Anchorage P.o. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 09,2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 5CANNI:D SEP 12 2007 !'1'3 - 117 ~N- 331 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with a 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 corrosion inhibitor/sealant was pumped on September 8, 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call M.J. Loveland at 907-659-7043, if you have any questions. :2~-~' ConocoPhillips Well Integrity Field Supervisor . . ConocoPhillips Alaska Inc. Suñace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 9/9/2007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitorl Well Name PTO# cement pumped cement date inhibitor sealant date ft bbls ft aal 2N-327 207-069 12" nla 12" nla 3.5 9/8/2007 2N-329 198-067 24" nla 24" nla 6 9/8/2007 2N-331 198-117 26" nla 26" nla 2 9/8/2007 2N-332 200-079 8" nla 8" nla 2 9/8/2007 2N-333 206-025 29" nla 29" nla 8.5 9/8/2007 2N-349 200-139 3" nla 3" nla 1 9/8/2007 2N-350 201-175 11" nla 11" nla 4.5 9/8/2007 2P-438 201-082 4' 10" nla 4'10" nla 2 9/8/2007 Œ 04/05/07 SC...'11'981' RECEIVED NO. 4205 ..",.-.. Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth APR 0 6 Z007 ~ OJI & Gas Cons. Commission Arn..i1orage Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 SCANNED APR 1 () 2007 UTC- {Cì1)-/l1- Field: Kuparuk WeU Log Description BL CD Color Job# Date 2M.12 11632681 PRODUCTION PROFILE 03/29/07 1 3S-22 (REDO) N/A INJECTION PROFILE 03/16/07 1 1 H-11 11665413 PRODUCTION PROFILE 03/31/07 1 1H-15 11686723 GLS 03/21/07 1 1 B-02 11665409 INJECTION PROFILE 03/24/07 1 2L-305 11665416 SBHP SURVEY 04/02/07 1 2L-329 11665414 SBHP SURVEY 04/01/07 1 2B-12 11628989 INJECTION PROFILE 03/21/07 1 2W-08 11632687 SHUT IN BHP 04/04/07 1 2A-09 11686726 MEM PROD PROFILE 03/24/07 1 1H-04 11632682 INJECTION PROFILE 03/30/07 1 2P-449 11688724 PRODUCTION PROFILE 03/22/07 1 1H-02' 11638845 GLS 03/21/07 1 2W-OS 11632686 SHUT IN BHP 04/03/07 1 1A-26 . 11686725 MEM PROD PROFILE 03/23/07 1 2N-33t N/A INJECTION PROFILE 03/23/07 1 3A-06 . 11665407 INJECTION PROFILE 03/22/07 1 1J-160. 11665412 USIT 03/29/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 1'6 . . MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor -Po / . '3 I' i 0(0"; f....J~·.¿, '~1. L DATE: Wednesday, August 09, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC FROM: Chuck Scheve Petroleum Inspector 2N-33! KUPARUK RIV U TARN 2N-331 tqß-\\ 7 Src: Inspector Reviewed By: P.I. Suprv.:Jl3'e-- Comm NON-CONFIDENTIAL Permit Number: 198-117-0 Inspector Name: Chuck Scheve Inspection Date: 8/812006 Well Name: KUPARUK RIV U TARN 2N-33 1 Insp Num: mitCS060808191745 Rei Insp Num API Well Number 50-103-20265-00-00 Packer Well Tm-33! IType Inj. : W I TVD ~: i 198I170 ¡TypeTest I SPT I Test psi ! Interval 4YRTST P/F P Depth 4770 I IA Pretest 950 Initial 15 Min. 30 Min. 45 Min. 60 Min. 2530 2520 2520 1500 . OA I i , VTubing I 400 550 550 1650 550 I , ---¡----~ -~ 1650 1650 1650 Notes Pretest pressures were observed and found stable. Well demonstrated good mechanical integrity. s(;ANNED AUG 2 4: 2008 Wednesday, August 09, 2006 Page 1 of 1 . . \ S ~-~ \ \ "\ tŒCRANICAL INTEGRITY REPORT "' :~ l G £\ E ~ .:: ;_ :: ~ : OPER & FIELD (\'I\-!: "" Q \J T ~,~ í-.-""E:ll NU1{BER d- N - ~ ~ \ -...,uo ...,,~- := :' L; ..:.. .:...:. : ~é< [,.LL DATA TD: . MD.. TVD: :?ETD: MD TVD TVD¡ DV: ~~ MD TV1J j :CF: \0 )~y HD ·Tvu C¿si:;g: ~O-\,~\ _ :..:-¡e:- : ~~J) .~ \{ J Shoe: lO~\s-l..\ rID Shoe: l\ð-\ <0 MD (~Q. Packe:::- \O~~~Jm ~ ~/, ana ;:~;!) :-:Joi.:;g: TVTI í Set ê. C ::ole Size Pe:-£s \a~l ç- to :~Cr.Þ_NIC¡'..L INTEGRITY - ?lillT 11 Annulus Press Test: IP 15 min ; 3 0 m~n COGElents: ~ct\\ ~c;.. ~ßÇ.5ci:) ,\,,\,~D..\ r; Si;.j\1s.e~·-.::,c:ø'L<\- ~'-\ C~OJ-) r ~Q::¥-\- ~é ~tJa Co . r- r'" 5&~~\s. J%\ S'f ~CHÞ~ICÞ~ INTEGRITY - PART 12 Cemenc Volumes:' l\mt. Liner ; Csg ; DV Cï:üt -"01 Co cove~ Der=s ~~ö'(c'k~ \"\0 ~'!(. \'.~·c.tr';,.~'""'r--\-a ~<.:."'/...D "I2eorecical TOC e ~O(C) v... ~ *"~~V\cú.\ \Dc... Sd-Oa I ')c..k \" l\bš-<;' <;s-- '. Cement Bond Log (Yes or No) ~~~ : In AOGCC File ·i<t5;.. CEL ~valua tion, zone ¿Dove pe.rfs 'öo~·~~~\Z\.~ c:....ð£J.o..~e::. " .J ~a..~~ '\. 'S ~O \\'1 -\--\" ,"a\':)~'\\K~DJCJ. \ Proàu~tion Log: Type ¡Evaluation CONCLUSIONS: . _I"" "I" . ~f{' :'¡",ßjí""l"'j' \.-,t,,j'(;; \." 'i.!!:--' "'--;-, '\ ()C,f'¡'{ )~, lJ ,"u L.}J ? ar C t 1 : ? ar:: ; z : \-l WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC 333 W. 7th Street Suite 700 Anchorage, Alaska 99501 RE' Distribution - Final Print[s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of' Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. 0. Box 13S9 Stafford, TX 77497 LOG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT[S) OR CD-ROM FILM BLUE LINE Open Hole 1 I 1 ~1~_ I 1 2N-331 7-16-03 Res. Eval. CH ) 0~ ~,'2-) I Mech. CH Caliper Survey 1 Rpt or 2 Color Signed ' Print Name: ProActive Diagnostic Services, Inc., PO Box ! 369 Stafford TX 77477 Phone:(281) 565-9085 Fax:(281) 565-1369 E-mail: pds~memorylog, com Website: www.memorylog.com MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille O. Taylor (~ DATE: August 3, 2002 Chair .... /I SUBJECT: Mechanical Integrity Tests THRU: Tom MaunderJO~'~'~'~l~-~ Phillips Alaska P.I. Supervisor ~ 2N Pad FROM: John Crisp Petroleum Inspector Kuparuk River Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. i. ,,WellI 2N-307IType,nJ.I G i ~.v.o.l'~'~' ITL~bingl 3150 l, 3150 I 3150 I 32,00 Ilntervall 4, , P.T.,D.! 1990170 ITypetestl P, ITestpsil 1500 I CasingJ 2275 I 2900 I 2900 I 2900 I P/F I P-- Notes: 'w.,.! 2.-321A ITYpe,n~.l S I T.V.D. I 4915 I T.b,ngl 17.00 1"1700 I' 1700 l 1700 I,nte~a,I 4 P.T.D.I 1981730 ~Typetest~ P IT,estpsi~ 1500 I,Casingl 100 I ,2150, ~,. 2150 I 2150 ,I PIF ,I P, Notes: Welt P.T.D. Notes: Well] P.T,D.' Notes: Well , P.T.D.I Notes: 2N-325 ITYpelnj. J G IT'v'D' ! 5o15 I Tubingl 2~0I 2650I 2650I 2~5o 'lll~tervall 4" 1981630 ITypetestl P I'l:estpsil 1500 ICasingI 1075 I 1956 I 19461 1940 I' P/F I P 2N-331 J Type,.j.J S I T.v.D. 14770 I Tubing i 1675 '1 1875 11675 11675 l ir~te;vaq 4I' 1981170 Itype{estJ ,P JTestpsiJ 1500 J C,asingJ 600 I 2025 I 2025J 2025 J' P/,F ,J ~l 2,-~3 I TY,e,nJ.I G I T.V.O. I 4938 I Tubing I m2550 I 2~50 I 2550 II :~550 111~tervalj 4 1980920 JTyp'etestJ P JTestpsiJ 1500 JCasingJ 2000J 2925-j 2925J 2925J P/F J E Type INJ, Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required byVariance W= Test dudng Workover O= Other (describe in notes) Test's Details I traveled to PAl's Kuparuk River Field to witness 4 year MIT's on 2N Pad. No failures witnessed. M.I.T.'s performed: Attachments: Number of Failures: O_ Total Time during tests: 4, hm. CC'- SCANNED AUG 1 P., 2002 MIT report form 5/12/00 L.G. 020803-MIT KRU 2N JC.xls 8/5/2002 W li compiiance Report File on Left side of folder 198-117-0 KUPARUK RIV U TARN 2N-331 50- 103-20265-00 PHILLIPS ALASKAINC Roll #1: Start: Stop Roll #2: Start Stop MD 1 1225 TVD 05252 Completion Date: 9/11/98 Completed Status: WAG1N Current: Name Interval D 8793 2 SPERRY MPT/GR/EWR4/CNP/SLD OH L CBL/SCMT FINAL 10250-11041 CH 2 L DGR/CNP/SLD-MD FINAL 3871-11225 OH L DGR/CNP/SLD-TVD FINAL 2313-5265 OH L DGR/EWR4-MD FINAL 3871-11225 OH L DGR/EWR4-TVD FINAL 2313-5265 OH L MI INJP FINAL 10200-11001 CH 2 R GYRO CONT. MULTI GYRODATA TBNG 0-10850. CH R SRVY CALC Daily Well Ops ____ --- -- Was the well cored? yes no Comments: Sent Received T/C/D · 12/16/98 12/17/98 12/21/98 1/5/98 12/16/98 12/17/98 12/16/98 12/17/98 12/16/98 12/17/98 12/16/98 12/17/98 1/20/99 1/21/99 12/7/98 12/7/98 BHI 108-I 1225. OH ,~2/24/98 12/28/98 Are Dry Ditch Samples Requir~ed? yes n ' And Received? yes no Analysis Description Received. yes~ Sample Set # Wednesday, November 08, 2000 Page 1 of 1 WELL LOG TRANSMITYAL 0: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.' Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 ~ ~ '~ {[ q December 16, 1998 LE: MWD Formation Evaluation Logs 2N-331, AK-MM-80359 he technical data listed below is being submitted herewith. Please address any problems or concerns :o the attention of.' Mi Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 2N-331: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-103-20265-00 2"x 5" TVD Resistivity & Gamma Ray Logs: 50-103-20265-00 2"x 5"MD Neutron & Density Logs: 50-103-20265-00 2"x 5" TVD Neutron & Density Logs: 50-103-20265-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 l~'olded Sepia DEC 17 1998 0il & Gas O~ns. Commissioa Anchorage 5631 8ilverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company ARCO Alaska, Inc. J/' 'PARUK RIVER UNIT '~ WI~-~ SERVICE REPORT ~,~ r O~l~ ~%['~ K1(N-331(W4-6)) WELL ~ JOB SCOPE JOB NUIglBER 2N-331// PERFORATE, PERF SUPPORT 093098t8~3§.t ~GA--T E DALLY WORK ........... U N· NUMBER 11/30/98 TAG FILL, DRIFT TUBING, AMERADA SBHP, CLOSE CMU SLEEVE 70175 DAY OPERATION COMPLETE I S~;ESSFUL KEY PERSON SUPERVISOR 12 (~ Yes O No I ..... ~ yes O No HFS-FELL FITZPAT...RICK FIELD AFC# CC# DAILY COST AOCUM COST Signed ..... ESTIMATE K851 O5 180 KN U 2TN $3,110 $166,979 Initial Tbg Press Final Tbg Press Initial In,er Ann Finai"~'~'~"Ann ~ Initial Outer Ann ~ Final Out:er Ann ..... 225 PSI 200 PSI 150 PS/ 500 PS~I. 250 PSII 250 PSI DALLY SUMMARY TAGGED @ 11029' RKB, NO FILL/RATHOLE. MEASURED BHP @ 10930' RKB: 2166 PSI. CLOSED SLEEVE @ 10251' RKB. TESTED CSG 2500 PSI, OK [Pres.~ure Data, Tag] TIME LOG ENTRY 14:20 ON LOCATION, HSE MEETING, DESIGNATE MUSTER AREA, DISCUSS JOB PROCEDURE_ 14:30 MIRU HFS AND LITTLE RED SERVICES 2,125" RLR STEM TS: RS, QC, 5', KJ, 5', K J, LSS, QC 14:50 P/T LINES AND LUBR TO 2500 PSI, RIH W/2.68" CENT, 3' X 1.875' WB & 2.70" SWAGE TO 11014' WLM + 15' CF (11029' RKB) POOH 15:45 START AMERADA CLOCKS ,., 16:00 BEGIN INITIAL 10 MIN LUBR READING TOP AMERADA 215 PSI BOTTOM AMERADA 220 PS! 16:10 RIH W/2.68" CENT, SOFT SET & DUAL AMERADAS, TOP ELF-89424, CLOCK-18540, BO'I-rOM ELF-74733, CLOCK-18536. 16:52 BEGIN 15 MIN READING @ 10735' WLM (10750' RKB) TOP AMERADA 21a9 PSI BOTTOM AMERADA 2139 PSI 17:07 CONTINUE IN HOLE 17;08 17;38 BEGIN 30 MIN READING @ 10915' WLM (10930' RKB) TOP AMERADA 2165 PSI BOTTOM AMERADA 2166 PSI POOH W/DUAL AMERADA ASSY 17:57 BEGIN FINAL 10 MIN LUBR READING TOP AMERADA 190 PSI BO'FI'OM AMERADA 194 PS! 18:07 END OF SBHP READINGS, RIH W/3' X 1.875" WB & 4260 SHIFr TOOL TO 10236' WLM (10251' RKB) JAR DOWN ON SLEEVE 10 TIMES, FELL THRU DRIFTED SEVERAL MORE TIMES COULD NOT SIT DOWN AGAIN POOH. 19:20 19:35 P/l' ANNULUS TO 2500 PSI W/200 PSI ON TUBING, MONITOR FOR 15 MIN. GOOD TEST, ANNULUS DROPPED TO 2450 PSI, TUBING REMAINED UNCHANGED @ 200 PSI, BLEED ANNULUS TO 5O0 PSI. 20:00 CCH W/4260 SHIFT TOOL, PIN WAS NOT SHEARED ALSO INDICATING THAT SLEEVE HAD BEEN SUCCESSFULLY SHIFTED CLOSED. 20:30 RDMO sERVICE COMPANY - SERVICI~ ................ DAILY cO'~T ACCUM TOTA'~-"' . _ .............. ,$.2:00 $674.20 APC $0.00 - $7,000.00 ARCO $0.00 $500.00 BAKER OIL TO~LS ..... $0.00 $3,800.00 DIESEL $0.00 $16.80 DOWEL_L ............... $0_00 $8,779~00 GYRO DATA .. $0.00 $8,000.00 HALLIBURTON ..... $1,710.00 $18,622.00 ,, LR-FLE RED ..... $1,40~.(J0 , $16,~55.00 MI FLUIDS $0.00 $1,000.00, _..SCHLUMBERGi~i~· . _... , ..... . $16,000.00 $89,632.50 TOTAL FIELD ~STIMATE ............................. $19,110.00 $156,979.50 i 1/20/99 GeoQuest 3940 Arctic 81vd Anchorage, AK 99503 ATTN: Sherrie NO. 12257 Company Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk/Tarn Pool Well Job # Log Description Date BL Sepia 2B-01 PRODUCTION PROFILE 990114 1 1 2M-18 ~ ~ C..-. MI INJECTION PROFILE 990105 1 1 2W-10 U~.t (,,, MI INJECTION PROFILE 990102 1 1 3N-05 U,.~ C._, INJECTION PROFILE 981212 1 1 2N-321A MI INJECTION PROFILE 990103 1 1 2N-331 MI INJECTION PROFILE 990104 1 1 SIG Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: · '~' ~. ,o 'l: ~ ,,.,~ , 12/21/98 GeoQuest 3940 Arctic Blvd Anchorage. AK 99503 ATTN: Sherrie NO. 12181 Company Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage. AK 99501 Field: Kuparuk Well Job # Log Description Date BL Sepia 1D-110 CBL-SCMT 981020 1 1 2L-329A CBL-SCMT 981122 1 1 2L-329A PRODUCTION LOG 981205 1 1 2L-329A PRODUCTION LOG 981207 1 1 2N-321A CBL-SCMT 981109 1 1 2N-325 CBL-SCMT 981108 1 1 2N-325 MI INJECTION PROFILE 981205 1 1 2N-331 CBL-SCMT 981123 1 1 1E-35 CEMENT MAPPING LOG 981203 1 1 1 E-35 PRODUCTION LOG 981208 1 1 1 E-36 STATIC PRESS/TEMP 981123 1 1 1G-16 bt.~C__. MI INJECTION PROFILE 981202 1 1 1Q-07 STATIC PRESS/TEMP 981119 1 1 1Y-15A CBL-SCMT 981109 1 1 2M-34 ~tc._. MI INJECTION PROFILE 981110 1 1 2W-12 PRODUCTION PROFILE 981028 1 1 3F-04 ~IC~ MI INJECTION PROFILE 981203 1 1 3F-12 tAlC MI INJECTION PROFILE 981204 1 1 3F- 19 RST WFL & GLS 981103 1 1 3G-03 PROD PROFILE W/DEFT 981104 1 1 3K-25 LI, I[. INJECTION PROFILE 981014 1 1 3K-26 ~ ~--____ INJECTION PROFILE 981014 1 1 SIGNE ~ DATE: Please sign and r~_~_~e co-p~f this transmi,al to Sherrie at the above address. Thank you. WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs December 16, 1998 2N-331, AK-MM-80359 1 LDWG formatted Disc with verification listing. API#: 50-103-20265-00 PLEASE ACKNOWLEDGE RECEIFr BY SIGNING AND RETURNING THE ATYACHED COPY OF THE TRANSMITY~ LETrER TO TI:IF. ATTENTION OF: Sperry-Sun Drilling Service Attn: Ali Turker 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 Signed'~~ 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A I-lallibufion Company ARCO Alaska, Inc. '.~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 24, 1998 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2N-331 (Permit No. 98-117) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 2N-331. If there are any questions, please call 263-4603. Sincerely, P. Mazzolini Tarn Drilling Team Leader AAI Drilling PM/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR REOOMPLETION REPORT AND LOG I Status of Well Classification of Service Well OIL [~] GAS E~ SUSPENDED [~ ABANDONED~ SERVICE F~ Injector '~'~ . 2 Name of Operator 7 Permit Number ~.~ · ARCO Alaska, Inc 98-117 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-103-20265 : ;.';:" - At At Total Depth.~. . : 11 Field and Pool 385' FSL, 314' FWL, Sec. 33, T10N, R7E, UM KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. Tarn Oil Pool RKB 28', Pad 121' ADL 380054 ALK 4602 12 Date Spudded 13 Date T.D. Reached 14 Date Comp. ~,Susp. or Aband. 115 Water Depth, if offshore 16 No. of Completions 31-Aug-98 09-Sep-98 11-Sep-98."/ I NA feet MSL 1 '17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 11225' MD & 5252' TVD 11118' MD & 5206' TVD YES M NOU N/A feet MD 1050 APPROX 22 Type Electric or Other Logs Run GR/Res, CBL 23 CASING, LINER AND CEMENTING RECORD SEI-rING DEPTH MD CASING SIZE Wl' GRADE TOP BTM HOLE SIZE CEMENT RECORD 16" 62.5# H-40 SURF. 108' 24" 9 CY High Early 7.625" 29.7# L-80 SURF. 3841' 9.875" 550 sx AS III, 250 sx Class G 5.5" x 15.5# L-80 SURF. 10384' 6.75" 281 sx Class G 3.5" 9.3# L-80 10384' 11216' 6.75" !(included above) 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) ALL 0 spT: 3.5" 10379' 10364' (CSR) 10715'-10752' MD 4981'-5001' TVD 10937'-10964' MD 5105'-5120' TVD 10762'-10782' MD 5007'-5018' TVD 10991'-11004' MD 5135'-5143' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 10792'-10812' MD 5024'-5035' TVD 11010'-11029' MD 5146'-5157' TV[; DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10870'-10880' MD 5067'-5073' TVD N/A N/A 10888'-10897' MD 5077'-5083' TVD 10908'-10916' MD 5089'-5093' TVD 27 PRODUCTION TEST A Date First Production Method of Operation (Flowing, gas lift, etc.)l nj e cto r Date of Test Hours Tested PRODUCTION FO OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOI: Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BDt 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. N/A Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GaR, and time of each phase. T-3 10654' 4934' T-2 11040' 5151' Annulus left open - freeze protected with diesel. 31. LIST OF AI~ACHMENTS Summary of Daily Drilling Reports, Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title '~,~,1.~ Z~ ~.~/~ DATE Prepared by Name/Number Sharon AIIsup-Drake/263-4612 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-sku 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 Date: 12/4/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:2N-331 WELL ID: AK9413 TYPE: AFC: AK9413 STATE:ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD: KUPARUK RIVER UNIT SPUD:08/31/98 START COMP: RIG:RIG # 141 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20265-00 08/30/98 (D1) TD: 108' (108) SUPV:D.BURLEY 08/31/98 (D2) TD: 2419' (2311) SUPV:D.BURLEY 09/01/98 D3) TD: 3851' 1432) SUPV:M.C. HEIM 09/02/98 D4) TD: 3851' 0) SUPV:M.C. HEIM 09/03/98 D5) TD: 3851' 0) SUPV:M.C. HEIM 09/04/98 (D6) TD: 3851' ( 0) SUPV:M.C. HEIM MW: 9.7 VISC: 108 PV/YP: 27/35 DRILLING 9 7/8" HOLE FROM 500' APIWL: 8.2 Move rig from 2N-321A to 2N-331. NU diverter. Accept rig @ 1600 hrs. Function test diverter. MW: 10.1 VISC: 54 PV/YP: 15/15 DRILLING 9 7/8" HOLE FROM 3070' APIWL: 5.8 Drill from 108' to 2419' Encountered hydrates @ 1350' MW: 10.3 VISC: 56 PV/YP: 19/18 APIWL: 4.6 CLEAN OUT TIGHT SPOT @ 520 (24 HRS. RIG POWER) Drilling and surveys rom 2419 to 3851' MW: 10.3 VISC: 125 PV/YP: 24/39 RIG UP TO CIRC. APIWL: 3.8 POH, tight from 900 to 460'. RIH to 490' Hit bridge. Wash and ream tight hole from 490' to 870'. Rig up to run 7-5/8" casing, hit bridge @ 475' MW: 10.3 VISC: 50 PV/YP: 19/22 N/U BOPE APIWL: 3.6 Finish running 7-5/8" casing. Pump 1st and 2nd stage cement. While chasing closing plug, 16 bbls short of bumping plug, was getting approx, third returns. Clean cement out of conductor and diverter, rig down diverter lines, noticed cement flowing in annulus. Close annular. Allow cement to set. WOC. MW: 9.5 VISC: 46 PV/YP: 10/15 POH F/ DRLG. ASSEMBLY. APIWL: 7.2 N/U BOPE and test. Clean out cement to 1573'. Drill out plug and stage collar. 09/05/98 (D7) MW: 9.2 VISC: 51 PV/YP: 12/18 APIWL: 6.6 TD: 4790' ( 939) DRLG. & SURVEYS @ 5350' SUPV:M.C. HEIM Drilling cement, baffle, float collar, shoe and 20' new hole to 3871'. Perform LOT to 16.0 EMW. Perform FIT to 16.15 ppg, same results. Drilling from 3871' to 4790' 09/06/98 D8) TD: 6672' 1882 SUPV:M.C. HElM 09/07/98 D9) TD: 8491' 1819 SUPV:M.C. HEIM 09/08/98 D10) TD: 9850' 1359 SUPV:M.C. HEIM 09/09/98 Dll) TD:11225' 1375 SUPV:M.C. HEIM 09/10/98 (D12) TD:11225' ( 0 SUPV:M.C. HEIM 09/11/98 (D13) TD:11225' ( 0) SUPV:M.C. HEIM 09/12/98 (D14) TD:11225' ( 0) SUPV:M.C. HEIM MW: 9.3 rISC: 48 PV/YP: 12/11 DRLG. & SURVEYS @ 7300. Drilling from 4790' to 6672' MW: 9.4 VISC: 49 PV/YP: 14/17 APIWL: 5.6 DRLG. & SURVEYS @ 8991. ( 24 HRS. RIG POWER) Drilling from 6672' to 8491' MW: 9.4 riSC: 45 PV/YP: 10/10 DRLG. & SURVEYS @ 10350. (GAS 8 UNITS) Drilling and surveys from 8491' to 9850'. Perform LOT, EMW 12.8%. MW: 10.0 riSC: 49 PV/YP: 18/18 LAYING DOWN 4" DP. (24 HRS. RIG POWER) Drilling and surveys from 9850' to 11225. MW: 10.0 VISC: 47 PV/YP: 18/15 SETTING 5.5" PACKOFF. Run 3.5" tubing. MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 MOVING RIG F/ 2N 331 TO 2N 325 Pump cement. Run 3.5" tubing. Freeze protect well. ND BOPE. NU master valve and test to 5000#. MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 MOVING RIG. Release rig from 2N-331 to 2N-325 @ 0300 hrs. 9/12/98. APIWL: 6.0 ( 24 HRS. R APIWL: 4.6 APIWL: 4.0 APIWL: 3.6 ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(2N-331(W4-6)) WELL JOB SCOPE JOB NUMBER " 2N-331 PERFORATE, PERF SUPPORT 0930981839.1 DATE DAILY WORK UNIT NUMBER 11/23/98 SCMT LOG 2128 DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 5 NO NO SWS-ELMORE LIGENZA FIELD AFC# CC# Signed ESTIMATE K85105 180KNU2TN Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 0 PSI 0 PSI 0 PSI 0 PSII 0 PSI I DAILY SUMMARY ICOMPLETE CEMENT BOND LOG FROM TD 11,046' TO 10,200'. PERFORATED 1 OF 11 ZONES, FROM 10,944' - 10,964', ATTEMPT TO PERF FROM 11,010' TO 11,029'. UNABLE TO GET PAST 10,090'.[Perf] TIME LOG ENTRY 08:00 MIRU SWS / HOT OIL. TGSM, DISCUSSED RIG UP W/HOT OIL IN CASE WE NEED TO BE PUMPED DOWN HOLE. NO CHECK VALVE ON LINE TO 2N-329 IN ORDER TO BE ABLE TO SUCK LINE BACK. ALSO CURRENT WIND CONDITIONS 18 - 25 MPH. 09:30 RIH W/LOGGING TOOLS TOTAL LENGTH = 39'. 11:25 LOG UP FROM 10,800'. FOR TIE IN. WHP = 1,000 PSI. 11:40 TAG BOTTOM AT 11046'. LOG UP REPEAT TIE IN. 12:10 LOG UP FROM TD TO 10,200'. ALL LOGS W/1,000 PSI. 12:40 COMPLETED LOGGING. POH. 15:15 RIH W/CCL 20'X 2-1/2" HC, DP, 6 SPF, 60 DEG PHASE, ROLLERS ON BOTTOM. 3.5' FROM CCL TO COLLAR. TIE IN, LOCATE AT 10,940.5' TO SHOOT FROM 10,944' TO 10,964'. 16:40 ON LOCATION AT 10,940.5'. TUBING PRESSURE AT 200 PSI. INDICATION SHOTS FIRED. LOG UP. POH 17:50 RIH W / CCL 19' X 2-1/2" HC, DP, 6 SPF, 60 DEG PHASE, ROLLERS ON BOTTOM. 4.5' FROM CCL TO COLLAR. TIE IN, LOCATE AT 11,005.5' TO SHOOT FROM 11,010' TO 11,029'.. 19:00 UNABLE TO GET PAST 10,090'. SUSPECT DEBRIS BELOW LAST PERF. 20:00 MADE SEVERL ATTEMPTS TO GET DOWN TO LOCATION. UNABLE TO GET PAST 10,090'. POH 21:00 RDMO FOR SLICK LINE. 0 WH PRESSURE AT RIG DOWN. ARCO Alaska, Inc. KUPARUK RIVER UNIT ,~, WELL SERVICE REPORT '~' K1(2N-331(W4-6)) WELL JOB SCOPE JOB NUMBER " 2N-331 PERFORATE, PERF SUPPORT 0930981839.1 DATE DAILY WORK UNIT NUMBER 11/26/98 PERF DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 8 NO YES ALLDEREGE KRALICK FIELD AFC# CC# Signed ESTIMATE K85105 180KN U2TN Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann Final Outer Ann 50 PSI 200 PSI 0 PSI 0 PSII 0 PSI 0 PSI DAILY SUMMARY PERF W/2.5" HC/DP/6 SPF/60 DEGREE PHASING FROM - 10,964'-10,937'/10,991 '-11,004' - SHOT W/200 PSI OVERBALANCE ON THE WELL - STRANDED WIRE @ 40' FROM SURFACE - CLOSED BOP'S, PULLED STRANDED WIRE OUT, TIED TOGETHER AND PULLED OUT TOOLS - LOST 5.1' OF ROLLER STEM OFF BOTTOM OF TOOL STRING - 7 RUNS LEFT ON PERF JOB[Perf] TIME LOG ENTRY 07:00 MIRU SWS 07:45 REBUILD HEAD 08:45 RIH W/CCL/SAFE/13' GUN 6 SPF/DP/2.5"HC/60 PHASED TO 10,922' - 10,937' - TIE IN AND SHOOT ~ ALL SHOTS FIRED - TAG BOTTOM AFTER SHOT 4' HIGH TO GET BOTTOM SHOTS OFF 10:00 RIH W/SAME TO SHOOT 13' @ 10,991' - 11,004' - POOH ALL SHOTS FIRED 11:30 RIH W/SAME TO SHOOT @ - POOH - HUNG UP @ 40' - PUMP MEOH - SHUT BOP'S TO CHECK WIRE 14:00 BLED OFF ABOVE BOTTOM BOP'S - POP LUB - WIRE CLAMP - CHAIN CLAMP TO BOP'S - A-I-['EMPT TO PULL OUT WIRE FROM GREASE HEAD - WIRE BROKE ABOVE CLAMP - LAY DOWN LUB - STRIP THROUGH BOP'S TO CLOSED MASTER VALVE - BACK THREAD GREASE HEAD 16:30 ADD TWO SECTIONS LUB - TIE WIRE TOGETHER AND TAPE - STAB LUB - OPEN MASTER AND BOP'S - PULL TOOLS TO SURFACE AND SHUT MASTER AND SWAB VALVE - DISCOVERED 5.1' OF ROLLER STEM OFF BOTTOM OF TOOL STRING MISSING AND PRESUMED DOWNHOLE 18:30 LAY DOWN EQUIPMENT AND REHEAD 20:00 RDMO TO STANDBY @ 2L-313 ARCO Alaska, Inc. KUPARUK RIVER UNIT ,k, WELL SERVICE REPORT '~ K1(2N-331(W4-6)) WELL JOB SCOPE JOB NUMBER " 2N-331 PERFORATE, PERF SUPPORT 0930981839.1 DATE DAILY WORK UNIT NUMBER 11/28/98 PERF DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 10 NO YES SWS-JOHNSON KRALICK FIELD AFC# CC# Signed ESTIMATE K85105 180KNU2TN Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 100 PSI 100 PSI 0 PSI 0 PSIII0 PSI 0 PSI DALLY SUMMARY PERF USING 2.5" HC/6 SPF/60 DEGREE PHASING/DP @ 11,010'~ 11,029' (19') & 10,908' - 10,916' (8') TIME 16:30 17:30 18:00 LOG ENTRY MIRU SWS P/T BOP AND LUB TO 3500 PSI - TGSM RIH W/2.5" HC/6 SPF/DP/60 DEGREE PHASED GUNS TO SHOOT LOWEST ZONE FROM 11,010' - 11,029' - TIE IN AND SHOOT - POOH ALL SHOTS FIRED 20:00 RIH W/SAME TO SHOOT FROM 10,908' - 10,916' - TIE IN AND SHOOT - POOH ALL SHOTS FIRED 23:00 RDFN SWS ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(2N-331(W4-6)) WELL JOB SCOPE JOB NUiVIBER " 2N-331 PERFORATE, PERF SUPPORT 0930981839.1 DATE DAILY WORK UNIT NUMBER 11/29/98 PERF DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 11 NO YES SWS-JOHNSON KRALICK FIELD AFC# CC# Signed ESTIMATE K85105 180KNU2TN Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 100 PSI 200 PSI 100 PSI 100 PSII 250 PSII 250 PSI DAILY SUMMARY IPERF USING 2.5" HC/DP/6 SPF/60 DEGREE PHASED GUNS @ 10,888' - 10,897' (9') / 10,870' - 10,880' (10') / 10,792' - 10,812' (20') 10,762' - 10,782' (20') SHOT WITH 200 PSI ON TBG[Pert'] TIME 07:45 MIRU SWS 08:45 09:00 11:45 14:00 16:30 17:45 LOG ENTRY P/T BOP AND LUB TO 3500 PSI - TGSM (COLD WEATHER - WATCH EACH OTHER) RIH W 2.5" HC/DP/6 SPF/60 DEGREE PHASED GUN TO SHOOT @ 10,888'- 10,897'- TIE IN AND SHOOT - POOH ALL GUNS FIRED RIH W/SAME TO SHOOT 10,870' - 10,880' - TIE IN AND SHOOT - POOH ALL SHOTS FIRED RIH W/SAME TO SHOOT 10,792' - 10,812' - TIE IN AND SHOOT - POOH - STOPPED @ 8490' - WORKED WIRE AND FINALLY PULLED FREE - CONTINUE OUT OF HOLE - ALL SHOTS FIRED PUMP 10 BBLS DIESELW LRS @ 2 BPM RIH W/SAME TO SHOOT 10,762' - 10,782'- TIE IN AND SHOOT - POOH - ALL SHOTS FIRED 21:00 RDFN SWS ARCO Alaska, Inc. KUPARUK RIVER UNIT ~ WELL SERVICE REPORT ~ Kl(2N-331(W4-6)) WELL JOB SCOPE JOB NUMBER 2N-331 PERFORATE, PERF SUPPORT 0930981839.1 DATE DAILY WORK UNIT NUMBER 11/30/98 PERF DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 12 YES YES SWS-JOHNSON KRALICK FIELD AFC# CC# Signed ESTIMATE K85105 180KNU2TN Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann Final Outer Ann 200 PSI 200 PSI 100 PSI 100 PSII 250 PSI 250 PSI DAILY SUMMARY I PERF USING 2.5" HC/DP/6 SPF/60 DEGREE PHASED GUNS @ 10,715' - 10,752' (37') - PERFORATIONS COMPLETE[Perf] TIME LOG ENTRY 07:30 MIRU SWS 08:30 P/T BOP AND LUB TO 3000 PSI - TGSM - WORKING CLOSELY WITH HALLIBURTON NEXT DOOR 08:35 RIH W/2.5" HC/DP/6 SPF/60 DEGREE PHASED GUNS TO PERF @ 10,752'- 10,732' (20') -TIE IN AND SHOOT - POOH - ALL SHOTS FIRED 11:00 RIH W/SAME TO PERF @ 10,732' - 10,715' (17') - TIE IN AND SHOOT - POOH - ALL SHOTS FIRED 14:00 RDMO SWS SURVEY CALCULATIONAND FIELD WORKSHEET Job No. 0451-00349 Sidetrack No. Page 1 of 6 I Company ARCO ALASKA, INC. Rig Contractor & No. DOYON DRILLING CO. - #141 Field TARN DEVELOPMENT FIELD Well Name & No. TARN DRILLSITE 2N/331 Survey Section Name Definitive Survey BHI Rep. KIRT CHRISTENSEN ~lllrr~l~ WELL DATA Target TVD (FT) Target Coord, N/S Slot Coord. N/S -94,81 Grid Correction 0,000 Depths Measured From: RKB ~ MSLD SS~ Target Description Target Coord. E/W Slot Coord, EjW -909,01 Magn. Declination 26,830 Calculation Method MINIMUM CURVATURE Target Direction (DD) Buil~Walk\DL per: 100ft[~ 30mD 10m0 Vert, Sec. Azim. 273.01 Magn. to Map Corr, 26.830 Map North to: OTHER SURVEY DATA Survey Survey Incl, Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (FT) (FT) (FT) (F'r) (Per 100 F-r)Drop (-) Left (-) 0,00 0,00 0,00 0,00 0.00 0,00 0.00 TIE IN POINT 31 -AUG-98 MWD 108.00 0,00 0.00 108,00 108.00 0,00 0,00 0,00 0,00 0.00 8" M1C 1,4 DEG AKO 31 -AUG-98 MWD 192,93 0.24 355,04 84,93 192,93 0.02 0,18 -0.02 0.28 0.28 31-AUG-98 MWD 279,93 0.84 303.46 87.00 279,93 0,60 0,71 -0.56 0,82 0.69 31 -AUG-98 MWD 370,81 3.68 293,46 90,88 370,73 3,91 2,24 -3,80 3,14 3,12 31 -AUG-98 MWD 465,58 6,30 293.33 94,77 465.13 11.63 5,51 -11,36 2.76 2.76 -0,14 31-AUG-98 MWD 554,33 8.85 294,61 88,75 553,10 22.55 10,28 -22,04 2,88 2.87 1.44 31 -AUG-98 MWD 637,59 12.52 294,43 83,26 634,90 36.91 16,68 -36,09 4,41 4,41 -0.22 31 -AUG-98 MWD 729,30 17,28 291,29 91,71 723,50 59.11 25.75 -57,84 5,26 5,19 -3.42 31 -AUG-98 MWD 820,36 21.30 286,54 91,06 809.44 88.05 35.37 -86,31 4,74 4,41 -5,22 31 -ALIG-98 MWD 912.18 24,39 281,76 91,82 894,05 123.01 43,98 -120,87 3,92 3.37 -5.21 31 -AUG-98 MWD 999,59 27,73 280,53 87,41 972.56 161,02 51,38 -158,54 3,87 3,82 -1,41 31 -AUG-98 MWD 1089,19 32,34 280,54 89,60 1050.11 205,47 59,58 -202,62 5.15 5,15 0,01 31 -AUG-98 MWD 1178,98 36,20 279,12 89.79 1124.30 255,66 68.18 -252,43 4,39 4.30 -1,58 31 -AUG-98 MWD 1271,72 40,14 278,04 92,74 1197,20 312,69 76,70 -309,09 4,31 4,25 -1,16 31 -AUG-98 MWD 1365,91 43,99 276,34 94,19 1267,11 375.62 84,56 -371.69 4.26 4,09 -1,80 31 -AUG-98 MWD 1459,26 47,57 275,43 93.35 1332,21 442,42 91,41 -438,23 3.90 3,84 -0,97 31 -AUG-98 MWD 1554,08 51,01 276,44 94,82 1394,04 514.19 98.85 -509.70 3,72 3.63 1,07 31 -AUG-98 MWD 1648,45 54,11 274,82 94,37 1451,41 589,03 106,18 -584,26 3,56 3,28 -1,72 31 -AUG-98 MWD 1742,75 57,74 273,84 94,30 1504,23 667,10 112.06 -662.13 3,94 3.85 -1,04 31 -AUG-98 MWD 1837.34 61.1 5 272.34 94.59 1552,32 748.54 116.43 -743,46 3.85 3,61 -1,59 31 -AUG-98 MWD 1931,42 64.48 271,91 94,08 1595.29 832.21 119,53 -827.07 3.56 3.54 -0.46 31 -AUG-98 MWD 2025.92 67.51 269,02 94,50 1633,74 918,43 120,21 -913,38 4,25 3,21 -3,06 31-AUG-98 MWD 2119.27 67,97 270,10 93,35 . 1669,10 1004,66 119,54 -999.76 1.18 0.49 1.16 i, r SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0451-00349 Sidetrack No. Page 2 of 6 · "_ [1[~-] =-I:~-'~ Company ARCO ALASKA, INC. Rig Contractor & No. DOYON DRILLING CO. - #141 Field TARN DEVELOPMENT FIELD I~=~=~l~m~ Well Name & No. TARN DRILLSITE 2N/331 Survey Section Name Definitive Survey BHI Rep. KIRT CHRISTENSEN WELL DATA Target TVD (F'r) Target Coord. N/S Slot Coord. N/S -94.81 Grid Correction 0.000 Depths Measured From: RKB ~ MSL~ SS~- Target Description Target Coord. E/W Slot Coord. E/W -909.01 Magn. Declination 26.830 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build~Walk\DL per: lOOft[~ 30mE] 1OmO Vert. Sec. Azim. 273.01 Magn. to Map Corr. 26.830 Map North to: OTHER SURVEY DATA Survey survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) /S(-) E(+) /W(-) DL Build (+) Right (+) Comment Type (F'r) (DD) (DD) (FT) (FT) (FT) (FT) (Per lO0 FT):Drop (-) Left (-) 31-AUG-98 MWD 2212.80 68.10 269.97 93.53 1704.09 1091.29 119.60 -1086.50 0.19 0.14 -0.14 31 -AUG-98 MWD 2307.46 68,40 267.57 94,66 1739,17 1178,96 117.71 -1174.40 2,38 0,32 -2.54 31 -AUG-98 MWD 2406.34 68.91 268.94 98.88 1775.16 1270,74 114.91 -1266.45 1,39 0,52 1,39 ,_ 01 -SEP-98 MWD 2496,58 69.04 270,61 90,24 1807,54 1354,83 114,58 -1350,68 1,73 0.14 1.85 01-SEP-98 MWD 2591,46 67.90 272.10 94.88 1842.36 1443.05 116,66 -1438,91 1,89 -1,20 1.57 .. 01 -SEP-98 MWD 2687,15 67,79 272,62 95,69 1878,44 1531,67 120,31 -1527,46 0,52 -0,11 0,54 01 -$EP-98 MWD 2778,61 68,05 271.32 91.46 1912.82 1616.40 123.22 -1612.16 1,35 0.28 -1,42 01 -SEP-98 MWD 2872,64 68,48 271,71 94,03 1947,65 1703,72 125,53 -1699,47 0,60 0,46 0.41 01 -SEP-98 MWD 2967,11 69.04 271,43 94,47 1981.87 1791.74 127.94 -1787,49 0,65 0.59 -0,30 01 -SEP-98 MWD 3062,91 68,37 273,19 95,80 2016,66 1880,99 131,54 -1876,67 1,85 -0,70 1,84 01 -SEP-98 MWD 3156,90 68,74 272.06 93.99 2051,03 1968.47 135,54 -1964,06 1,19 0,39 -1,20 01 -SEP-98 MWD 3251,74 66,87 273,34 94,84 2086,85 2056,27 139,67 -2051,77 2,33 -1,97 1,35 01 -SEP-98 MWD 3345,64 66,75 271,20 93,90 2123,83 2142,57 143.09 -2138,01 2,10 -0,13 -2,28 01-SEP-98 MWD 3439,06 67,46 273,08 93,42 2160,18 2228,62 146,31 -2224,00 2,00 0,76 2,01 '~. 01 -SEP-98 MWD 3534,80 67,93 272,61 95,74 2196,52 2317,19 150.70 -2312,47 0.67 0,49 -0,49 01 -SEP-98 MWD 3628,13 68.43 273,80 93,33 2231.21 2403,83 155,55 -2398,98 1,30 0.54 1,28 01 -SEP-98 MWD 3716,82 68,45 272,66 88,69 2263,80 2486,32 160,20 -2481.33 1,20 0.02 -1,29 01-SEP-98 MWD ' 3738,34 68.39 273.69 21,52 2271,72 2506,33 161,30 -2501,31 ' 4,46 -0,28 4,79 05-SEP-98 MWD 3859,43 69,00 274,29 121,09 2315,71 2619,12 169,15 -2613.85 0.68 0,50 0,50 4 3/4" M1/XL 1.2 Deg AKO 05-SEP-98 MWD 3952.51 69,49 273.52 93.08 2348,70 2706,15 175,08 -2700.68 0,94 0,53 -0,83 05-SEp-98 MWD 4046,20 70,06 271,94 93,69 2381,09 2794.06 179,27 -2788,49 1,70 0.61 -1,69 05-SEP-98 MWD 4141.07 69,04 273.81 94.87 2414.24 2882,94 183.72 -2877,27 2,i 4 -1,08 1,97 05-SEP-98 MWD 4234,48 68.36 274,17 93.41 2448.17 2969,96 189,77 -2964,09 0,81 -0.73 0.39 05-SEP-98 MWD 4328.09 69.45 273.87 93.61 2481,86 3057,28 195,90 -3051.21 1,20 1.16 -0.32 SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0451-00349 Sidetrack No, Page 3 of 6 t Company ARCO ALASKA, INC. Rig Contractor & No, DOYON DRILLING CO. - #141 Field TARN DEVELOPMENT FIELD Well Name & No, TARN DRILLSITE 2N/331 Survey Section Name Definitive Survey BHI Rep. KIRT CHRISTENSEN j~j~"r~4~ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -94.81 Grid Correction 0.000 Depths Measured From: RKB ~ MSL[~ ssr~ Target Description Target Coord. E/W Slot Coord. E/W -909.01 Magn. Declination 26.830 Calculation Method MINIMUM CURVATURE Target Direction (DD) Buil~Walk\DL per: lOOft~ 30m~ lOm~ Vert. Sec. Azim, 273.01 Magn. to Map Corr. 26,830 Map North to: OTHER SURVEY DATA Survey Survey Incl, Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (F'r) (DD) (DD) (F'r) (FT) (FT) (FT) (Per 400 F~ Drop (-) Left (-) 05-SEP-98 MWD 4423.38 68.59 273.78 95.29 2515.98 3146.25 201.83 -3139.98 0.91 -0.90 -0.09 05-SEP-98 MWD 4518.81 67.12 274.47 95.43 2551.95 3234.62 208.19 -3228.14 1.68 -1.54 0.72 05-SEP-98 MWD 4614.16 67.39 275.71 95.35 2588.82 3322.49 215.99 -3315.72 1.23 0.28 1.30 __. 05-SEP-98 MWD 4705.38 67.61 276.08 91.22 2623.72 3406.66 224.64 -3399.55 0.45 0.24 0.41 06-SEP-98 MWD 4805.49 67.79 274.70 100.11 2661.71 3499.20 233.34 -3491.76 1.29 0.18 -1.38 06-SEP-98 MWD 4899.21 68.72 275.67 93.72 2696.43 3586.19 241.21 -3578.46 1.38 0.99 1.03 06-SEP-98 MWD 4995.54 67.99 273.02 96.33 2731.97 3675.69 248.00 -3667.73 2.67 -0.76 -2.75 06-SEP-98 MWD 5090.36 68.21 271.32 94.82 2767.34 3763.65 251.33 -3755.64 1.68 0.23 -1.79 06-SEP-98 MWD 5183.13 69.13 273.04 92.77 2801.09 3850.05 254.62 -3841.98 1.99 0.99 1.85 06-SEP-98 MWD 5277.68 67.66 271.25 94.55 2835.90 3937.94 257.92 -3929.82 2.35 -1.55 -1.89 06-sEP-98 MWD 5372.37 67.48 269.12 94.69 2872.03 4025.36 258.20 -4017.34 2.09 -0.19 -2.25 06-SEP-98 MWD 5468.29 68.04 269.19 95.92 2908.34 4113.94 256.89 -4106.12 0.59 0.58 0.07 06-SEP-98 MWD 5560.79 68.45 268.74 92.50 2942.62 4199.64 255.34 -4192.01 0.63 0.44 -0.49 -- 06-SEP-98 MWD 5654.28 69.01 269.02 93.49 2976.54 4286.53 253.64 -4279.12 0.66 0.60 0.30 ,~ 06-SEP-98 MWD 5750.07 68.88 268.43 95.79 3010.95 4375.68 251.65 -4368.49 0.59 -0.14 -0.62 06-SEP-98 MWD 5842.68 69.44 269.26 92.61 3043.90 4462.00 249.91 -4455.02 1.03 0.60 0.90 06-SEP-98 MWD 5934.09 69.03 270.52 91.41 3076.31 4547.34 249.74 -4540.49 1.36 -0.45 1.38 06-S EP-98 MWD 6028.53 67.91 269.77 94.44 3110.97 4635.08 249.96 -4628.34 1.40 -1.19 -0.79 06-SEP-98 MWD 6123.14 68.67 271.14 94.61 3145.96 4722.89 250.67 -4716.23 1.57 0.80 1.45 06-SEP-98 MWD 6206.75 68.00 270.39 83.61 3176.83 4800.53 251.70 -4793.93 1.16 -0.80 -0.90 06-SEP-98 MWD 6310.50 66.31 271.35 103.75 3217.11 4896.07 253.15 -4889.52 1.84 -1.63 0.93 06-SEP-98 MWD 6404.44 66.70 271.19 93.94 3254.56 4982.18 255.06 -4975.65 0.44 0.42 -0.17 07-SEP-98 MWD 6495.94 67.54 270.80 91.50 3290.14 5066.43 256.52 -5059.94 1.00 0.92 -0.43 07-S EP-98 MWD 6591.69 66.55 272.90 95.75 3327.48 5154.57 259.36 -5148.06 2.27 -1.03 2.19 SURVEY CALCULATION AND FIELD WORKSHEET Jot)No. 0451-00349 Sidetrack No. Page 4 of 6 I Company ARCO ALASKA, INC. Rig Contractor & No. DOYON DRILLING CO. - #141 Field TARN DEVELOPMENT FIELD Well Name & No. TARN DRILLSITE 2N/331 Survey Section Name Definitive Survey BHI Rep. KIRT CHRISTENSEN J~l~r~~ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -94.81 Grid Correction 0.000 Depths Measured From: RKB ~] MSL[-] SSD Target Description Target Coord. E/W Slot Coord. E/W -909.01 Magn. Declination 26.830 Calculation Method MINIMUM CURVATURE Target Direction (DD) Buil~Walk\DL per: 100ftC[ 30m~ 10mo Vert. Sec. Azim. 273.01 Magn. to Map Corr. 26.830 Map North to: OTHER · SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (F'r) (DD) (DD) (FT) (FT) (FT) (FT) (Per 100 FT) Drop (-) Left (-) 07-SEP-98 MWD 6686.19 66.01 275,67 94.50 3365.50 5241.06 265.82 -5234.32 2.74 -0.57 2.93 ,' -- 07-SEP-98 MWD 6781.77 66.12 272.04 95.58 3404.29 5328.39 271.69 -5321.46 3.47 0.12 -3.80 07-SEP-98 MWD 6875.18 66.57 273.13 93.41 3441.77 5413.95 275.55 -5406.94 1.17 0.48 1.17 07-SEP-98 MWD 6968.15 66.94 273.46 92.97 3478.46 5499.37 280.46 -5492.22 0.51 0.40 0.35 07-SEP-98 MWD 7063.94 67.63 273.46 95.79 3515.45 5587.72 285.80 -5580.42 0.72 0.72 0.00 07-SEP-98 MWD 7155.95 67.68 272.07 92.01 3550.43 5672.82 289.90 -5665.42 1.40 0.05 -1.51 07-SEP-98 MWD 7251.85 68.11 272.22 95.90 3586.52 5761.66 293.23 -5754.20 0.47 0.45 0.16 07-SEP-98 MWD 7346.33 68.45 271.66 94.48 3621.49 5849.42 296.20 -5841.93 0.66 0.36 -0.59 07-SEP-98 MWD 7440.47 69.08 271.96 94.14 3655.58 5937.15 298.97 -5929.63 0.73 0.67 0.32 07-SEP-98 MWD 7533.39 67.29 273.27 92.92 3690.11 6023.41 302.90 -6015.80 2.33 -1.93 1.41 07-SEP-98 MWD 7626.11 66.03 273.81 92.72 3726.85 6108.53 308.15 -6100.77 1.46 -1.36 0.58 07-SEP-98 MWD 7717.80 66.12 275.12 91.69 3764.03 6192.31 314.68 -6184.32 1.31 0.10 1.43 07-SEP-98 MWD 7811.02 66.13 274.97 93.22 3801.76 6277.50 322.17 -6269.24 0.15 0.01 -0.16 07-SEP-98 MWD 7906.28 65.99 274.56 95.26 3840.42 6364.53 329.41 -6356.00 0.42 -0.15 -0.43 07-SEP-98 MWD 8001.07 66.11 275.10 94.79 3878.90 6451.11 336.70 -6442.32 0.54 0.13 0.57 07-SEP-98 MWD 8095.13 66.74 275.33 94.06 3916.52 6537.26 344.54 -6528.17 0.71 0.67 0.24 07-SEP-98 MWD 8189.34 67.40 275.94 94.21 3953.22 6623.93 353.06 -6614.52 0.92 0.70 0.65 ,, 07-sEp-98 MWD ' 8283.27 68.05 275.58 93.93' 3988.82 6710.75 361.78 -6701.00' 0.78 0.69 -0.38 07-SEP-98 MWD 8377.79 68.45 274.36 94.52 4023.85 6798.49 369.38 -6788.46 1.27 0.42 -1.29 08,SEP-98 MWD 8477.99 68.48 275.16 100.20 4060.63 6891.65 377.12 ~6881.34 0.74 0.03 0.80 08-SEP-98 MWD 8566.68 69.07 273.99 88.69 4092.74 6974.29 383.71 -6963.75 1.40 0.67 -1.32 08-SEP-98 MWD 8663.37 69.98 274.34. 96.69 4126.56 7064.85 390.29 -7054.09 1.00 0.94 0.36 08-SEP'98 MWD 8757.01 70.74 274.69 93.64 4158.04 7153.01 397.23 -7142.01 0.88 0.81 0.37 08-SEP-98 MWD 8853.35 69.21 274.50 96.34 4191.02 7243.49 404.49 -7232.23 1.60 -1.59 -0.20 ii ii =[l[r~'- I Company ARCO ALASKA, INC. Rig Contractor & No. DOYON DRILLING CO. - #141 Field TARN DEVELOPMENT FIELD m~ Well Name & No. TARN DRILLSITE 2N/331 Survey Section Name Definitive Survey BHI Rep. KIRT CHRISTENSEN WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -94.81 Grid Correction 0.000 Depths Measured From: RKB ~ MSL ~ SSD Target Description Target Coord. F_JW Slot Coord. E/W -909.01 Magn. Declination 26.830 Calculation Method MINIMUM CURVATURE Target Direction (DD) Buil~Walk\DL per: lOOft~ 30m~ lOm~ Vert. Sec. Azim. 273.01 Magn. to Map Corr. 26.830 Map North to: OTHER i SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) /S(-) E(+) /W(-) DL Build (+) Right (+) Comment Type (Fr) (DD) (DO) (FT) (FT) (FT) (FT) (Per lO0 F~3 Drop (-) Left (-) 08-SEP-98 MWD 8944.65 69.09 272.63 91.30 4223.52 7328.80 409.79 -7317.38 1.92 -0.13 -2.05 08-SEP-98 MWD 9040.31 70.03 272.43 95.66 4256.93 7418.44 413.75 -7406.93 1.00 0.98 -0.21 ~ 08-SEP-98 MWD 9138.94 69.22 271.64 98.63 4291.27 7510.88 417.03 -7499.33 1.11 -0.82 -0.80 08-SEP-98 MWD 9230.71 69.01 272.38 91.77 4323.99 7596.61 420.04 -7585.02 0.79 -0.23 0.81 08-SEP-98 MWD 9322.00 70.26 271.84 91.29 4355.75 7682.18 423.19 -7670.54 1.48 1.37 -0.59 08-SEP-98 MWD 9417.32 69.10 271.64 95.32 4388.85 7771.54 425.90 -7759.89 1.23 -1.22 -0.21 08-SEP-98 MWD 9506.45 68.34 271.45 89.13 4421.20 7854.57 428.14 -7842.91 0.88 -0.85 -0.21 08-SEP-98 MWD 9603.93 68.86 272.05 97.48 4456.77 7945.31 430.92 -7933.62 0.78 0.53 0.62 08-SEP-98 MWD 9696.17 69.23 271.00 92.24 4489.76 8031.41 433.21 -8019.73 1.14 0.40 -1.14 09-SEP-98 MWD 9789.89 68.51 271.1 9 93.72 4523.54 8118.78 434.88 -8107.13 0.79 -0.77 0.20 09-SEP-98 MWD 9888.64 65.45 272.34 98.75 4562.16 8209.63 437.67 -8197.96 3.28 -3.10 1.16 09-SEP-98 MWD 9980.91 65.87 271.36 92.27 4600.19 8293.69 440.38 -8281.99 1.07 0.46 -1.06 09-SEP-98 MWD 10076.27 64.32 271.85 95.36 4640.34 8380.15 442.80 -8368.44 1.69 -1.63 0.51 09-SEP-98 MWD 10172.46 61.75 270.78 96.19 4683.96 8465.83 444.77 -8454.14 2.85 -2.67 -1.11 "~ 09-SEP-98 MWD 10267.26 59.13 269.13 94.80 4730.72 8548.17 444.72 -8536.59 3.15 -2.76 -1.74 09-SEP-98 MWD 10360.59 57.41 272.01 93.33 4779.81 8627.46 445.50 -8615.95 3.21 -1.84 3.09 09-SEP-98 MWD 10451.61 55.41 272.61 91.02 4830.17 8703.27 448.55 -8691.71 2.26 -2.20 0.66 09-SEP-98 MWD 10544.85 54.77 272.47 93.24 4883.53 8779.73 451.94 -8768.09 0.70 -0.69 -0.15 09-SEP-98 MWD 10642.69 55.18 273.58 97.84 4939.68 8859.85 456.1.7 -8848.10 1.02 0.42 1.13 09-SEP-98 MWD 10733.40 56.06 271.26 90.71 4990.91 8934.70 459.32 -8922.89 2.32 0.97 -2.56 09-SEP-98 MWD 10829.56 55.98 272.91 96.16 5044.65 9014.42 462.22 -9002.57 1.43 -0.08 1.72 09-SEP-98 MWD 10920.86 55.65 270.72 91.30 5095.96 9089.92 464.61 -9078.05 2.02 -0.36 -2.40 09-SEP-98 MWD 11016.21 55.87 271.27 95.35 5149.61 9168.70 465.98 -9156.86 0.53 0123 0.58 09-SEP~98 MWD 11110.18 56.94 271.76 93.97 5201.60 9246.95 468.05 -9235.11 1.22 1.1 4 0.52 ~' " SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0451-00349 Sidetrack No, Page 6 of 6 Company ARCO AI_~SK~, INC. Rig Contra~or & No. DO¥ON DRIll_lNG CO. - #141 Field TARN DI~/F:IOPMENT FIELD Well Name & No, TARN DRILLSITE 2N/331 Survey Section Name Definitive Survey BHI Rep, KIRT CHRISTENSEN ~llrr~l~ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -94.81 Grid Correction 0.000 Depths Measured From: RKB ~ MSL ~ SS~- Target Description Target Coord. F_JW Slot Coord. EJW -909.01 Magn. Declination 26.830 Calculation Method MINIMUM CURVATURE Target Direction (OD) Buil~Walk\DL per: lOOft[~ 30mD lOm~ Vert. Sec. Azim. 273.01 Magn. to Map Corr. 26.830 Map North to: OTHER · SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) /S(-) E(+) /W(-) DL Build (+) Right (+) Comment Type (F~ (OD) (OD) (F~ (FT) (FT) (F'r) (Per 100 F'r)Drop (-) Left (-) 09-SEP-98 MWD 11131,48 57,01 271.03 21,30 5213.21 9264,80 468,49 -9252,96 2,89 . 0,33 -3,43 , 09-SEP-98 MWD 11225,00 57,01 271,03 93,52 5264,13 9343,19 469,90 -9331,39 0,00 0.00 0,00 Projected Data - NO SURVEY , ORI61NAL RECEIVED ARCO ALASKA INC. DRILLSITE 2N, WELL NO. 2N-331 TARN POOL , ALASKA D[C O7 1998 Alaska Oil & Gas Cons. CornmisSjO~ Gyro Continuous Multishot Survey Inside 3.5" TUBING Survey date' 05-OCTOBER, 1998 Job number' AK1098GCE499 CONTENTS JOB NUMBER' AK1098GCE499 1. DISCUSSION , SURVEY CERTIFICATION SHEET 2. SURVEY DETAILS 3. OUTRUN SURVEY LISTING 4. QUALITY CONTROL 5. EQUIPMENT AND CHRONOLOGICAL REPORT SURVEY CERTIFICATION SHEET JOB NUMBER · AK1098GCE499 The data for this survey and the calculations for this survey were obtained and performed by me according to standards and procedures as set forth by Gyrodata Limited, true and correct to the best of my knowledge. TOM STODDARD OPERATIONS ENGINEER The data and calculations for this survey have been checked by me and conform to the standards and procedures as set forth by Gyrodata Limited. This report represents a directional survey of this well based on the original data obtained at the wellsite. Checked by :- JACK E. MAY OPERATIONS MANAGER 2. SURVEY DETAILS SURVEY DETAILS JOB NUMBER: AK1098GCE499 CLIENT: ARCO ALASKA INC. RIG: SCHLUMBERGER LOCATION: DRILLSITE 2N WELL: 2N-331 LATITUDE: 70.25 N LONGITUDE: SURVEY DATE: 150.0 W 05 -oCTOBER, 1998 SURVEY TYPE : GYRO CONTINUOUS MULTISHOT DEPTH REFERENCE: ROTARY TABLE ELEVATION 147.3 MAX. SURVEY DEPTH: 10850' SURVEY TIED ONTO: N/A SURVEY INTERVAL: 0-10850' APl NUMBER: TARGET DIRECTION: 050-103-20265-00 273.01 GRID CORRECTION: N/A CALCULATION METHOD: MINIMUM CURVATURE SURVEYOR: TOM STODDARD 3. OUTRUN SURVEY LISTING A Gyro da t a D i re c t i ona i Survey for ARCO ALASKA INC. WELL: 2N-331, 3.5" Location: DRILLSITE 2N, TARN POOL, ALASKA Job Number: AK1098GCE499 Run Date: 5-Oct-98 10:30:00 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.250000 deg. N Sub-sea Correction from Vertical Reference: 147.3 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 273.010 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyro da t a D i r e c t i ona i Survey %RCO ALASKA INC. dELL: 2N-331, 3.5" Location: DRILLSITE 2N, lob Number: AK1098GCE499 ~EASURED I N C L AZIMUTH DEPTH feet deg. deg. 1600.0 52.45 275.77 1650.0 54.32 274.89 1700.0 55.83 274.31 1750.0 58.27 272.88 1800.0 59.60 272.31 1850.0 61.97 270.95 1900.0 63.20 270.44 1950.0 65.10 269.31 2000.0 66.51 268.71 2050.0 67.65 268.24 2100.0 67.95 268.14 2150.0 68.11 268.24 2200.0 68.24 268.25 2250.0 68.17 268.30 2300.0 68.51 268.44 2350.0 68.58 268.57 2400.0 68.87 268.78 2450.0 69.05 268.95 2500.0 69.05 269.11 2550.0 69.57 269.34 2600.0 67.49 271.22 2650.0 67.75 271.62 2700.0 67.69 271.66 2750.0 67.75 271.50 2800.0 68.39 271.54 TARN POOL, ALASKA DOGLEG VERTICAL SUBSEA VERTICAL SEVERITY DEPTH DEPTH SECTION deg./ feet feet feet 100 ft. 2.82 1421.5 1274.2 552.8 4.01 1451.3 1304.0 592.9 3.17 1479.9 1332.6 633.9 5.43 1507.1 1359.8 675.8 2.85 1532.9 1385.6 718.7 5.29 1557.3 1410.0 762.3 2.62 1580.4 1433.1 806.6 4.31 1602.2 1454.9 851.6 3.04 1622.7 1475.4 897.1 2.43 1642.1 1494.8 943.0 .63 1661.0 1513.7 989.1 .37 1679.7 1532.4 1035.3 .27 1698.3 1551.0 1081.6 .17 1716.9 1569.6 1127.8 .73 1735.3 1588.0 1174.1 CLOSURE DIST. AZIMUTH feet deg. 558.2 281.0 598.1 280.6 638.9 280.2 680.6 279.8 723.1 279.4 Page 766.4 278.9 810.3 278.5 854.8 278.0 899.9 277.6 945.4 277.1 HORIZONTAL COORDINATES feet 991.2 276.7 1037.1 276.3 1083 .0 276.0 1129.1 275.7 1175.2 275.4 .29 1753.6 1606.3 1220.5 1221.4 275.1 .~8 1771.8 1624.5 1267.0 1267.7 274.9 .49 1789.7 1642.4 1313.5 1314.1 274.7 .30 1807.6 1660.3 1360.1 1360.6 274.5 1.12 1825.3 1678.0 1406.8 1407.2 274.3 5.42 1843.6 1696.3 1453.3 1453.6 274.2 .91 1862.6 1715.3 1499.5 1499.8 274.1 .13 1881.6 1734.3 1545.7 1546.0 274.0 .31 1900.5 1753.2 1592.0 1592.2 274.0 1.28 1919.2 1771.9 1638.4 1638.5 273.9 106.2 N 548.0 W 109.9 N 588.0 W 113.2 N 628.8 W 115.8 N 670.7 W 117.8 N 713.5 W 119.0 N 757.1 W 119.5 N 801.5 W 119.4 N 846.5 W 118.7 N 892.1 W 117.4 N 938.1 W 116.0 N 984.4 W 114.5 N 1030.7 W 113.1 N 1077.1 W 111.7 N 1123.5 W l10.4~N 1170.0 W 109.2 N 1216.5 W 108.1 N 1263.1 W 107.2 N 1309.7 W 106.4 N 1356.4 W 105.7 N 1403.2 W 106.0 N 1449.7 W 107.1 N 1495.9 W 108.4 N 1542.2 W 109.7 N 1588.4 W 110.9 N 1634.8 W A Gyro da t a D i r e c t i ona i Survey ARCO ALASKA INC. WELL: 2N-331, 3.5" Location: DRILLSITE 2N, Job Number: AK1098GCE499 TARN POOL, ALASKA Page MEASURED I N C L AZIMUTH DEPTH feet deg. deg. DOGLEG VERTICAL SUBSEA VERTICAL CLOSURE SEVERITY DEPTH DEPTH SECTION DIST. AZIMUTH deg./ feet feet feet feet deg. 100 ft. HORIZONTAL COORDINATES feet 4100.0 70.32 272.89 4150.0 68.65 273.61 4200.0 68.22 273.96 4250.0 68.43 273.92 4300.0 69.24 273.97 .26 2396.1 2248..8 2847.4 2847.6 273.6 3.60 2413.6 2266.3 2894.3 2894.4 273.6 1.09 2432.0 2284.7 2940.8 2940.9 273.6 .44 2450.4 2303.1 2987.2 2987.4 273.6 1.62 2468.5 2321.2 3033.8 3034.0 273.6 178.8 N 2842.0 W 181.5 N 2888.7 W 184.5 N 2935.1 W 187.7 N 2981.5 W 190.9 N 3028.0 W 4350.0 69.53 273.87 4400.0 69.54 274.28 4450.0 67.35 275.65 4500.0 67.27 275.74 4550.0 67.38 275.74 .61 2486.1 2338.8 3080.6 3080.8 273.6 .77 2503.6 2356.3 3127.5 3127.6 273.6 .06 2521.9 2374.6 3173.9 3174.1 273.6 .23 2541.2 2393.9 3220.0 3220.2 273.7 .23 2560.5 2413.2 3266.1 3266.3 273.7 194.1 N 3074.7 W 197.5 N 3121.4 W 201.5 N 3167.7 W 206.1 N 3213.6 W 210.7 N 3259.5 W 4600.0 67.22 275.71 4650.0 67.61 275.81 4700.0 67.56 275.79 4750.0 67.84 275.84 4800.0 68.10 275.89 .32 2579.8 2432.5 3312.2 3312.4 273.7 .78 2599.0 2451.7 3358.3 3358.6 273.8 .09 2618.1 2470.8 3404.5 3404.8 273.8 .57 2637.0 2489.7 3450.7 3451.0 273.8 .53 2655.8 2508.5 3497.0 3497.3 273.8 215.3 N 3305.4 W 219.9 N 3351.4 W 224.6 N 3397.3 W 229.3 N 3443.4 W 234.0~N 3489.5 W 4850.0 68.23 275.79 4900.0 68.89 275.68 4950.0 69.47 275.55 5000.0 68.08 273.47 5050.0 67.99 272.78 .33 2674.4 2527.1 3543.3 3543.7 273.9 1.~3 2692.7 2545.4 3589.8 3590.2 273.9 1.20 2710.4 2563.1 3636.5 3636.9 273.9 4.78 2728.5 2581.2 3683.1 3683.5 273.9 1.29 2747.2 2599.9 3729.4 3729.9 273.9 238.7 N 3535.7 W 243.4 N 3582.0 W 248.0 N 3628.5 W 251.6 N 3674.~9 W 254.2 N 3721.2 W 5100.0 68.43 272.77 5150.0 69.01 272.72 5200.0 69.08 272.74 5250.0 68.93 272.26 5300.0 67.39 270.23 .87 2765.8 2618.5 3775.9 3776.3 273.9 1.16 2783.9 2636.6 3822.5 3822.9 273.9 · 14 2801.8 2654.5 3869.2 3869.6 273.9 · 95 2819.7 2672.4 3915.8 3916.3 273.8 4.86 2838.3 2691.0 3962.2 3962.6 273.8 256.4 N 3767.6 W 258.6 N 3814.1 W 260.9 N 3860.8 W 262.9 N 3907.4 W 263.9 N 3953.8 W A Gyro da t a D i r e c t i ona i Survey ARCO ALASKA INC. WELL: 2N-331, 3.5" Location: DRILLSITE 2N, Job Number: AK1098GCE499 TARN POOL, ALASKA Page MEASURED I N C L AZIMUTH DEPTH feet deg. deg. DOGLEG VERTICAL SUBSEA VERTICAL SEVERITY DEPTH DEPTH SECTION deg./ feet feet feet 100 ft. CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet 5350.0 67.25 269.89 5400.0 67.77 269.91 5450.0 67.99 269.99 5500.0 68.12 269.92 5550.0 68.61 270.01 .69 2857.6 1.04 2876.8 .48 2895.6 .28 2914.3 .99 2932.7 2710 2729 2748 2767 2785 .3 .5 .3 .0 .4 4008.3 4008.6. 273.8 4054.4 4054.7 273.7 4100.7 4101.0 273.7 4147.0 4147.2 273.6 4193.4 4193.6 273.6 264.0 N 3999.9 W 263.9 N 4046.1 W 263.8 N 4092.5 W 263.8 N 4138.8 W 263.8 N 4185.3 W 5600.0 68.58 270.05 5650.0 68.87 270.00 5700.0 69.22 269.96 5750.0 68.85 269.86 5800.0 69.24 269.87 .O8 .58 .71 .78 .79 2950.9 2969.1 2987.0 3004.9 3022.7 2803 2821 2839 2857 2875 .6 4239.9 4240.1 273.6 · 8 4286.4 4286.6 273.5 .7 4333.0 4333.2 273.5 · 6 4379.7 4379.8 273.5 · 4 4426.3 4426.4 273.4 263.8 N 4231.9 W 263.8 N 4278.5 W 263.8 N 4325.2 W 263.7 N 4371.8 W 263.6 N 4418.5 W 5850.0 69.53 269.85 5900.0 69.58 269.84 5950.0 67.98 270.99 6000.0 67.81 271.26 6050.0 68.05 271.18 59 10 85 61 50 3040.3 3057.8 3075.9 3094.7 3113.5 2893 2910 2928 2947 2966 .0 4473.0 4473.1 273.4 .5 4519.8 4519.9 273.3 .6 4566.4 4566.4 273.3 .4 4612.7 4612.7 273.3 .2 4659.0 4659.0 273.3 263.5 N 4465.3 W 263.4 N 4512.2 W 263.7 N 4558.8 W 264.6 N 4605.1 W 265.6~N 4651.4 W 6100.0 68.40 271.18 6150.0 68.42 271.06 6200.0 68.42 270.80 6250.0 66.01 271.20 6300.0 66.30 271.10 7O 48 87 61 3132.1 3150.5 3168.8 3188.2 3208.4 2984 3003 3021 3040 3061 .8 4705.4 4705.4 273.2 .2 4751.8 4751.9 273.2 .5 4798.3 4798.3 273.2 .9 4844.4 4844.4 273.2 .1 4890.1 4890.1 273.2 266.6 N 4697.9 W 267.5 N 4744.3 W 268.2 N 4790.8 W 269.0 N 4836.9 W 270.0 N 4882.6 W 6350.0 66.46 271.05 6400.0 66.47 271.11 6450.0 67.00 271.08 6500.0 67.25 271.07 6550.0 67.79 271.19 33 12 O7 49 11 3228.5 3248.4 3268.2 3287.6 3~06.7 3081 3101 3120 3140 3159 .2 4935.9 4935.9 273.1 .1 4981.7 4981.7 273.1 .9 5027.6 5027.6 273.1 .3 5073.6 5073.6 273.1 .4 5119.8 5119.8 273.1 270.8 N 4928.4 W 271.7 N 4974.3 W 272.6 N 5020.2 W 273.4 N 5066.3 W 274.3 N 5112.4 W A Gyro da t a D i r e c t i ona i Survey ARCO ALASKA INC. WELL: 2N-331, 3.5" Location: DRILLSITE 2N, Job Number: AK1098GCE499 MEASURED I N C L AZIMUTH DEPTH feet deg. deg. TARN POOL, ALASKA DOGLEG VERTICAL SUBSEA VERTICAL SEVERITY DEPTH DEPTH SECTION deg./ feet feet feet 100 ft. CLOSURE DIST. AZIMUTH feet deg. Page HORIZONTAL COORDINATES feet 6600.0 65.97 273.42 6650.0 65.56 273.96 6700.0 65.98 274.01 6750.0 66.21 273.69 6800.0 66.55 273.55 .48 3326.4 3179.1 5165.8 .28 3346.9 3199.6 5211.4 .86 3367.4 3220.1 5257.0 .74 3387.7 3240.4 5302.7 .72 3407.7 3260.4 5348.5 5165.8 273.1 5211.4 273.1 5257.0 273.1 5302.7 273.1 5348.5 273.1 276.2 N 5158.4 W 279.1 N 5203.9 W 282.3 N 5249.4 W 285.4 N 5295.0 W 288.2 N 5340.7 W 6850.0 66.48 273.47 6900.0 66.80 273.39 6950.0 66.77 273.39 7000.0 67.16 273.23 7050.0 67.70 273.10 .21 3427.6 3280.3 5394.3 .66 3447.5 3300.2 5440.2 .06 3467.2 3319.9 5486.2 .83 3486.7 3339.4 5532.2 .11 3505.9 3358.6 5578.4 5394.3 273.1 5440.2 273.1 5486.2 273.1 5532.2 273.1 5578.4 273.1 291.1 N 5386.5 293.8 N 5432.3 296.5 N 5478.2 299.2 N 5524.1 301.7 N 5570.2 7100.0 67.50 272.82 7150.0 67.76 272.63 7200.0 67.63 272.58 7250.0 68.39 272.49 7300.0 68.32 272.44 .66 3525.0 3377.7 5624.6 .63 3544.0 3396.7 5670.8 .29 3563.0 3415.7 5717.1 .53 3581.7 3434.4 5763.4 .17 3600.2 3452.9 5809.9 5624.6 273.1 5670.8 273.1 5717.1 273.1 5763.4 273.1 5809.9 273.1 304.1 N 5616.4 306.3 N 5662.6 308.4 N 5708.8 310.5 N 5755.1 312.5~'N 5801.5 7350.0 68.37 272.44 7400.0 69.09 272.48 7450.0 69.04 272.53 7500.0 68.95 272.63 7550.0 66.43 274.10 .09 3618.6 3471.3 5856.4 .~6 3636.7 3489.4 5903.0 .15 3654.6 3507.3 5949.7 .25 3672.5 3525.2 5996.3 .72 3691.5 3544.2 6042.6 5856.4 273.1 5903.0 273.1 5949.7 273.1 5996.3 273.1 6042.6 273.1 314.4 N 5847.9 W 316.4 N 5894.5 W 318.5 N 5941.1 W 320.6 N 5987.8' W 323.3 N 6033. 9 W 7600.0 66.12 274..37 7650.0 66.17 274.27 7700.0 65.96 274.45 7750.0 65.97 274.45 7800.0 66.23 274.47 .80 3711.6 3564.3 6088.4 .20 3731.8 3584.5 6134.1 .54 3752.1 3604.8 6179.8 .03 3772.5 3625.2 6225.4 .51 3792.7 3645.4 6271.1 6088.4 273.1 6134.1 273.1 6179.8 273.1 6225.4 273.1 6271.1 273.1 326.7 N 6079.6 W 330.1 N 6125.2 W 333.6 N 6170.8 W 337.1 N 6216.3 W 340.7 N 6261.9 W A Gyro da t a D i r e c t i ona i Survey ARCO ALASKA INC. WELL: 2N-331, 3.5" Location: DRILLSITE 2N, Job Number: AK1098GCE499 TARN POOL, ALASKA Page MEASURED I N C L AZIMUTH DEPTH feet deg. deg. DOGLEG VERTICAL SUBSEA VERTICAL CLOSURE SEVERITY DEPTH DEPTH SECTION DIST. AZIMUTH deg./ feet feet feet feet deg. 100 ft. HORIZONTAL COORDINATES feet 7850.0 65.88 274.65 7900.0 66.21 274.82 7950.0 66.06 274.84 8000.0 65.77 274.97 8050.0 66.34 275.01 .77 3813.0 3665.7 6316.8 6316.8 273.1 .74 3833.3 3686.0 6362.5 6362.5 273.1 .32 3853.6 3706.3 6408.2 6408.2 273.1 .62 3874.0 3726.7 6453.8 6453.8 273.2 .15 3894.3 3747.0 6499.5 6499.5 273.2 344.3 N 6307.4 348.1 N 6353.0 351.9 N 6398.5 355.8 N 6444.0 359.8 N 6489.5 8100.0 66.29 275.10 8150.0 67.13 275.35 8200.0 67.57 275.43 8250.0 67.52 275.47 8300.0 68.34 275.41 .20 3914.3 3767.0 6545.2 6545.3 273.2 363.8 N 6535.1 W .75 3934.1 3786.8 6591.1 6591.1 273.2 368.0 N 6580.9 W .88 3953.4 3806.1 6637.2 6637.3 273.2 372.4 N 6626.8 W .12 3972.5 3825.2 6683.4 6683.4 273.2 376.7 N 6672.8 W .65 3991.3 3844.0 6729.7 6729.7 273.2 381.1 N 6718.9 W 8350.0 68.48 275.20 8400.0 68.58 275.05 8450.0 68.65 274.86 8500.0 68.24 274.64 8550.0 69.19 274.77 .48 4009.7 3862.4 6776.1 6776.2 273.3 385.4 N 6765.2 W .35 4028.0 3880.7 6822.6 6822.7 273.3 389.6 N 6811.6 W .37 4046.2 3898.9 6869.2 6869.2 273.3 393.6 N 6858.0 W .92 4064.6 3917.3 6915.6 6915.7 273.3 397.5 N 6904.3 W .92 4082.7 3935.4 6962.2 6962.3 273.3 401.3~'~N 6950.7 W 8600.0 69.27 274.78 8650.0 69.91 274.62 8700.0 70.44 274.63 8750.0 70.42 274.46 8800.0 71.41 274.52 .16 4100.5 3953.2 7008.9 7009.0 273.3 1.]3 4117.9 3970.6 7055.8 7055.9 273.3 1.06 4134.8 3987.5 7102.8 7102.9 273.3 .33 4151.6 4004.3 7149.9 7150.0 273.3 2.00 4167.9 4020.6 7197.1 7197.3 273.3 405.2 N 6997.3 W 409.0 N 7044.0 W 412.8 N 7090.9 W 416.5 N 7137.9 W 420.2 N 7185.0 W 8850.0 69.74 273.96 8900.0 68.99 273.32 8950.0 69.17 273.24 9000.0 69.74 273.32 9050.0 70.28 273.20 3.52 4184.6 4037.3 7244.3 7244.4 273.4 1.91 4202.2 4054.9 7291.1 7291.2 273.4 .39 4220.0 4072.7 7337.8 7337.9 273.4 1.14 4237.6 4090.3 7384.6 7384.7 273.4 1.12 4254.7 4107.4 7431.6 7431.7 273.4 423.7 N 7232.0 W 426.7 N 7278.7 W 429.4 N 7325.3 W 432.1 N 7372.1 W 434.7 N 7419.0 W A Gyro da t a D i r e c t i ona i Survey ARCO ALASKA INC. WELL: 2N-331, 3.5" Location: DRILLSITE 2N, Job Number: AK1098GCE499 TARN POOL, ALASKA Page MEASURED I N C L AZIMUTH DEPTH feet deg. deg. DOGLEG VERTICAL SUBSEA VERTICAL SEVERITY DEPTH DEPTH SECTION deg./ feet feet feet 100 ft. CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet 9100.0 70.66 273.00 9150.0 69.27 272.16 9200.0 68.58 272.03 9250.0 69.15 271.97 9300.0 69.92 271.98 .84 4271.4 3.20 4288.5 1.40 4306.5 1.14 4324.5 1.53 4342.0 4124 4141 4159 4177 4194 .1 .2 .2 .2 .7 7478.7 7525.7 7572.3 7618.9 7665.8 7478.8 273.4 7525.8 273.3 7572.4 273.3 7619.1 273.3 7665.9 273.3 437.3 N 7466.0 W 439.4 N 7513.0 W 441.1 N 7559.6 W 442.7 N 7606.2 W 444.3 N 7653.0 W 9350.0 70.24 272.09 9400.0 70.78 271.89 9450.0 67.83 271.48 9500.0 68.03 271.31 9550.0 68.67 271.20 .68 4359.0 1.16 4375.7 5.95 4393.4 .53 4412.2 1.29 4430.6 4211 4228 4246 4264 4283 .7 .4 .1 .9 .3 7712 7759 7806 7853 7899 .8 .9 .7 .0 .4 7712.9 273.3 7760.0 273.3 7806.8 273.3 7853.1 273.3 7899.5 273.3 446.0 N 7700.0 W 447.6 N 7747.1 W 449.0 N 7793.8 W 450.1 N 7840.2 W 451.2 N 7886.6 W 9600.0 68.43 271.26 9650.0 69.17 271.15 9700.0 69.11 270.92 9750.0 69.63 270.90 9800.0 68.31 271.19 .50 4448.9 1.50 4467.0 .44 4484.8 1.05 4502.4 2.69 4520.4 4301 4319 4337 4355 4373 .6 .7 .5 .1 .1 7945 7992 8039 8086 8132 .9 .5 .2 .0 .6 7946.0 273.3 7992.6 273.3 8039.3 273.2 8086.0 273.2 8132.7 273.2 452.2 N 7933.1 W 453.1 N 7979.7 W 454.0 N 8026.5 W 454.7 N 8073.3 W 455.6~'N 8119.9 W 9850.0 67.18 271.55 9900.0 65.58 271.19 9950.0 65.37 271.02 10000.0 '65.95 270.95 10050.0 66.00 270.85 2.36 4539.3 3 .25 4559.3 .52 4580.1 1.15 4600.7 .21 4621.1 4392 4412 4432 4453 4473 .0 .0 .8 .4 .8 8178 8224 8270 8315 8361 .9 .7 .1 .7 .3 8178.9 273.2 8224.7 273.2 8270.2 273.2 8315.7 273.2 8361.3 273.2 456.7 N 8166.2 W 457.8 N 8212.0 W 458.7 N 8257.5 W 459.5 N 8303.0 W 460.2 N 8348.7 W 10100.0 63.51 270.47 10150.0 63.37 270.26 10200.0 61.17 269.86 10250.0 61.29 269.86 10300.0 58.77 270.73 5.02 4642.4 .47 4664.7 4.46 4688.0 .25 4712.1 5.27 4737.0 4495.1 4517.4 4540.7 4564.8 4589.7 8406.5 8451.2 8495.4 8539.1 8582.4 8406.5 273.1 8451.2 273.1 8495.4 273.1 8539.1 273.1 8582.4 273.1 460.7 N 8393.9 W 461.0 N 8438.6 W 461.0 N 8482.9 W 460.9 N 8526.7 W 461.1 N 8570.0 W A Gyroda t a D i r e c t i ona i Survey ARCO ALASKA INC. WELL: 2N-331, 3.5" Location: DRILLSITE 2N, Job Number: AK1098GCE499 TARN POOL, ALASKA MEASURED I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. 10350.0 58.64 270.88 .35 10400.0 56.69 271.93 4.29 10450.0 56.11 272.16 1.23 10500.0 54.58 272.52 3.11 10550.0 54.88 272.59 .61 10600.0 55.02 272.66 .31 10650.0 55.33 272.63 .62 10700.0 55.85 272.55 1.05 10750.0 56.19 272.53 .68 10800.0 56.21 272.56 .07 10850.0 55.96 272.65 .52 Station Closure: Final Page VERTICAL SUBSEA VERTICAL DEPTH DEPTH SECTION feet feet feet 4763.0 4615 4789.7 4642 4817.4 4670 4845.9 4698 4874.7 4727 4903.4 4756 4932.0 4784 4960.3 4813 4988.2 4840 5016.0 4868 5043.9 896 CLOSURE DIST. AZIMUTH feet deg. .7 8625.1 8625.1 273.1 .4 8667.3 8667.3 273.1 .1 8708.9 8708.9 273.1 .6 8750.1 8750.1 273.1 .4 8790.9 8790.9 273.1 .1 8831.8 8831.8 273.0 .7 8872.9 8872.9 273.0 .0 8914.1 8914.1 273.0 .9 8955.6 8955.6 273.0 .7 8997.1 8997.1 273.0 9038.6 .6 Distance: 9038.61 ft Az: 9038.6 273.0 273.04 deg. HORIZONTAL COORDINATES feet 461.7 N 8612.7 W 462.8 N 8654.9 W 464.3 N 8696.6 W 465.9 N 8737.7 W 467.8 N 8778.4 W 469.6 N 8819.3 W 471.5 N 8860.3 W 473.4 N 8901.5 W 475.2 N 8942.9 W 477.1 N 8984.5 W 479.0 N 9025.9 W - A Gyr oda t a D i re c t i ona i Survey for ARCO ALASKA INC. WELL: 2N-331, 3.5" Location: DRILLSITE 2N, TARN POOL, ALASKA Job Number: AK1098GCE499SS Run Date: 5-0ct-98 10:30:00 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.250000 deg. N Sub-sea Correction from Vertical Reference: 147.3 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 2}3.010 deg Vertical'Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyro da t a D i r e c t i ona i Survey ARCO ALASKA INC. WELL: 2N-331, 3.5" Location: DRILLSITE 2N, TARN POOL, Job Number: AK1098GCE499SS ALASKA Page SUBSEA I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. VERTICAL VERTICAL CLOSURE DEPTH SECTION DIST. AZIMUTH feet feet feet deg. HORIZONTAL COORDINATES feet -147.3 0.00 0.00 0.00 0.0 .35 313.46 .20 100.0 .83 303.93 .50 200.0 2.78 292.92 1.96 300.0 5.75 292.14 2.97 0.0 147.3 247.3 347.3 447.3 0.0 .4 1.3 4.3 11.3 0.0 0.0 .9 313.6 2.4 308.9 7.3 300.2 17.4 295.0 0.0 N 0.0 E .4 N .4 W 1.0 N 1.3 W 2.2 N 4.1 W 5.0 N 11.0 W 400.0 8.90 292.74 3.12 500.0 13.04 292.59 4.09 600.0 19.25 289.07 7.23 700.0 22.41 285.25 3.27 800.0 27.06 281.11 4.17 547.3 647.3 747.3 847.3 947.3 23.4 41.6 67.7 104.7 150.3 33.0 293.6 55.5 293.2 87.3 292.4 124.8 290.6 168.6 288.3 10.0 N 22.9 W 17.4 N 40.8 W 27.3 N 66.4 W 38.6 N 102.8 W 48.7 N 148.0 W 900.0 32.39 280.64 4.77 1000.0 37.73 279.18 4.43 1100.0 42.96 277.66 3.64 1200.0 48.28 276.63 3.63 1300.0 54.07 275.01 3.85 1047.3 1147.3 1247.3 1347.3 1447.3 206.7 276.3 361.1 463.1 587.5 219.3 286.3 307.5 284.7 373.4 283.2 481.0 281.9 598.1 280.6 59.6 N 203.8 W 71.5 N 272.9 W 84.0 N 357.2 W 96.5 N 458.7 W 109.4 N~ 582.6 W 1400.0 61.00 271.51 4.28 * 1500.0 67.73 268.21 1.94 1600.0 68.56 268.53 .44 1700.0 67.54 271.30 4.54 1800.0 68.63 271.64 .29 1547.3 1647.3 1747.3 1847.3 1947.3 744.3 955.6 1204.5 1462.3 1709.8 766.4 279.1 991.2 277.0 1221.4 275.2 1499.8 274.2 1731.6 273.8 118.5 N 739.1 W 117.0 N 950.8 W 109.6 N 1200.4 W 106.2 N 1458.8 W 112.9 N 1706.3 W 1900.0 68.75 272.98 .55 2000.0 67.29 274.04 .66 2100.0 68.51 273.83 .46 2200.0 69.46 273.17 .68 2300.0 68.40 273.93 .55 2047.3 2147.3 2247.3 2347.3 2447.3 1968.0 2208.8 2456.7 2713.9 2979.3 2011.3 273.6 2241.7 273.6 2473.7 273.6 2753.6 273.6 2987.4 273.6 122.9 N 1964.2 W 138.3 N 2204.6 W 155.4 N 2452.0 W 171.8 N 2708.6 W 187.2 N 2973.6 W A Gyro da t a D i r e c t i ona i Survey ARCO ALASKA INC. WELL: 2N-331, 3.5" Location: DRILLSITE 2N, TARN POOL, Job Number: AK1098GCE499SS ALAS KA Page SUBSEA I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. VERTICAL VERTICAL CLOSURE DEPTH SECTION DIST. AZIMUTH feet feet feet deg. HORIZONTAL COORDINATES feet 2400.0 67.31 275.74 .23 2500.0 67.99 275.87 .55 2600.0 68.00 272.78 1.29 2700.0 67.32 270.07 2.92 2800.0 68.59 270.04 .27 2547.3 2647.3 2747.3 2847.3 2947.3 3234.5 3476.0 3729.6 3983.6 4230.6 3266.3 273.7 3497.3 273.8 3776.3 273.9 4008.6 273.8 4240.1 273.6 207.5 N 3228.1 W 231.9 N 3468.6 W 254.2 N 3721.4 W 263.9 N 3975.3 W 263.8 N 4222.6 W 2900.0 69.55 269.85 .39 3000.0 68.42 271.08 .31 3100.0 66.47 271.11 .13 3200.0 65.57 273.96 1.28 3300.0 66.80 273.39 .65 3047.3 3147.3 3247.3 3347.3 3447.3 4491.6 4743.9 4979.1 5212 .3 5439.9 4519.9 273.4 4751.9 273.2 4981.7 273.1 5257.0 273.1 5440.2 273 . 1 263.5 N 4484.0 W 267.3 N 4736.4 W 271.6 N 4971.7 W 279.2 N 5204.8 W 293.8 N 5431.9 W 3400.0 67.74 272.62 .57 3500.0 69.06 272.51 .68 3600.0 66.01 274.41 .46 3700.0 66.11 274.83 .45 3800.0 67.43 275.41 1.16 3547.3 3647.3 3747.3 3847.3 3947.3 5678.9 5930.6 6168.9 6394.0 6622.7 5717.1 273.1 5949.7 273.1 6179.8 273.1 6408.2 273.1 6637.3 273.2 306.7 N 5670.6 W 317.6 N 5922.1 W 332.8 N 6159.9 W 350.7 N 6384.4 W 371.0 N'~ 6612.3 W 3900.0 68.62 274.85 .40 4000.0 70.42 274.50 .52 4100.0 70.05 273.25 1.13 4200.0 70.02 272.01 1.27 4300.0 68.45 271.26 .57 4047.3 4147.3 4247.3 4347.3 4447.3 6872.0 7137.8 · 7411.3 7680.4 7941.8 6915.7 273.3 7150.0 273.3 7431.7 273 .4 7712.9 273.3 7946.0 273.3 393.9 N 6860.7 W 415.6 N 7125.8 W 433.6 N 7398.7 W 444.9 N 7667.6 W' 452.1 N 7929.0 W 4400.0 66.54 271.40 2.72 4500.0 63.48 270.43 4.02 4600.0 58.72 270.79 3.33 4700.0 54.59 272.53 2.99 4800.0 55.61 272.59 .85 4547.3 4647.3 4747.3 4847.3 4947.3 8197.2 8416.3 8599.3 8752.1 8895.2 8224.7 273.2 8451.2 273.1 8625.1 273.1 8790.9 273.1 8914.1 273.0 457.1 N 8184.5 W 460.8 N 8403.7 W 461.4 N 8586.9 W 466.0 N 8739.7 W 472.5 N 8882.6 W - A Gyro da t a D i r e c t i o n a i Survey ARCO ALASKA INC. WELL: 2N-331, 3.5" Location: DRILLSITE 2N, TARN POOL, ALASKA Job Number: AK1098GCE499SS Page SUBSEA I N C L AZIMUTH DOGLEG VERTICAL DEPTH SEVERITY DEPTH feet deg. deg. deg./ feet 100 ft. VERTICAL CLOSURE SECTION DIST. AZIMUTH feet feet deg. HORIZONTAL COORDINATES feet 4896.6 55.96 272.65 .52 5043.9 9038.6 9038.6 273.0 479.0 N 9025.9 W Final Station Closure: Distance: 9038.61 ft Az: 273.04 deg. 4. QUALITY CONTROL QUALITY CONTROL REPORT JOB NUMBER · AK1098GCE499 TOOL NUMBER' 791 MAXIMUM GYRO TEMPERATURE · 75.44 C MAXIMUM AMBIENT TEMPERATURE · 55.36 C MAXIMUM INCLINATION' 71.41 AVERAGE AZIMUTH · 273.04 WIRELINE REZERO VALUE · O! REZERO ERROR / K ' N/A CALIBRATION USED FOR FIELD SURVEY' 2700 CALIBRATION USED FOR FINAL SURVEY' 2700 PRE JOB MASS BALANCE OFFSET CHECK: -.55 POST JOB MASS BALANCE OFFSET CHECW · USED O.O/N/A CONTINUOUS CONDITION OF SHOCK WATCHES -.72 UPON ARRIVAL AT RIG · UPON COMPLETION OF SURVEY' OK OK UPON RETURN TO ATLAS ' OK BOTTOM LINE COMPARISIONS M.D. INC AZIMUTH TVD NORTHING EASTING MWD N~A FINAL SURVEY 10850 55.96 272.65 5043.9 479 9026 FUNCTION TEST JOB NUMBER' AK1098GCE499 5 Survey stations were collected at the measUred depth shown below. The tables show the repeatability of the gyro tool in both inclination and azimuth at one measured depth. INCLINATION M.D. ft 1 2 3 4 5 700 16.460 16.460 16.460 16.460 16.580 AZIMUTH M.D. ft 1 2 3 4 5 700 291.70291.61 216.61 216.81 216.71 5. EQUIPMENT AND CHRONOLOGICAL REPORT EQUIPMENT REPORT JOB NUMBER: AK1098GCE499 DOWNHOLE ELECTRONICS SURFACE ELECTRONICS PRIMARY TOOL No. 791 GYRO SECTION DATA SECTION POWER SECTION BACKUP TOOL No. 790 GYRO SECTION DATA SECTION POWER SECTION A0150 C0111 C0083 A0162 C0089 C0086 COMPUTER POWER SUPPLY PRINTER INTERFACE COMPUTER POWER SUPPLY PRINTER INTERFACE A0467 A0085 A0079 A0143 A0433 A0107 A0029 A0055 WIRELINE COMPANY: CABLE SIZE: 7/32" SCHLUMBERGER RUNNING GEAR 2.25" HOUSING w ECCENTRIC BAR TOTAL LENGTH OF TOOL: 25' MAXIMUM O.D.: 2.25" INCHES TOTAL WEIGHT OF TOOL: 220 POUNDS CHRONOLOGICAL REPORT JOB NUMBER: AK1098GCE499 MONDAY, 10/05/98 05:50 08:00 10:00 11:30 13:30 15:30 17:45 18:30 20:00 23:00 TO LOCATION MU TOOL, RU SCHLUMBERGER PICK LIP GYRO SURVEY TO 3910' TOOL SET DOWN. WORK TOOL TO 5900' PUMP TOOL DOWN SURVEY OUT LD TOOL, RD SCHLUMBERGER. TO ATLAS PROCESS SURVEY, CHECK TOOLS. 2N-339. TOMORROW A.M. STATE OF ALASKA AL/~'I2,A OIL AND GAS CONSERVATION COMMTSSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend_ Alter casing __ Repair well _ Change approved program __ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 96' FNL, 909' FEL, Sec. 3, T9N, R7E, UM At top of productive interval 356' FSL, 795' FWL, Sec. 33, T10N, R7E, UM At effective depth At total depth 369' FSL, 321' FWL, Sec.33, T10N, R7E, UM Operation Shutdown _ Re-enter suspended well _ Plugging__ Time extension _ Stimulate_ Pull tubing Variance Perforate Other X 5. Type of Well: 6. Datum elevation (DF or KB) Development X_ Exploratory __ Stratigraphic __ Service 12. Present well condition summary Total Depth: measured (approx) true vertical 11,225' feet Plugs (measured) 5264' feet Annular Iniection 28' RKB feet 7. Unit or Property name Kuparuk River Field/Tarn Oil Pool 8. Well number 2N-331 9. Permit number 98-117 10. APl number 50-103-20265 11. Field/Pool Kuparuk River Field/Tarn Oil Pool Effective depth: measured (approx) true vertical 11118' feet Junk (measured) 5205' feet None Casing Length Structural Conductor 80' Surface 3813' Size Cemented 16" 9 CY High Early 7.625" 550 sx ASlIIL/250 Cl G Measured depth True vertical depth 108' 108' 3841' 1985' Intermediate Production 10336' Liner 852' 5.5"x 281 sx Class G 3.5" I O364' 4799' 11216' 5259' Perforation depth: measured true vertical Tubing (size, grade, and measured depth) 3.5", 9.3#, L-80 @ 10379' Packers and SSSV (type and measured depth) Baker CSR @ 10364' 13. Attachments Description summary of proposal .... Detailed operation program__ ~"i;B~i~tch __ Contact Paul Mazzolini at 265-4603 with any questions. 14. Estimated date for commencing operation September 1998 Oil X 16. If proposal was verbally approved Name of approver Date approved Service __ 17. I here~ certify that the foregoing is true and correct to the best of my knowledge. Signed ~'2~:O/~' ~-"~~ Title Tarn Drilling Team Leader FOR COMMISSION USE ONLY LOT test, surface cement details and casing detail sheets X 15. Status of well classification as: Gas __ Suspended__ Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test Location clearance Mechanical Integrity Test_ Subsequent-form require 10- ~'~ ~--I~_~¢"~~ Approved by the order of the Commission Form 10-403 Rev 06/15/88 drlglrlal ;Sigilou 0avid W. Commissioner IApproval No~ Date SUBMIT IN T~IPLIC;ATE ARCO Alaska, Inc. Cementing Details Well Name: 2N 331 Report Date: 09/02/98 Report Number: 4 Ri~l Name: DOYON 141 AFC No.: AK9413 Field: KUP Casing Size Hole Diameter: Angle thru KRU: Shoe Depth: LC Depth: % washout: 7 5/8" 9 7/8" 3841 3716 Centralizers State type used, intervals covered and spacing Comments: Used 40 gemeco bow spring cent. as per program. Mud Weight: PV(prior cond): PV(after cond): YP(prior cond): YP(after cond): Comments: 10.3 24 19 39 22 Gels before: Gels after: Total Volume Circulated: 18/22 8/10 1920 bbl. Wash 0 Type: Volume: Weight: Comments: Water 5 bbl 8.3 Spacer 0 Type: Volume: Weight: Comments: ARCO 30 bbl. 10.5 Lead Cement 0 Type: ] Mixwtrtemp: No. of Sacks:I Weight: Yield: Comments: ASIII 80 550 10.5 4.47 Lead cement=Il0 sx as3 on Additives: 1st stage. 440 sx on 2nd As per program stage. TallCement 0 Type: , Mixwtrtemp:, No. of Sacks:, Weight:, Yield: Comments: GI I I 180 250 15.8 1.15 Tall cement=240 sx G on 1st stage. 10 sx on 2nd stage. Additives: as per program Displacement 0 Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: Comments: 6 bpm 6 bpm 95k Reciprocation length: Reciprocation speed: Str. Wt. Down: 15' 90 fph 60k Theoretical Displacement: Actual Displacement: Str. Wt. in mud: 172 bbl. 172 bbl. Calculated top of cement: CP: Bumped plug: Floats held: surface Date:9-3-98 yes yes Time:1600 hrs. Remarks:Last 16 bbls, on 2nd stage was getting 1/3 returns, shut stage tool=bleed off, rigging down diverter. Noticed flow back out of 3" collar on tonal, pipe. shut in f/3 hrs. had 200#= bleed 2 bbl. to 0 pressure. , Cement Company: Rig Contractor: Approved By: DS DOYON M.C. HE M ARCO Alaska, Inc. KR 2N-331 (0-10384, APl: 501032026500 Well Type: INJ Angle @ TS: deg @ 0D:3.500, SSSV Type: NONE Orig Cornpltn: 9/11/98 Angle @ TD: 57 deg @ 11225 ID:2.992) Annular Fluid: DSUSW Last W/O: Rev Reason: Tag fill by ImO Reference Log: Ref Log Date: Last Update: 1/7/99 Last Tag: 11017 TD: 11215ftKB Last Tag Date: 1/4/99 Max Hole Angle: 71 deg @ 8800 NIP (494-495, Size Top Bottom TVD I Wt Grade Thread 0D:3.500) 16.000 0 108 108{ 62.58 H-40 Welded 7.625 0 3841 3841 29.70 L-80 BTC 5.500 0 10384 10384 I 15.50 L-80 LTCM 3.500 10384 11215 11215 t 9.30 L-80 EUE 8rd Size , Top I Bottom TVD I Wt GradeI Thread Surface " 3.500 I 0 10384 10384 9.30 L-80 I EUE 8rd (0-3841, PerforatiOns Summary: i: :: :~: : : : :::: : i : ::~ '::::~ :::~i~: 0D:7.625, Interval 1109~-r~.1D0964 Zone Status FeetSPFIDatet2.Tsy. pe[ Comment Wt:29.70) 10944 - 10964 20 6 1/30/9 60 DEG PHASED HC/DP S:n MD ITVDI ManI Man VMfr VType VOD LatchPort TRO0 Date Vlv SLEEVE Mfr Type Run Comment (10251-10252, 10301 10301 CAMCO KBG29 CAMCO DV 1.0 NT 0.000 9/11/98 0D:3.500) Other (plugs. eqUip,etc,),jeweiry:~:i : :::: : : i: :: i :: :: : ::i: i:: ::: :::::: Depth TVD Type Description ID 494 , ,4~)z/ NIP CAMCO DB NIPPLE 2.875 10251 1..~¢~j~ SLEEVE BAKER CMU - closed 11/30/98 2.813 10354 11.:.~3~ NIP CAMCO D NIPPLE 2.750 Gas Lift 10364 . SEAL BAKER CSA 80-40 2.985 andrel/Dummy I /~ 7 Valve 1 (10301-10302, 0D:4.725) NIP (10354-10355, 0D:3.500) SEAL (10364-10365, OD:5.000) Production (O-1O384, OD:5.500, Wt:15.50) Production (10384-11215, 0D:3.500, Wt:9.30) Peri .......................... (10944-10964) CASING TEST and FORMATION INTEGRITY TEST Well Name: Supervisor: 2N-331 M.C. HElM 7 5/8", 29.7 ppf, L-80, BTC Date: 9/8/98 Casing Size and Description: Casing Setting Depth: Mud Weight: 9.4 pp~l Hole Depth: 4,544' TVD LOT = 3841 TMD 2,314' TVD EMW = Leak-off Press. + MW 0.052 x TVD 810 psi + 9.4 ppg EMW (0.052 x 4,544') = 12.8 ppg Fluid Pumped = 4.0 bbl Pump output = 0.1000 bps 2,300 I:~ 2,2OO psi 2,100 psi 2,000 psi , 1,7OO psi 1,400 psi h300 p~ gOO psi 800 p~ 7OO psi 6OO psi 500 psi 4OO pa 300 psi 2OO p~ 1OO p~i Opsl ! I' J ~ LEAK-OFF TEST I~ ='~-CASING TEST r ..... '~"'"" LOT SHUT IN TIME j ~ ~ CASING TEST SHUT IN TIME jr .r. -+-TIME -IN~ J ~, I ~' '""~ : : 2 4 6 8 I0 12 14 16 18 20 22 24 26 28 30 32 34 36 38 40 42 44 46 4B 60 62 54 56 58 60 62 64 66 68 70 72 74 76 78 80 82 64 86 86 90 stk sir stk stk stk stk stk stl< Stk stk stk stk stk StR stk stk ark ,tk stk stk 5tk stk slk stk stk stk stk stk stk stk stk stk stk stk stk sfk stk 5tk stk stk stk stk stk stk stk stk STROKES LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE ........................... .0..~!.k_~ ........... .0..p.?..i ....... .......................... .2_~.!_k.~ .......... .e..0..p.~! ...... .......................... .4..~t_.k_~ .......... .2..2..0..p..s..i ..... ........................... E.~.!_k_~ ......... ?.s..o..p.~! .... .......................... ~_~!~ .......... ~_4_.o..p.~! ..... .......................... _~..0..?.!_k_.~. ......... .4..0..0..p.~j ..... ........................... .~.E?.!.k.~ ......... .4.~.0..p.~j .... ......................... .L4.._~.!_k.~ ......... §.3..0._p_~_i ..... .......................... .~..6...~.t.~ ......... .6..0..0..~j .... ......................... .~.~..~.k.~ ......... ~.o..~j ..... .......................... .2_0...s_! .k_s. ......... .7..3..o..p_.s.j ..... ......................... .2..2...s_!~.~. .......... Z~.O..p.~j ..... ......................... .2.E.~.!.k.~ ......... ~Zo._P.~j ..... .......................... .2..4...~.!~ ......... .6.~.o._p..s.! ..... ......................... .2.~..~.t.~ ......... .6..o..o..p._.s.! ..... ......................... Eo..~!.k.~ ......... .s..s..o..p_.s.! ..... .......................... ~E~!.k.~ ......... §~.o..p.~! ..... ......................... .4..O...s!k_s' ......... .5..5..0..p_~j ..... .......................... .4..E?.t_k.~ ......... .s._s..o..~j ..... ......................... .S_O...~.!.k.~ ......... _S..S..O..p_~.i ..... ......................... .S.~..s.!.k..s. ......... §.5..O..p_s.! ..... SHUT IN TIME SHUT IN PRESSURE 1.0min i t 450 p_si ..... .... .................... [ .... .... ..... §z'~'~'~ .... i .................... [ .... '~'~'~ .... ..... ~:E~'i'~ .... t .................... ~ .... '~5'Bi;i .... , ..... ~Z'~T~'"-r .................... t .... 'i~'~'~."~ .... I ..... 6]6'~i~ .... T .................... T .... ~'~6'~;i .... l ..... ~Z'~T~'-'T .................... t .... '~'~-p'-;i .... 1 9.0 min .L [ 400 p. si CASING TEST DATA MINUTES FOR CSGTEST STROKES PRESSURE ..................... i- ....................,~ ..................... ..................... [ ..... 5'~i'~ ..... i ...... '6"~'~i' ..... " ................... f ................... t .................... -t I : 2stks ~ 175 psi ~ .................... i ..... ~-~i-~; ..... 1 ..... ~'~'~"~'a'"'i ..................... : ..... ~-~i'~ ..... 1 ..... ~-~-~"~'a'"'l ..................... : ..... ~.~!.k.~ ..... 1 .... ..sZ..s.~.[ .... i 10stks i 1,330 psi ..................... [ .... -~-~i-~ .... ]'"~;~'i;~i'", ..................... [ .... .... i I , 1 SHUT IN TIME SHUT IN PRESSURE 0.0 min ! 2,060Psi 1.0 min : 2,060 psi 2.0 min ! 2,060 psi ..... ES'~B' ......................... !"'Eii~ii'iJ~i"i ..... ~:~'~i'~' .... [ .................... ..... §:iJ'~[h' .... [ .................... ..... g:[J'~i'~' .... [ .................... ..... ~:ij';~fF,' .... ~ .................... ..... §:~'~B' .... [ .................... ..................... t .................... ~ .................... 9.0 min ~ i 2,030 psi t ............... 7 ..... [ .................... ~ ................. ='"~ lO.Omen , ! 2,020DS~ .... '~§:~'~'i'a'"'[ .................... ]'"~:iJ:l'~'~.[i" 25.0min | 2,000 psi i NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY CASING TEST and FORMATION INTEGRITY TEST Well Name: Supervisor: 2N-331 M.C. HElM 7 5/8", 29.7 ppf, L-80, BTC Date: 9/5/98 Casing Size and Description: Casing Setting Depth: Mud Weight: 9.1 ppg Hole Depth: 2,321' TVD LOT = 3841 TMD 2,314' TVD EMW = Leak-off Press. + MW 0.052 x TVD 830 psi + 9.1 ppg EMW (0.052 x 2,321') = 16.0 ppg Fluid Pumped = 0.8 bbl Pump output = 0.1000 bps 2,300 psi 2,200 psi 2,100 psi 2,000 psi 1,900 psi 1,800 psi 1,700 psi 1,600 psi 1,500 psi 1,400 psi 1,300 psi 1,200 psi 1,100 psi 1,000 psi 900 psi 800 psi 700 psi 600 psi 500 psi 400 psi 300 psi 200 psi 100 psi 0 psi 1, [, l, [, i, i, i, 1, I, l, [, l, l, [, I, I, I, 1, i, i, l= i: [= 1: I:TT! = ! =',°,'7= ,?Fy7 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 32 34 36 38 40 42 ~4 46 ~8 50 52 54 56 58 60 62 64 66 68 70 72 74 76 78 ~ 82 stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk Stk stk St~ stk stk stk stk stk stk stk stk stR stR stk stk stk stR Stk stk stk Stk STROKES LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE , .................... -,. .................... 0 stks 0 psi J .................... ..,. .................... ~. .................... J .......................... .!_.s.!.k..s. ........... _s_ 9_ _ .p_ .sj ...... ........................... .2_._s.t_.k__s. .......... .L7__o.__p..sj ..... ............................ ~__s.~_~_s_ .......... .2.Z.O.._p..sJ ..... ........................... _4___s.t__k__s_ .......... _4__o_.o___p_.sj ..... ........................... _5___s.!_k__s_ .......... .5Jg._.p_.sj ..... 6 stks 670 psi ........................... .S.._s]_k_.s. ......... _8.].o...p..sj ..... ..................... ~. .................... i.................... .~. .................... ~. .................... J , , i.................... .~. .................... ~. .................... ., l ~- .................... ' ..................... " .................... ~ ..................... i. ........................................ ,i SHUT IN TIME SHUT IN PRESSURE ...... .o_:_o__.m__i.n_ ................................ _8__~_9_.p..s.! ..... ...... j_:g...mj.n. ............................... Z~_o__p_.s_] ..... 2.0 min 680 psi [ ..... §:~'~i'~ ..... F .................... [ .... '~'i~i ..... ...................... ," .................... t .................... 4.0min , , 640 psi l ..................... F .................... ~ .................... -I 5.0 min : : 630 psi ...... ~._o.?. ..... L .................... [ .... ~.o..o..p_.sj ..... 10.0 min : : 570 psi .... j__4_:_o...m.j~....~ .................... ..... j._5_:.o...m.j.n_..._L .................... CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE ~. .................... ~. .................... ~ .................... .., ........................... .O...s_!.k__s_ ..... j ...... _9_..p__sL ...... 2stks i 175psi r- .................... r .................... -, .................... ........................... _4___s__t_k__s_ ..... j .... __4.9..o_.p..sj_ .... 6stks J 725 psi 8stks i 975 psi 12stks [ 1,600psi 15stks i 2,060 psi : ..................... i' .................... i .................... i SHUT IN TIME J SHUT IN PRESSURE ,- .................... ~. .................... ~ ..................... 0.0 min i i 2,060p_si i ...................... ~ .................... ~, ................... 1.0min : i 2,060 psi i 3.0 min i [ 2,050 psi [ ..... ~:6'~i'fi' .... r .................... i"'Ei~ii-~;i---[ : 6.0 min : i 2,040 psi l : 8.0min : ! 2,030 psi J ..... _9.:.o...m..i..n. .... [ .................... i...~:~_R.s.!__j 10.0 min ! i 2,020 psi i 15.0min J i 2,010 psi l i .... ~iS:6'~'ffi"-f .................... i'"Eiii:iii-i~i'-',,' ~ ......................................... i---Eiii:ii:i-i~i--i ~ .... .2_.5_ ..o__.m..i..n_.i .................... ~ .................... L._..3..o...o...m..i._n._[ .................... i _...2..,.°..°_ .o_ _P_ .s. L,'' NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY CASING TEST and FORMATION INTEGRITY TEST Well Name: Supervisor: 2N-331 M.C. HElM 7 5/8", 29.7 ppf, L-80, BTC Date: 9/5/98 Casing Size and Description: Casing Setting Depth: Mud Weight: 9.1 ppg Hole Depth: 2,314' TVD 3841 TMD 2,314' TVD EMW = Leak-off Press. + MW 0.052 x TVD 830 psi + 9.1 ppg EMW LOT = (0.052 x 2,314') = 16.0 ppg Fluid Pumped = 0.8 bbl Pump output = 0.1000 bps 2,300 psi 2,2oops, ],700 psi 1,600 1,500 psi 1,400 1,000 psi 900psi L K F E T 0 0 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 32 34 36 38 40 42 44 46 48 50 52 54 56 58 60 62 64 66 68 70 72 74 76 78 80 82 stk stk stk stk stk stk stk Stk stk StR stk stk stk stk Stk stk stk stk stk stk SiR stK stk stk stk sTk St!( stk stk Stk stk stk stk stk stk stk stk stk stk stk stk stk STROKES LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE .......................... .l___s_t_.k_.s_ ........... _5__o___p__sj ...... 2 stks 170 psi ........................... ~__s.t_~.s. .......... ~Z_o___p_.sj ..... ........................... .4...s.t..k._s. .......... .4__o_.o...p..sj .... ........................... .5._.s.t..k..s. .......... .E4._o.._p..sj .... 6 stks 670 psi ........................... ~__s_t__k__s_ .......... ~_o___p_.sj ..... , ..................... ~. .................... ~. .................... CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE ........................... .0__.s__t.k_.s. ............ _.0.._p_s..i_ ...... 2 stks 175 psi ..................... r .................... -~ .................... ........................... .4._.s__t.k__s_ .......... . _4..o..o__p_.sj. .... ........................... .6_..s_.t.k._s_ .......... ._7_.2_5__p_..sL .... ........................... .8._.s__t.k__s_ .......... _?_T.s.__p_.sj. .... .......................... J.O...s_.t.k_.s_ ........ j_,~.o__p__s_L_. 12 stks 1,600 psi ......................... J~_.s__tk__s_ ....... _2_ ,_o_ .6..o_ _ _p_ _s. ! _ _ _, i- .................... ~, .................... -i i ' i SHUT IN TIME: SHUT IN PRESSURE ,, .................... ~ ................. 7---~ ! 0.0min ! ! 2,060ps~ j [ ..................... ,~ .................... [ .................... ~ i 2,060 psi j ..... ~: ~' ~r~' .... [ .................... !--'~;~'~;~i"i ~RE [' .... ~:~-['~i~' .... [ .................... ]---~;~-~i--~ ," i 0.0min i i 830 psi j ..... E:~-~-i'~ ..... F .................... [ .... -~-~-i~i .... i ..... '~:~-~i~- .... i .................... i---~;~-~i--1 l ..... §:[:::FB'i'~ ..... F .................... [ .... 'f,i~i:i'i~i .... i ..... ~:a'~i'l:-i-.... [ .................... i-'-~i~ii::i'i:;[i'"!,,' : ..................... ~ .................... ~ .................... i 5.0min ! i 630 psi [ ..... ~:[::)--Ffii-m-i ..... r .................... i .... '~i~'~i .... ! F'--'l-i::i:~'[-h'i'~'"'i .................... i---~i~ii-i:;~i--i 7.0min ~ : 610 psi 15.0min ..... §:~'Ffi"i~ F ..... .................... ~ '~'6i:i'~i~i i i .... .... .... ~:i::i'B'i'ri'"'[ .................... i--'~;i::iiii:i'i:;~i--i ...... ~:[:)--~-i-~ ..... F .................... i .... -~-~i .... ..... j_.o_._.o_..m.j.n. .... L .................... [ .... §Z.°__P_.S_) .......... .8..O.:.O...m._i_.n.._.[ .................... j...~.,.o..o..o__.p__s_!__j NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY ARCO Alaska, Inc. Casing Detail 7-5/8" Surface Casing WELL: TARN 2N-331 DATE: 9/1/98 Subsidiary of Atlantic Richfield Company 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH TOPS Doyon 141 RT to LR = 28.90 7 5/8" Landing Joint 34' OA. 28.90 FMC GEN V- Prudhoe 7 5/8" Csg Hgr 2.02 28.90 54-88 7 5/8", 29.7#, 1_-80 BTC-MOD 1502.33 30.92 Jt #98 7 5/8", 29.7#, 1_-80 BTC-MOD (Thread Locked Collar) 40.50 1533.25 Gemeco 7 5/8" Stage Collar (BAKERLOIO 2.79 1573.75 Jt. #97 7 5/8", 29.7#, L-80 BTC-MOD (Thread Locked Collar) 42.62 1576.54 jts. 3-53 7 5/8",29.7#, L-80 BTC-MOD (shutoff baffle on top ofjt #3, BAKE 2137.11 1619.16 Gemeco Float Collar 1.28 3756.27 jts 1-2 7 5/8", 29.7#, 1_-80 BTC-MOD 82.30 3757.55 Gemeco Float Shoe 1.51 3839.85 3841.36 Insert baffle @ 3716.01 40 Gemeco Bow Spring CENTRALIZERS Run centralizers over stop collars on Jts. 1, 2, 97, & 98. Run centralizers over collars on Jts 3-13, 16, 19, 22, 25, 28, 31, 34, 37, 40, 43, 46, 49, 52, 56, 59, 62, 65, 68, 71, 74, 77, 80, 83, 86, 89. Remarks: String Weights with Blocks: 100K# Up, 65K# Dn, 12k# Blocks. Ran 90 joints of casing. Drifted casing with 6.750 plastic rabbit. Used Arctic Grade APl Modified No Lead thread compound on all connections. Casing is non-coated. Doyon 141 Drilling Supervisor: M.C. HElM --T-,'TY -¥NOWLES. 30VERNOn, ~LASKA OIL AND GAS ~ONSERVATION COMMISSION .\uuust 14. 1998 ~001 ~CFCUPINE DFiVE : NC;'~C..-q.'AG E. ALASKA 99501-31.92 :HONE: ~07) 279-143S :~,X: ~07~ 276-7542 Paul Ma72ol iili Tam Drilling Team Leader .-'uRCO Alaska. Inc. PO Box 100360 .*nchoraae. AJ<. 995 I0-0360 Re: Kuparuk River Unit 2N-331 ARCO Alaska. Inc. Permit No. 98-117 Sur. Loc.: 96'FNL. 909'FEL SEC 03. T09N. R07E. UM Btlnhole Loc: 39YFSL. 360'FWL. SEC 33. T10N. R07E. Dear Mr. Mazzolini: Enclosed is thc approved application for permit to drill the above rcfcrcnccd well. The pcrnut to drill docs not exempt you from obtaining additional permits rcquircd by law front governmental agencies, and does not authorize conducting drilling operations until all other required permitting dctcrnunations are made. Am~ular disposal of drilling waste will not be approved until sufficient data is suNnitted to ensure that tim requirements of 20 AAC 25.080 arc met. Annular disposal of drilling wastes will bc contingent on obtaining a well ccmemcd surface casing confinned bv a valid Fonnation Integrity Test (FIT'). Cementing records. FIT data. and any CQLs must be submitted to the Comlnission on Fonn 10-403 prior to thc start of disposal operations. Please note that anv disposal of fluids gcncratcd from this drilling operation which are pumped doxvn the surface/production casmg aunulus of a permitted existing well on Drill Sit~ 2N nmst comply with thc requirements and limitations of 20 AAC 25.080. Approval of this pcmut to drill docs not authorize disposal of drilling xx astc in a volume greater titan 35.000 barrels tlu'ough thc aunular space of a single well of for a period longer than one year. Blowout prevention equipment tBOPE) mnst bc tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of thc BOPE test performed before drilling below the surface casing shoe must be given so that a representative of tile Co~mnission ~nav xvitncss the test. Notice may be given by contacting thc Conumsslon petroleum field inspector on thc North Slope pager at 659-3607. David W. Johnston Chairman BY ORDER OF THE COMMISSION .:.i: encmsures l)epartmcnt of i:'<h 8: Game. [labitat Section w o cncl. i)cDllrl[llCll[ of ! :7, :rOlllllClll. {._'oilserw:.ltlOll ',,',' o end. ARCO Alaska, Inc. ' Post Office Box 100360 Anchorage, Alaska 99510-0360 August 3, 1998 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re' Application for Permit to Drill KRU 2N-331 Surface Location: 96' FNL 909' FEL Sec 3 TgN R7E, UM Target Location: 375' FSL, 729' FWL Sec. 33, T10N, R7E, UM Bottom Hole Location: 393' FSL, 360' FWL Sec. 33, T10N, R7E, UM Dear Commissioner Johnston, ARCO Alaska, Inc. hereby files this Application for Permit to Drill a development well in the Tarn area, KRU 2N-331, located approximately seven miles southwest of the Kuparuk River Unit's 2M Drillsite. The well is accessed via a new gravel road originating at 2M Pad. Doyon Rig 141 will drill the well. If commercial, the well will completed with Doyon 141 also. Attached is the information required by 20 AAC 25.005(c). There will be no reserve pit for this well. W~ aste drilling mud will be disposed of down the annulus of an existing well on Drillsite 2N .(subiect to AOGCC ap_proval), or hauled to a KRU Class II disposal well. All cuttings generated will be either stored temporarily onsite or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. The TD of this well will be in the Tarn formation. H2S has not been encountered in this region in any stratum shallower than the Lisburne Formation. Therefore, ARCO has not included an H2S contingency plan with this Application, and requests an exemption from the H2S requirements. However, all drilling mud, cores and produced fluids exiting the wellbore will be monitored for detectable levels of H2S. The following are ARCO's designated contacts for reporting responsibilities to the Commission: RECEIVED Au~ ~998 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany Alaska 0il & Gas Cons, ComI.~lssion Anchorage David W. John~$n Application for Permit to Drill Page 2 KRU 2N-331 1) Completion Report (20 AAC 25.070) Sharon AIIsup-Drake, Drilling Technologist 263-4612 2) Geologic Data and Logs Doug Hastings, Geologist (20 AAC 25.071) 265-6967 If you have questions or require additional information, please contact Tom Brassfield at 265-6377 or me at 263-4603 in our Anchorage office. Sincerely, Paul Mazzolini Drilling Team Leader Exploration / Tarn Development Group Attachments cc: KRU 2N-331 Well File STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill E lb Type of Well Exploratory [~ Stratigraphic Test r, Development Oil X Re-Entry F' Deepen E Service [~ Development Gas r- SingleZone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 28', Pad 121' feet Kuparuk River Field 3. Address 6. Property Designation Tarn Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 380054,~ALK 4602 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 96' FNL, 909' FEL, Sec. 3, T9N, R7E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 375' FSL, 729' FWL, Sec. 33, T10N, R7E, UM 2N-331 #U-630610 At total depth 9. Approximate spud date Amount 393' FSL, 360' FWL, Sec. 33, T10N, R7E, UM 8/20/98 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 2N-337A 11209' MD 360' @ TD feet 87' @ 525' feet 2560 5253' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 300' feet Maximum hole angle 68.15° Maximum surface 1 357 psig At total depth (TVD) 2300 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 90' 28' 28' 118' 118' _+200 CF 9.875" 7.625" 29.7# L-80 BTC MOB 3814' 28' 28' 3842' 2300' 1. 110 sx ASIIIL & 240 sx CIG 2. 260 sx ASIII L & 60 sx ASI 6.75" 5.5" 15.5# L-80 LTC-M 10357' 28' 28' 10385' 4780' 260 sx Class G 6.75" 3.5" 9.3# L-80 8rd EUE 824' 10385' 4780' 11209' 5253' (included above) 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural ConductorRECEIVED Surface Intermediate Production /~ijG 4 1998 LinerORIGINAL Perforation depth: measured true verticalAlaska 0il & Gas Cons. c0mrnis~ioi Anchorage 20. Attachments Filing fee X Property plat F' BOP Sketch X Diverter Sketch X Drilling program X Ddlling fluid program X Time vs depth plot E Refraction analysis E~ Seabed report [~ 20AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ¢"'~O.~ ~"~~__,~ Title Tarn Drilling Team Leader Date Commission Use Only I APl number [ Approval date ~/ f,~ [~ I See cover letter for Permitl~?er il7 50-JO~ ~,','~O& ~' -- "' other requirements Conditions of approval Samples required F- Yes [~ No Mud Io~ requtred E Yes [~ No Hydrogen sulfidemeasures r'- Yes ~ No Directional surveyrequired ~' Yes E~ No Required working pressure for BOPE F' 2M [~ 3M [~ 5M [~ 10M E 15M Other: d,'ig~rla. I Signed By~/~. David W. Johnstonby order of ~/l Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 i~ :ate 10. 11. 12. ARCO Alaska, Inc. GENERAL DRILLING AND COMPLETION PROCEDURE KUPARUK RIVER FIELD - PRODUCER KRU 2N 331 1. Move in and rig up Doyon 141. 2. Install diverter system. 3. Drill 9-7/8" hole to 7-5/8" surface casing point according to directional plan. 4. Run and cement 7-5/8" casing, using stage collar placed approximately 200' MD below the base of the permafrost. Use lightweight lead cement in the first stage. 5. Install and test BOPE to 3,500 psi. Test casing to 2,000 psi. 6. Drill out cement and 20' of new hole. Perform leak off test to 16.0 ppg 7. Drill 6-3/4" hole to TD according to directional plan. Run LWD logging equipment with density and porosity tools. Note: If significant hydrocarbon zones are present above the Tarn, sufficient cement will be pumped for isolation in accordance with 20 AAC 25.030(d)(3)(C). 8. Run and cement 5-1/2" L-80 LTC Csg X 3-1/2" L-80 8rd EUE-Mod tapered production casing string with Baker casing seal receptacle at crossover point. 9. Pressure test casing to 3,500 psi. Run 3-1/2" L-80 8rd EUE-Mod completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus to 3,500 psi. ND BOPE and install production tree. Secure well. Rig down and move out. ARCO Alaska, Inc. DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRILLING AREA RISKS Well KRU 2N 331 Drillinq Fluid Properties' Density PV YP Funnel Vis Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to surface casing point 9.0-10.2 ppg 15-35 25-50 70-120' Drill out to TD 8.5 - 10.0 ppg 12-24 15-30 45-60 10-25 15-40 5-7 9.5-10 +_10% 2-6 4-8 4-6 through Tarn 9.0-10 <11% Drillinq Fluid System: Triple Derrick Shale Shakers Desander, Desilter, Mud Cleaner Centrifuge Degasser IPit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators *Spud mud should be adjusted to a FV between 100-120 sec/qt to drill gravel beds Drilling fluid practices will be in accordance with the regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Maximum anticipated surface pressure (MASP) while drilling the production hole is calculated using a surface casing leak-off of 13.5 ppg EMW (0.70 psi/fi) and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur at a surface pressure of 1,660 psi. Therefore ARCO will test the BOP equipment to 3,500 psi after setting surface casing. MASP = (2,300 ft)(0.70 - 0.11) = 1,357 psi Based on offset well data, reservoir pressures in the Tarn sands in the vicinity of 2N pad are expected to be -2,350 psi (0.50 psi/ft). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.5 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 5,100'. ARCO Alaska, Inc. Well Proximity Risks' The nearest well to 2N 331 is 2N 337A. The wells are 87' from each other at a depth of 525'. Drillinq Area Risks: The primary risk in the 2N 331 drilling area is shallow gas below the permafrost. Therefore the surface hole will need to be drilled with weighted mud (9.8 - 10.2 ppg) to avoid underbalancing the hole. Another observed problem in the area is lost circulation at around 3,300' TVD and in the Tarn formation. Analysis of pressure data from offset wells shows that a mud weight of 9.6-10.0 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement the well. The 9-5/8" casing shoe will be tested to leak-off, or to a maximum equivalent mud weight of 16.0 ppg upon drilling out of the casing. Annular Pumpin_cl Ol~erations: Incidental fluids developed from drilling operations will be either injected into an approved annulus on the same pad or hauled to the nearest permitted Class II disposal well. (Note that cement rinseate will not be iniected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 2N 331 surface/production casing annulus will be filled with diesel after setting production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. We request that 2N 331 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoe will be set a minimum of 200' vertically below the base of the West Sak into the heart of the shales. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2,300') + 1,500 psi Max Pressure = 2,935 psi --" ARCO Alaska, Inc. ~ This pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and production casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf)Grade!Range Type Collapse Collapse Burst Burst 7-5/8"29.7 L-80 3 BTC 4,790 psi 4,072 psi 6,450 psi 5,483 psi 5½" 15.5 L-80 3 LTC-Mod 4,990 psi 4,242 psi 7,000 psi 5,950 psi 3½" 9.3 L-80 2 8rd EUE Mod 10,530 psi8,951 psi 10,160 psi8,636 psi Fluids to be disposed of in the annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (h). 2N WELLBORE SCHEMATIC and CEMENT DESIGN 16' Conductor Casing at 135' MD I RKB permafrost ::::::::::, 1,254' MD :!:!:i:i:! Stage i:i:i:i:i: 1,536'MD Top of :i:i:i:!:! WestSak ..... 1,3'11' MD :i:i:i:i:i ..... West Sak 2,1t40' MD 7-5/8" Surface Casing at 3,842' MD Top of Cement at 9,800' MD Production 10,385' MD Production Casing at 11,209' MD :.:.;-:-:- 6-3/4" Hole Conductor Casing Size I Hole Size 16' in 20' hole Depth: 135' MDRKB Top of Cement Surface Excess Calculated: -100% Volume Calculations: (135 to (0.7854 cf/if) (2.00) = 212 cf (212 cf) 1(0.93 cflsx) = 230 sx Slurry Volume: 212cf or Arctic Set I 230ax S~uny Weight 15.7 ppg rounded Slumf Yield 0.93 cf/sx Surface Casing excess 7-5/8' in 9-7/8" hole Stage 1: Volume (1,506 to (0.2148 d/if) (1.45) = 469 cf Lead (469 cO ~(4,42 cf./ax) =106 sx Tail (800 If) (0.2148 cf/if) (1.45) = 249 cf shoejointvo121 cf+ (249cO 1(1.15cf/sx) = 237sx System: Lead (Arctic Set 3 Lite cement + 3.5% D44 (NaCI) + 30% D53 (gyp) + 50% D124 (spheres) + 1.5% SI(CaClz) + 1.5% D79 (ext.) + 0.4% D46 (deft=am.) Tail (Cl G cmt + 1% SI(CaCI2) + 0.3% D65 (disp.) + 0.2% D46 (defoam.) Lead Slurry Volume: 469 cf or 110 sx Slurry Weight 10.5 ppg Arctic Set 3 Ute Slurry Yield 4.42 cf/ax Thickening Tu~e 6.0+ hours Tail Slurry Volume: 249 cf or 240 sx Sluny Weight 15.8 ppg Class G Slun-y Yield 1.15 cf/ax Thickening Time 3.5 - 4.5 hours Surface Casing excess Stage 2: VOl. Lead (1,254 tO (0.2148 cf/if) (4,00) = 1,077 cf (132 If) (0.2148 cf/i0 (1.45) = 41 cf (1,118 CO 1(4.42 cf/ax) = 253sx Tail (0 tO (0.2148 cf/10 (4.00) = 0 cf (150 If) (0.2148 cf/if) (1.45) = 47 cf (47 cO /(0.93 cf/ax) = 50 sx System: Lead (Arctic Set 3 Lite cement + 3.5% D44 (NaC~) + 30% D53 (gyp) + 50% D124 (spheres) + 1.5% SI (CaCrz) + 1.5% D79 (ext.) + 0.4% D46 (detoam.) Tail (Arctic Set 1 cement ) Lead Slur~ Volume: 1,118 cf or 260 sx Slun'y Welghl 10.5 ppg ArcticSet3 Ute Slurry Yield 4.42 cf/sx Thickening Time 6.0+ hours Tail Slurry Volume: 47 cf or 60 sx Slurry Weight 15.7 ppg Arctic Set 1 Slurry Yield 0.93 cf/sx ThicAening Time 3.5 - 4.5 hours Production Casing Size I Hole Size 5-112" and 3-112" in 6-3/4" hole Depth: 11,209' Top of 3-1/2' casing 10,385' Top of Cement 9,800' Excess Calculated:50% BHT(Static): 160'F 13(:PF BHT(Cim): exce,~ Volume around 5-1/2" (585 to (0.0835 cf/if) (1.50) = 73 ct' Volume around 3-1r2" (824 if) (0.1817 cf/if) (1.50) = 225 cf 298 cf shoe joint vol 4 cf+ (298 cf) /(1.20 cf/ax) = 251 sx System: (Class G cement + 2 gpa D600 (latex) + 0.1 gpa D135 (stabilizer) + 0.1 gpa D47 (defoam.) + 3% D53 (Gyp) + 0.8% D65 (disp) + 0_12% DS00 (ret.) Slurry Volume: 298 cf or 260 sx Slun'yWelght 15.8 ppg C/ass G Slurry Yield 1.20 cf/ax Thickening Time 3.5 - 4.5 hours 7/31/98 ARCO Alaska, Inc. Diverter Schematic Doyon 141 Flowline ~ 21 ¼" 2,000 psi WP DRILLING SPOOL w/16" Outlet I 21¼" HYDRIL MSP 2,000 psi WP ANNULAR PREVENTER 16" 200 psi WP HYDRAULIC KNIFE VALVE _~/ 16" OD DIVERTER LINE 16" 62 ppf PEB CONDUCTOR PIPE set at 80' (GL) ARCO Alaska, Inc. DOYON 141 13-5/8" 5,000 PSI BOP COMPONENTS 1 F I I 3" 5,000 psi WP OCT r-j MANUAL GATE V KILL LINE ~r~ 3" 5,000 psi wP Shaffer GATE VALVE w/hydraulic actuator / / DSA 13-5/8" 5,000 psi WP --"'"'"~'L x 11" 3,000 psi WP \ 13-5/8" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER w/companion flange to bell nipple DOUBLE 13-5/8" 5,000 psi WP, HYDRIL Magnum BOP w/pipe rams on top and blind rams on bottom 3" 5,000 psi wP Shaffer GATE VALVE _ __ ~/hydraulic actuator L~~ CHOKE LINE 13-5/8" 5,000 psi WP k__~ ~ DRILLING SPOOL w/two 3" 5M psi WP outlets SINGLE 13-5/8" 5,000 psi WP, HYDRIL MPL BOP w/pipe rams <- West (feet) 9500 9000 8500 8000 7500 7000 6500 6000 5500 5000 4.500 4000 3500 3000 2500 2000 1500 1000 500 0 TD LOCATION SEC. 33, T10N RTE I ~,,~~~ .... 0 - ,RKB EL~ATION: 149 ~. O% I TARGET LOCATION: ] % % 500 I r v 375' FSL, 729' FWL - IKOP TVD=300 *MD=300 DEP=0 { SEC. 33, T10N, R7E I TARG~ 500 - _ ~9.00 ~D=4994 1000 ~ TMD:10758 - NBEGIN TURN TO TARGET ~D:794 TMD=800 DEP=64 OEP=8935 ~nan N24.95 DLS: 5.00 deg per 100 fi NORTH ~70 .... - N ~EST 8922 ' ~.~2 T/ W SAK SNDS TVD=1243 TMD:1311 DEP=299 1500 ~ EOC ~D=1565 TMD=1868 DEP=746 0~ ~t A~IllTTmII I91 ~5' NL, 909' FEL . 2000 1I l Villi Ill l NTC_I ~ ~ 5/8" cso PT ~O=2~00 T~D=aa42 IYIAXIIYI U lyf AIN ~L~ ~~ c80 TVD=2457 TMD=~264 OEP=2970 ~oo 68.15 DEG 3000 3824 TMD=7937 DEP:6379 4000 4500 BEGIN ANGLE DROP TVO=4572 TMD 66.55 DLS: 3.00 deg per 100 ft 57.55 5000 5500 55 DEG 0 500 ~ 000 1 ~00 2000 2500 ~000 3500 4000 4500 ~OOO 5500 ~000 6500 7000 7500 8000 8500 9000 9500 10000 VerHcal Section (feet) -> Azimuth 273.01 with reference 0.00 N, 0.O0 E from slot I1351 IARCOA1 ska, Inc. a IStructure : Torn Drill Site 2N Well : 3],1 Field : Tarn Development Field Location : North Slope, Alaska 220 2OO 180 160 140 120 A I 1 O0 80 (-' 60 0 Z 40 60 <- West (feet) 560 340 320 ,:300 280 260 240 220 200 1 BO 160 140 120 1 O0 80 60 40 20 0 20 40 60 I I I I [ I I t I I I I I I I I I I I I I I I I I I I I I I I I I I I I I t I I I I I ~-.. ~-.. ~oo ~ %,,~. ................ . .............. ~ ~ ~;; ,,. ',,.,,, '"-.. 1500 "--.. ~ ',,.. '.,,, '"'"-.. '""-.. ._ "-...~100 '-.. '... ....... '"'--... 1700 ~ '"-. "-. ' ' .... "'-. ........ .. ~ ',, ',. ,,oo ~ ..... '"'"'" ~.~oo ....... '" "'""'~'" ...... - ......... '--.. ~ ~oo' ,,",, ................ ' ........ '""--,,j 6oo ~ ".,% ........ &~oo ....... . " .... '~. ~ooo ",','.,, ~ ............. ""'.~oo .... ..... '"'-.. -~u '"'"" ~ooo ~"---~ ¢oo ....... ' ...... ",.., ~ '.'..,. ~ ....... - ...... "-,.. ~ 500 ~ ~ ~ oo '",,. ~ ..... ... 1500 '""" -'"'" ~ 900 ""'% '"'"'--. '""-. "",. 1400 ~ ............................... ............... ..... ..,..,..o.o..... -'"'"---?0 ~ 7200 ............................ "'-.... 1 200 "-.. ".., c~-:: .................... - ......... ,..~..o~ ............ ~ ........ ..~.,..oo -.....~.o.o '.....:~oo O0 '"'"-... 1000 "'"., 800 '"'¥-~. '"-... 900'"-. 700 looo ............... '~b'O ............. _ 900 ~ ....... .~oo "-.~..~. ""-....700 ~.~ 500 ~ 400 ....................................................................................... soo '~ ' ......... ::: ..... 500 ............................................... 700 500 "-'~t' ..... T 500 ~/o oo / 60° i .oo · 700 _sOO/o ' / [7oo ~ o o / 700 800 , ..... I .... I I I I I I I~ I I i I I I i I i I I i I i I i I I 360 34-0 520 300 280 260 240 220 200 180 160 14.0 120 1 O0 8'0 ' ' ' ' ' ' ' ' 6'0 60 40 2'0 0 2'0 4'0 <- West (feet) 220 200 180 160 120 ~oo I Z 0 8o -~ 6o --~ 4o 20 4o 6O ARCO Alaska, Inc, Structure: Tarn Drill Site 2N Well : 331 Field : Tarn Development Field Location : North Slope, Alaska 700 600 500 400 3O0 2OO 100 0 100 200 300 400 50O 6OO 700 <- West (:feel) 2400 2500 2200 2100 2000 1900 1800 1700 1600 1500 1400 1300 1200 1100 1000 900 800 700 600 500 400 300 I t I i I I I I I J I I I I I I I I I I I I I I I I I I I I I I I I I i I I I I I I 1 ...................... "'~-~..:::::::: ........... . . ""-.:::-.,......, ~:::..~. ......... 2500 ........ ' ..... 2700 ' '""" 2~°~ ~oo ............... ' ........ ::::' ........ ' -~. """,'~. 19oo ................. ' ........ ::::' ..... -. 2500 , ":::"" 500 ~ 2500 .......... ' ..... ' .... ' ~oo ............. ' ...... ::::::.~.o..o_ -....200 ............ . ...... :::::: ........ oo .............. ~1oo 19;~'--:'-:'.:: ......... 21oo~. .......................................... !?__o_o. ~---_.~:_.~ '-- .......... - ........ ::::..:.: ..... ~. 300 ...............................~1~oo 1~o~ 19oo 1~ ...... : ...... 200 ..................... 2100 ..................................................... 1900 " 1500 ....................................... 1700 ....... - ......................................................... 1 500 1 O0 1500 1700 .................. 54oo. .......... :::::::::::~-~'---'~-5~3300 2~oo ~~~oo ~ ~ ....... 3~'~ .... ~900 2700 ~ ~ 1500~ ~ ~ - ' 170O . 500 I I I I I I I I I I I I I I I I I I I t I I I I I I I I I I I I t ~/ I I I I I I I I I / 700 2400 2300 2200 21 O0 2000 1 gOO 1800 1700 1600 1500 1400 1300 1200 11 O0 1000 900 800 700 600 500 400 300 <- West (feel) A I 2: o ARCO Alaska, Inc. Structure : Torn Dr;Il Site 2N Well : Field : Tarn Development Field Location : North Slope, Alaska 1600 1400 1200 1000 8O0 600 ¢00 200 0 2O0 400 6OO 800 10o0 1200 <- West (feet) 6000 5800 5600 5400 5200 5000 4800 4600 4400 4200 4000 3800 3600 3400 3200 3000 2800 2600 2400 2200 2000 1800 I I I I I I I I I I I I I I I I I I I I I ~ I I I I I t I I I I I I I I I I I I I f ~ ..... q~ .... q~ .... .. ~oo ~o %.. .......... 3700 ........ " --.. '---.............. 3100 '"' .......... '--""--.. 4500 ~ '"-, ~ 2700 "-~-- .......... _..~oo ............ . ..... ~?.?o ............... 2900' ......... ' .......~, 4100 .......... 3300 ........ ' ...... '~....~500 ............ ' .......... ' ........ p9oo .... _~L?.o. ......... 2700 .......... 3500 ........ g?..o~ ........ '.::::: ...... ~3oo ............... 2500 ....... :::::: ...... 31 ~_______~4300 ........ 2700 ...... .~"~ 2900 3700 5500 ...................................... 2700 ~ 3300 ................................ 7 ................ 2500 31 O0 2900 2300'-'-"-"----'~ 27OO 2500 2300 3500 2j oo ~ ....................... 3300 ~ ~ ~ - .................. .................................................... :j..u_u._ ................... ?~00 2700 250(:] .......................... 2Lo_?_ ....... _~ 2300 ............. ZtO0-'"~4~ ................ 5100 ............. 4500 2500 ..................... 4900 2900 ...................... 3500 3300 ......... ~t~__~J~ 4500 4100 5900 3700 .. -- 3100 ................................. .-- 3100 2900 27~ 3300 ................................... [~ .............. ~00 23°0/ ~ 2300 2900 ~ 2500 3100 ,, 2700 2700 2900 ~ 3100 /' 3300 3300 ,' ~ 3500/-'-~ /" 3900...~.~ ,'/ ,, i i i I I i I i i i i i i i ! I i I I i I ! I ! I [ i i I I i I I I I I 1600 1400 1200 1000 80O 6O0 I 400 Z 0 200 ~- 0 200 400 60O 800 1000 1200 6000 5800 5600 5400 5200 5000 4800 4600 4400 4200 4000 3800 3600 3400 3200 3000 2800 2600 2400 2200 2000 1800 <- West (feet) IAI CO Alaaka, Inc. ..... Structure : Tarn Drill Site 2N Well : 331 Fleld : Tarn Development Field Location : Nodh 51ope, Aloska <- West (feet) 9800 9600 9400 9200 9000 8800 6600 8400 8200 8000 7800 7600 7400 7200 7000 6800 6600 6400 6200 6000 5800 5600 5400 2000 , I I I I I I I I I I ~ ~ I ~ ~ ~ J J ~ I I I ~ I I ~ I I ~ ~ I ~ I. I I II I. ~, I 2000 ....... _j~oo 1800 1800 1600 600 1400 1400 1200 1200 1000 1000 ~ 5300 ~~--..__..__._~5100 4900 4700 4500 800 5300 3100 3700 3500 .................................. ............................................................................................................. 2900 ~ ............................................................................. 600 [~ ......... 2100 4900 ¢700 4500 ....................................................................... 4300 4100' ~9~0 400 ......................................................... ~ u 3700 350C 800 6O0 ~00 2OO 200 4OO 6OO 8OO 3300 3500 .......................... 3700 3900 2O0 200 4O0 60O 800 9800 9600 9400 9200 9000 8800 8600 8400 8200 8000 7800 7600 7400 7200 7000 6600 6600 6400 6200 6000 5800 5600 5400 <- West (feet) Z I ARCO Alaska Inc. Structure : Tarn Drill Site 2N Il : .551 Field : Torn Development Field Location : North Slope, Alaska WELL PROFILE DATA ..... Pe~t ..... N0 inc OL' ~0 No~ Cait v. Sect 0e~lOO ~l on 0.O0 ~a0 0.~ 0,~ O.~ 0.CO 0.~ a. o0 KOP 300.ag O. oo0.~ 300.~ o.~o O.~ 0.~ O. aO End ~ ~d~um 8~.00 IS, Q0 282.00 794.31 I&Sl -63.65 E~.~ 3.00 Blg~ S ~ ~ l~.gg 25.0027g.~g82.g4 25.61-131.22132.~5.00 ~d al ~d~um 1867.8S~.15 272.76 IS&S,I~76.0J-74~.4&746.41 5.00 ~d ~ ~ 1~5.10 ~.~ 272.78 ~780~8 ~4.g6-8617.4~ 8e2g.~ 3.00 ......... C~, ........... ~ ..................................... TRUE NORTH ~d et ~ 11~.76 ~ 272.76 tl~&.~ 47g.~ -~127.~ il4~,~ ~.~ 550 0 10 34O 20 33O q~ .... 520 -- 3900 510 300 29O 280 27O 5O c~oted ~ ~.ch For: BRASSFIELD gate ~otled : 2g--dui-g8 J Plot Reference i,~ ,.131 V~on ~7. I ~ 71100 4oi/ jgoo / / / / 7O 8O 9O 26O · 700~, , 250 ', 240 11( 250 22O 2 2C 190 180 Normal Plane Travelling Cylinder - Feet 100 110 120 130 ""--.. 140 · -- )0 '"'., 1 1 O0 "'-. ................ "1% -1- ~'"'- 11 O0 170 All depths shown ore Measured depths on Reference Well ARCO Alaska, Inc. Tarn Drill Site 2N 331 slot #331 Tarn Development Field North Slope, Alaska SUMMARY CLEARANCE by Baker Hughes INTEQ REPORT Your ref ~ 331 Version Our ref : prop2857 License : Date printed = 29-Jul-98 Date created = 27-Feb-98 Last revised : 28-Jul-98 Field is centred on nT0 12 49.742,w150 18 33.414 Structure is centred on nT0 10 13.955,w150 18 32.772 Slot location is nT0 10 13.022,w150 18 59.106 Slot arid coordinates are N 5911913.137, E 460683.927 Slot local coordinates are 94.81 S 909.01 W Projection ty~e= alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object we11path PMSS <O-9553t>,,323,Tarn Drill Site 2N PMSS <0-9631'>,,343,Tarn Drill Site 2N PMSS <0-9690'>,,329,Tarn Drill Site 2N PMSS <O-12339'>,,341,Tarn Drill Site 2N PMSS <0-10655'>,,337,Tarn Drill Site 2N PMSS <7090-???>,,337A, Tarn Drill Site 2N PMSS <0-???>,,313,Tarn Drill Site 2N PMSS <O-8239~>,,339,Tarn Drill Site 2N PMSS <O-7431~>,,345,Tarn Drill Site 2N PMSS < 0 - 7650>,,Tarn#2,TARN #2 PMSS < 2250 - 7162'>,,3A, TARN #3 PMSS < 0 - 6150'>,,TARN#4,TARN#4 Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging £romM.D. 23-Jul-98 117.2 375.0 375.0 28-May-98 175.7 575.0 575.0 28-May-98 30.0 0.0 0.0 15-Jul-98 148.1 575.0 575.0 18-Jun-98 87.1 525.0 525.0 19-Jun-98 87.1 525.0 525.0 28-Jul-98 268.6 350.0 350.0 1-Jun-98 112.2 575.0 575.0 21-Jul-98 165.5 1125.0 1125.0 14-Aug-97 12974.7 120.0 120.0 13-Jul-98 4086.7 2220.0 2220.0 12-Aug-97 6765.7 325.0 325.0 · WELL PERMIT CHECKLIST COMPANY FIELD & POOL ADMINISTRATION INIT CLASS ~ ~ LJ ENGINEERING WELL NAME '[~-x.~CL. ~(~'~ ~,.~ ! PROGRAM' exp [] devAredrll [] serv [] wellbore seg II ann. disposal para req,/~ g ~ OBOE AREA ~ ¢ 0 UNITfl / ( / ~ 8 ON/OFF SHORE d ~ 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... (~N N 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. ROPEs, do they meet regulation ................ 26. ROPE press rating appropriate; test to ~(:~O~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. N N N GEOLOGY A~R DATE 30. Permit can be issued w/o hydrogen sulfide measures ..... 31. Data presented on potential overpressure zoO. 32. Seismic analysis of shallow gas ~ ......... 33. Seabed condition surve~~ore) ............. 34. C~ progress reports ....... ory only] ANNULAR DISPOSAL APPR DATE 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... (B) will not contaminate freshwater; or cause drilling waste... to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N Y N . . Y N Y N N APPC,.oV,~.~ p-"~¢-- .F-'O [d t-.~ ~ rO,~ 'd l....A,g-- ,,E:)I 5Po5¢,, t_.. . N N. N (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. G E O.L1_%G_ Y: .... ENGINEERING; UlC/Annular C OM M..LSS I_O_N..: JDH ~ ' RNC ............ ~_.~__ co .... M:chet~list rev 05/29/98 dlf:C:\msoffice\wordian\diana\checklisl _. Please note tl~at an,,' disposal of fluids gc'n'cratcd from this' drilling operation which are pumped down thc surfacc/pr~:tuction casing annulus of a permitted cxistin ,,veil on Drill Site .l-.D~rn~ust corn ' · - " g ply xx'~th thc rcqu~rcmcnts and l~mitations of 20 AAC 2~.080. .-\pproval of this pcrrnit to drill docs not authorize disposal of drilling x~astc in a volume ~rcater than 35.000 barrels through thc annular space ora single xvcll or for a pcriod longer than one x.car. ~ Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. * ALASK~ COMPUTING CENTER * ....... SCHLUMBERGER ....... * ............................ * COMPANY NAME WELL NAME FIELD NAME BOROUGH STATE API NUMBER REFERENCE NO : BP EXPLORATION, INC. : MPF-80 : MILNE POINT RECEIVED 1999 ' NORTH SLOPE : ALASKA : 500292292800 : 98618 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JAN-1999 15:23 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 99/01/ 6 ORIGIN : FLIC REEL NAME : 98618 CONTINUATION # : PREVIOUS REEL : COR~4ENT : BP EXPLORATION, MILNE POINT, MPF-80, API #50-029-22928-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE ' 99/01/ 6 ORIGIN : FLIC TAPE NAME : 98618 CONTINUATION # : 1 PREVIOUS TAPE : CO~94ENT . BP EXPLORATION, MILNE POINT, MPF-80, API #50-029-22928-00 TAPE HEADER MILNE POINT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: ~GE : FNL: FSL: FEL: FWL : ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1 ST STRING 2ND STRING MPF-80 500292292800 BP Exploration, Inc. SCHLUMBERGER WELL SERVICES 6-JAN-99 BIT RUN 1 98618 RA TH ER T /DA~4~ LOCKWOOD BIT RUN 2 BIT RUN 3 6 13N iOE 43.25 10.80 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 24.000 20.000 112.0 12.250 9.675 5600.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JAN-1999 15:23 3RD STRING 8.500 PRODUCTION STRING REMARKS: CONTAINED HEREIN IS THE LDWG FORMATTED CDR AND ADN LWD DATA AQUIRED ON BP EXPLORATION'S MPF-80 WELL. THE DATA WAS AQUIRED IN THREE BIT RUNS. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE · FLIC VERSION : O01CO1 DATE · 99/01/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENUMBER: 1 EDITED MERGEDMWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: O. 5000 FILE SUMMARY LDWG TOOL CODE $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 13428.0 122.0 BASELINE DEPTH .............. 88888.0 13228.0 13226.5 13207.5 13191.0 13188.0 13186.0 13174.5 13159.0 13146.0 13102 5 13098 5 13059 5 12990 5 12968 5 12958 0 12932 0 12925 0 .......... EQUIVALENT UNSHIFTED DEPTH .......... ....... 88910 0 13250 0 13247 5 13228 5 13213 5 13210 5 13207 0 13196 0 13180 0 13167 0 13124.0 13120.5 13081.5 13011.0 12990.5 12979.5 12953.5 12945.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12915.0 12905.5 12888.0 12800 5 12768 0 12751 5 12745 0 12727 0 12710 5 12621 5 12611 5 12586 0 12579 5 12570 5 12561.5 12555.0 12551.0 12543.0 12541.5 12540.5 12533.5 12526.0 12520.5 12515.0 12475.5 12462.0 12442.5 12430.5 12419.0 12408.0 12353.0 12203.0 12187.0 12173.5 12159.0 12050.5 12046.0 12030.5 12016.5 12004.0 11997 0 11969 0 11962 5 11947 0 11930 0 11874 0 11867 5 11843.5 11810.0 11808.0 11790.5 11756.0 11736.5 11660.5 11636.5 12934.0 12925.5 12909.5 12820.5 12789.0 12769.5 12761.5 12746.5 12730.5 12640.5 12632.0 12601.5 12597.5 12589.0 12579.5 12573.5 12570.0 12561.5 12559.0 12557.5 12551.0 12544.0 12539.0 12535.5 12490.5 12479 5 12459 0 12448 0 12438 0 12426 5 12370 0 12219 0 12202 0 12191.5 12180.5 12068.5 12063.5 12048.0 12038.0 12026.0 12017.5 11989.5 11981.0 11966.5 11949.0 11891.5 11887.0 11861.5 11829.5 11826.5 11810.5 11773.0 11756.0 11674.5 11651.5 25-JAN-1999 15:23 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 11619.0 11608.5 11561.5 11545.0 11536.5 11527.0 11502.0 11496.0 11274.0 11255.5 11228.0 11216.5 11203.5 11176.0 11160 5 11158 5 11153 0 11116 5 11078 0 11070 0 11037 5 11032 0 11025 5 11018 0 10974 0 10922 0 10851 0 10845 0 10842.0 10837.0 10813.5 10799.5 10787.5 10687.0 10661.0 10575.5 10532.0 10517.0 10441.5 10414.0 10407.0 10374.5 10232.5 10226.5 10089.5 10046.0 10042.5 10003.5 9980.5 9862.0 9847.5 9801.0 9780.5 9708.0 9697.0 11636.5 11627.5 11578.5 11561.5 11555.0 11544.0 11517.0 11512.5 11292.5 11270.0 11241.0 11231.0 11219.0 11191.5 11174.5 11172.0 11166.5 11131.0 11094.5 11088.5 11055.0 11050.5 11042.5 11035.5 10989.5 10938.5 10871.0 10863 0 10860 5 1O858 5 10831 5 10817 0 1O805 5 10704 5 10678 5 10590 5 10547 0 10534 0 10457 5 10427 0 10423 0 10392.0 10250.5 10246.5 10112.0 10069.5 10065.0 10024.0 10001.5 9878.5 9861.5 9812.5 9791.5 9712.5 9702.0 25-JAN-1999 15:23 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 9672.5 9617.5 9585.5 9503.5 9491.5 9451.5 9407.5 9402.5 9376.5 9366.5 9352.0 9329.5 9305.0 9269.5 9260.0 9227.0 9212.0 9184 5 9124 0 9110 0 9071 5 9068 5 9059 0 8972 5 8962 5 8937 0 8931 0 8905.0 8901.5 8898.0 8875.5 8868.5 8794.5 8790.5 8694.0 8685.0 8678.5 8672.5 8657.0 8622.5 8599.0 8586.5 8505.0 8491.0 8489.5 8472.5 8462.0 8425.0 8397.5 8380.0 8344.0 8338.0 8329.5 8285.5 8231.0 9675.5 9620.5 9590 0 9517 5 9505 0 9459 0 9415 0 9411 0 9384 5 9375 5 93 60 5 9339 5 9313 5 9275 0 9267.0 9240.0 9223.5 9194.5 9135.5 9122.0 9083.0 9081.0 9068.5 8982.0 8970.5 8943.5 8937.5 8913.5 891 O. 5 8906.5 8884.5 8877.0 8803.5 8797.5 8704.0 8693.5 8688.5 8680.5 8667.0 8632.0 8608 5 8598 5 8518 0 8501 0 8498 5 8482 0 8469 0 8431 0 8401 0 8384 5 8348 0 8341 5 8334 0 8294 0 8239 0 25-JAN-1999 15:23 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JAN-1999 15:23 PAGE: 8204.5 8168.0 8165.0 8148.0 8127.5 8097.5 8076.5 8052.0 100.0 $ MERGED DATA SOURCE LDWG TOOL CODE .............. $ REMARKS: 8213.5 8177.0 8173.0 8158.5 8137.0 8108.0 8087.5 8062.0 106.0 BIT RUN NO. MERGE TOP MERGE BASE 1 122.0 5520.0 2 5520.0 9400.0 3 9400.0 13366.0 THIS FILE CONTAINS THE EDITED DATA. THE CURVES ARE MERGED AT THE DEPTHS SHOWN ABOVE. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN THE MWD GR AND THE GR LOG AQUIRED BY SCHLUMBERGER ON 07-DEC-98. ALL LWD CURVES ARE CARRIED WITH THE GR SHIFTS. NOT ALL DEPTH SHIFTS APLLIED ARE SHOWN ABOVE BECAUSE THEIR NUMBER EXCEEDS THE BUFFER SIZE OF THE HEADER PROGRAM. THE GR AND ROP DATA ARE INTERPOLATED AND DESPIKED OVER THE BIT RUN 1 INTERVAL. THE RESISTIVITY CURVES ARE QRO PROCESSED. LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 80 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JAN-1999 15:23 PAGE: 7 TYPE REPR CODE VALUE 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 1 1 1 4 68 0000000000 FET MWD HR O0 000 O0 0 1 1 1 4 68 0000000000 RA MWD OH~4~ O0 000 O0 0 1 1 1 4 68 0000000000 RP MWD OHIO4 O0 000 O0 0 1 1 1 4 68 0000000000 VRA MWD OHi~ O0 000 O0 0 1 1 1 4 68 0000000000 VRP MWD OtH~4 O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD FPHR O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI O0 000 O0 0 1 1 1 4 68 0000000000 RHO1 MWD G/C3 O0 000 O0 0 1 1 1 4 68 0000000000 RH02 MWD G/C3 O0 000 O0 0 1 1 1 4 68 0000000000 RH03 MWD G/C3 O0 000 O0 0 1 1 1 4 68 0000000000 RH04 MWD G/C3 O0 000 O0 0 1 1 1 4 68 0000000000 DRHOMWD G/C3 O0 000 O0 0 1 1 1 4 68 0000000000 PEF ~D BN/E O0 000 O0 0 1 1 1 4 68 0000000000 DCALMWD IN O0 000 O0 0 1 1 1 4 68 0000000000 CALSMWD IN O0 000 O0 0 1 1 1 4 68 0000000000 CALAMWD IN O0 000 O0 0 1 ! 1 4 68 0000000000 NPHIMWD PU-S O0 000 O0 0 1 1 1 4 68 0000000000 NRATMWD O0 000 O0 0 1 1 t 4 68 0000000000 TRPMMWD RPM O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 13428.000 FET.MWD -999.250 RA.MWD -999.250 RP.MWD -999.250 VRA.MWD -999.250 VRP.MWD -999.250 ROP.MWD 95.230 GR.MWD -999.250 RHO1.MWD -999.250 RHO2.MWD -999.250 RHO3.MWD -999.250 RHO4.MWD -999.250 DRHO.~D -999.250 PEF.MWD -999.250 DCAL.MWD -999.250 CALS.MWD -999.250 CALA.MWD -999.250 NPHI.MWD -999.250 iVRAT.MWD -999.250 TRPM.MWD -999.250 DEPT. 128.000 FET.MWD -999.250 RA.MWD -999.250 RP.~4WD -999.250 VRA.MWD -999.250 VRP.MWD -999.250 ROP.~D 214.130 GR.MWD -999.250 RHO1.MWD -999.250 RHO2.MWD -999.250 RHO3.MWD -999.250 RHO4.MWD -999.250 DRHO.MP~ -999.250 PEF.MWD -999.250 DCAL.~4~D -999.250 CALS.MWD -999.250 CALA.~D -999.250 NPHI.MWD -999.250 NRAT.MWD -999.250 TRPM.MWD -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JA1~-1999 15:23 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 99/01/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 99/01/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: O. 5000 FILE StC4MARY VENDOR TOOL CODE START DEPTH ~fWD 112.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWATHOLE SOFT~gARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 5600.0 08-NOV-98 5.1-12 5.0C REAL-TIME 13408.0 112.0 13408.0 0.0 70.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NTJMBER GR GA~A RAY MiO 038 CDR RESISTIVITY CDR 7077 ADN AZIMUTHAL DENS NEUTRON ADN 113 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JAN-1999 15:23 PAGE: BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : 24. 000 112.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHNk4) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TE~fPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): LSND 9.10 800.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): E%~R FREQUENCY (HZ): 20000 REMARKS: ************ RUN1 12.25 in Hole Run 1:112 ft to 5628 ft bfDC 038 Software: I~DC v5.0c Gamma Ray corrected for hole size and mud weight Data in real time only. ************ RUN2 ************* 8.5 in Hole Run 2:5628 - 9445 ft MDC 368, CDR 7077 Software: MDC vS. Oc, CDR vS. Oc IDEAL v5.1-12 Gamma Ray corrected for hole size and mud weight. Data from downhole tool memory. ************ RUN3 ************* 8.5 in Hole Run 3: 9445 ft to 13408 ft MDC 068, CDR 7045, ADN 113 Software: MDC vS.0c, CDR vS.0c, ADN v4.0 IDEAL v5.1-12 sources: gsrjaO126/csrja2042 TNPH corrected for hole size, hydrogen index, mud salinity, and temperature. Gamma Ray corrected for hole size and mud weight. Data from downhole tool memory. Thank you for using Anadrill-Schlumberger. THIS FILE CONTAINS THE RAW DATA FOR BIT RUN #1. LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JAN-1999 15:23 PAGE 10 $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 16 4 66 255 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 64 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 2 1 1 4 68 0000000000 GRRW LW1 GAPI O0 000 O0 0 2 1 1 4 68 0000000000 GRIN LW1 GAPI O0 000 O0 0 2 1 1 4 68 0000000000 ROP5 LW1 F/HR O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 112.000 GRRW. LW1 -999.250 GRIN. LWl -999.250 ROP5.LW1 DEPT. 5600. 000 GRRW. LW1 -999. 250 GRIN. LW1 -999. 250 ROP5. LW1 -999.250 82. 570 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JAN-1999 15:23 PAGE: 11 **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 99/01/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 99/01/ 6 MA~REC SIZE : 1024 FILE TYPE : LO LAST FILE FILE HEADER FILE NIIMBER 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: O. 5000 FILE SUM~IARY VENDOR TOOL CODE START DEPTH ~ 954.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DO~VHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 9445.0 08-NOV-98 5.1-12 5. OC REAL- TIM~ 13408.0 112.0 13408.0 68.8 76.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAF~MA RAY CDR RESISTIVITY ADN AZIMUTHAL DENS NEUTRON TOOL NUMBER MiO 038 CDR 7077 ADN 113 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JAN-1999 15:23 PAGE: 12 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : 24.000 112.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (0H~94) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): LSND 9.20 600.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 20000 REMARKS: 12.25 in Hole Run 1: 112 ft to 5628 ft ~DC 038 Software: f4DC vS.0c Gamma Ray corrected for hole size and mud weight Data in real time only. 8.5 in Hole Run 2:5628 - 9445 ft ~DC 368, CDR 7077 Software: ~JgC vS.0c, CDR vS.0c IDEAL v5.1-12 Gamma Ray corrected for hole size and mud weight. Data from down_hole tool memory. 8.5 in Hole Run 3: 9445 ft to 13408 ft ~!DC 068, CDR 7045, ADN 113 Software: MDC vS.0c, CDR vS.0c, ADN v4.0 IDEAL v5.1-12 sources: gsrjaO126/csrja2042 TNPH corrected for hole size, hydrogen index, mud salinity, and temperature. Gamma Ray corrected for hole size and mud weight. Data from downhole tool memory. Thank you for using Anadrill-Schlumberger. THIS FILE CONTAINS THE RAW DATA FOR BIT RUN#2. LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JAN-1999 15:23 PAGE: 13 $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 24 4 66 255 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 42 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 3 1 1 4 68 0000000000 TVDE LW2 FT O0 000 O0 0 3 1 1 4 68 0000000000 ROP5 LW2 F/HR O0 000 O0 0 3 1 1 4 68 0000000000 ATR LW2 OHNk4 O0 000 O0 0 3 1 1 4 68 0000000000 PSR LW2 OHiV~I O0 000 O0 0 3 1 1 4 68 0000000000 GR LW2 GAPI O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 954.000 TVDE.LW2 PSR.L~ 2000.000 GR.LW2 965.417 ROP5.LW2 9578.352 ATR.LW2 34.541 DEPT. PSR.LW2 9445.000 TVDE.LW2 4922.200 ROPS.LW2 3.254 GR,LW2 88.411 98,398 ATR.LW2 O. 097 2. 854 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JAN-1999 15:23 PAGE: 14 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION . O01CO1 DATE · 99/01/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 99/01/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE AFUblBER 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: O. 5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH bfWD 904.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOF2~¢ARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH .......... 13408.0 08-NOV-98 5.1-12 5.0C MEMORY 13408.0 112.0 13408.0 25.8 76.3 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JAN-1999 15:23 PAGE: 15 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GR GAIV~zA RAY MiO 038 CDR RESISTIVITY CDR 7077 ADN AZIMUTHAL DENSNEUTRON ADN 113 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): 24. 000 112.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OPflvfl~) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): LSND 10.20 400 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): SANDSTONE 2.65 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 20000 REMARKS: Run 1: 112 ft to 5628 ft ~DC 038 Software: I4DC vS.0c Gamma Ray corrected for hole size and mud weight Data in real time only. ************ RUN2 ************* 8.5 in Hole Run 2:5628 - 9445 ft b!DC 368, CDR 7077 Software: b¢~C v5.0c, CDR vS.0c IDEAL v5.1-12 Gamma Ray corrected for hole size and mud weight. Data from downhole tool memory. ************ RUN3 ************* 8.5 in Hole Run 3: 9445 ft to 13408 ft MDC 068, CDR 7045, ADN 113 Software: ~DC vS.0c, CDR vS.0c, ADN v4.0 IDEAL v5.1-12 sources: gsrjaO126/csrja2042 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JAN-1999 15:23 PAGE: 16 TNPH corrected for hole size, hydrogen index, mud salinity, and temperature. Gamma Ray corrected for hole size and mud weight. Data from downhole tool memory. Thank you for using Anadrill-Schlumberger. THIS FILE CONTAINS THE RAW DATA FOR BIT RUN #3. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 120 4 66 255 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 8 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 4 ! 1 4 68 0000000000 TVDE LW3 FT O0 000 O0 0 4 1 1 4 68 0000000000 ROP$ LW3 F/HR O0 000 O0 0 4 1 1 4 68 0000000000 ATR LW3 OHNk4 O0 000 O0 0 4 1 1 4 68 0000000000 PSR LW3 OH~4 O0 000 O0 0 4 ! t 4 68 0000000000 GR LW3 GAPI O0 000 O0 0 4 i 1 4 68 0000000000 TABD LW3 O0 000 O0 0 4 i 1 4 68 0000000000 DRHB LW3 G/C3 O0 000 O0 0 4 i 1 4 68 0000000000 DRHL LW3 G/C3 O0 000 O0 0 4 1 t 4 68 0000000000 DRHU LW3 G/C3 O0 000 O0 0 4 1 1 4 68 0000000000 DRHR LW3 G/C3 O0 000 O0 0 4 1 1 4 68 0000000000 PEB LW3 O0 000 O0 0 4 t 1 4 68 0000000000 PEL LW3 O0 000 O0 0 4 1 t 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JAN-1999 15:23 PAGE: 17 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) PEU LW3 O0 000 O0 0 4 1 1 4 68 0000000000 PER LW3 O0 000 O0 0 4 1 1 4 68 0000000000 ROBB LW3 G/C3 O0 000 O0 0 4 1 1 4 68 0000000000 ROBL LW3 G/C3 O0 000 O0 0 4 1 1 4 68 0000000000 ROBU LW3 G/C3 O0 000 O0 0 4 1 1 4 68 0000000000 ROBR LW3 G/C3 O0 000 O0 0 4 1 1 4 68 0000000000 UB LW3 O0 000 O0 0 4 1 1 4 68 0000000000 DCAL LW3 IN O0 000 O0 0 4 1 1 4 68 0000000000 TN-RALW3 O0 000 O0 0 4 1 1 4 68 0000000000 RPM LW3 RPM O0 000 O0 0 4 1 1 4 68 0000000000 VDIA LW3 IN O0 000 O0 0 4 1 1 4 68 0000000000 HDIA LW3 IN O0 000 O0 0 4 1 1 4 68 0000000000 DPHB LW3 PU O0 000 O0 0 4 1 1 4 68 0000000000 DPHU LW3 PU O0 000 O0 0 4 1 1 4 68 0000000000 DPHL LW3 PU O0 000 O0 0 4 1 1 4 68 0000000000 DPHR LW3 PU O0 000 O0 0 4 1 1 4 68 0000000000 TNPH LW3 PU O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 904.500 TVDE.LW3 1010.600 ROPS.LW3 4370.972 ATR.LW3 PSR.LW3 64.250 GR.LW3 34.376 TABD.LW3 O. 000 DRHB.LW3 DRHL.LW3 -0.238 DRHU. LW3 -0.256 DRHR.LW3 -0.239 PEB.LW3 PEL.LW3 19.361 PEU. LW3 15.298 PER.LW3 20.338 ROBB.LW3 ROBL. LW3 2. 084 ROBU. LW3 2 . 108 ROBR. LW3 2. 135 UB. LW3 DCAL.LW3 0.176 TNRA.LW3 28.176 RPM. LW3 0.000 VDIA.LW3 HDIA.LW3 7. 868 DPHB.LW3 36.275 DPHU. LW3 32. 870 DPHL.LW3 DPHR. LW3 31 . 220 TNPH. LW3 53. 856 DEPT. 13408. 000 TVDE.LW3 7178. 384 ROPS.LW3 87. 359 ATR.LW3 PSR.LW3 3. 067 GR.LW3 97. 955 TABD.LW3 6000. 406 DRHB.LW3 DRHL.LW3 O. 054 DRHU. LW3 O. 075 DRHR.LW3 O. 074 PEB.LW3 PEL.LW3 4.870 PEU. LW3 5. 488 PER.LW3 5.193 ROBB.LW3 ROBL. LW3 2 . 433 ROBU. LW3 2. 446 ROBR. LW3 2. 469 UB. LW3 DCAL.LW3 0.133 TNRA.LW3 23.815 RPM. LW3 105.667 VDIA.LW3 HDIA.LW3 8. 793 DPHB.LW3 10. 002 DPHU. LW3 12. 383 DPHL.LW3 D PHR . LW3 10. 990 TNPH . LW3 40. 951 0.127 -0.243 19.332 2. 051 40. 451 8. 868 34.274 3. 589 0. 077 4. 938 2. 485 12.331 8. 831 13.146 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-JAN-1999 15:23 PAGE: 18 **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE · FLIC VERSION . O01CO1 DATE . 99/01/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE . 99/01/ 6 ORIGIN · FLIC TAPE NAME : 98618 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT · BP EXPLORATION, MILNE POINT, MPF-80, API #50-029-22928-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 99/01/ 6 ORIGIN · FLIC REEL NAME · 98618 CONTINUATION # : PREVIOUS REEL : CO~k4ENT . BP EXPLORATION, MILNE POINT, MPF-80, API #50-029-22928-00 Sperry-Sun Drillin9 Services LIS Scan Utility Wed Dec 09 14:37:54 1998 Reel Header Service name ............. LISTPE Date ..................... 98/12/09 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 98/12/09 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT, MWD/MAD LOGS WELL NAME: API NUMBER: OPER31TOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA TARN POOL JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: MWD RUN 2 AK-MM-80359 R. KRELL D. HE IM 2N-331 501032026500 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 09-DEC-98 3 09N 07E 96 909 148.80 147.30 120.90 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 16.000 108.0 9.875 7.625 3841.0 6.750 11225.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL ONLY AND IS NOT PRESENTED. 3. MWD RUNS 2 IS DIRECTIONAL WITH DUAL GAMMA P~AY (DGR), ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4), COMPENSATED THERMAL NEUTRON POROSITY (CTN) AND STABILIZED LITHO-DENSITY (SLD) . 4. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE E-MAIL MESSAGE FROM DOUG HASTINGS OF ARCO ALASKA, INC. ON 22 OCTOBER, 1998. SPERRY-SUN MWD DATA IS PRIMARY DEPTH CONTROL (PDC) FOR WELL 2N-331. 5. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11225'MD, 5264'TVD. SROP = SMOOTHED P~ATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA HAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SPSF = SMOOTHED COMPENSATED NEUTRON POROSITY (SAAIDSTONE MATRIX-FIXED HOLE SIZE). SNNA = SMOOTHED AVERAGE OF NEAR DETECTORS' COUNT HATES. SNFA = SMOOTHED AVERAGE OF FAR DETECTORS' COUNT RATES. SBD2 = SMOOTHED BULK DENSITY (HAPID SAMPLE METHOD). SCO2 = SMOOTHED STANDOFF CORRECTION (RAPID SAMPLE METHOD). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR. ENVIRONMENTAL PAlq3LMETERS USED IN PROCESSING NUCLEAR/NEUTRON LOG DATA: MATRIX: SANDSTONE FIXED HOLE SIZE: 6.75" MUD WEIGHT: 9.1 TO 10.0 ppg MUD SALINITY: 500-750 CL- ppm FORMATION WATER SALINITY: 19,149 CL- ppm $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/12/09 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE START GR 3774 RPD 3840 RPM 3840 RPS 3840 RPX 3840 PEF 3843 DRHO 3843 RHOB 3843 FCNT 3849 NCNT 3849 NPHI 3849 FET 3851 ROP 3871 $ DEPTH 5 0 0 0 0 0 0 0 5 5 5 5 5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: STOP DEPTH 11130 0 '11137 0 11137 0 11137 0 11137 0 11117 0 10519 5 10519 5 11101 0 11101 0 11101 0 11137 0 11224 5 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 2 3871.0 11225.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order DEPT GR MWD RPD MWD ROP MWD FET MWD RPX MWD RPS MWD RPM MWD NPHI MWD FCNT MWD NCNT MWD RHOB MWD DRHO MWD PEF MWD Units Size Nsam Rep FT 4 1 68 API 4 1 68 OHMM 4 1 68 FT/H 4 1 68 HOUR 4 1 68 OHMM 4 1 68 OHMM 4 1 68 OHMM 4 1 68 PU 4 1 68 CNTS 4 1 68 CNTS 4 1 68 GM/C 4 1 68 GM/C 4 1 68 BARN 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name DEPT GR RPD ROP FET RPX RPS RPM NPHI FCNT NCNT RHOB DRHO PEF Min 3774.5 38.9 1 01 0 26 0 48 1 04 0 83 0 33 12 92 150.7 18870.6 1.85 -0.41 0.08 Max Mean Nsam 11224.5 7499.5 14901 216.33 121.094 14712 2000 6.37682 14595 934.03 191.636 14707 9.74 1.2348 14572 1784.5 5.1634 14595 1329.02 5.37291 14595 2000 5.75604 14595 52.14 39.9441 14504 989.95 217.857 14504 42491.8 24431.6 14504 3.06 2.3297 13354 0.6 0.0432335 13354 12.99 3.4922 14549 First Reading 3774.5 3774.5 3840 3871.5 3851.5 3840 3840 3840 3849.5 3849.5 3849.5 3843 3843 3843 Last Reading 11224.5 11130 11137 11224.5 11137 11137 11137 11137 11101 11101 11101 10519.5 10519.5 11117 First Reading For Entire File .......... 3774.5 Last Reading For Entire File ........... 11224.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/12/09 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 ' Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/12/09 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 R3~W MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 3774.5 RPD 3840 0 RPM 3840 0 RPS 3840 0 RPX 3840 0 PEF 3843 0 DRHO 3843 0 RHOB 3843 0 FCNT 3849 5 NCNT 3849 5 NPHI 3849 5 FET 3851 5 ROP 3871 5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS STOP DEPTH 11130 0 11137 0 11137 0 11137 0 11137 0 11117 0 10519 5 10519 5 11101 0 11101.0 11101.0 11137.0 11224.5 09-SEP-98 INSITE 3.2.12.3 CIM 5.46,SP4 5.16,SLD 10.87 MEMORY 11225.0 3871.0 11225.0 54.7 70.7 TOOL NLTMBER P1080GRM4 P1080GRM4 P1080GRM4 P1080GRM4 6.750 6.8 MUD TYPE: MUD DENSITY (LB/G): MIID VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT M3IX CIRCULATING TERMPEthATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 LSND 10.00 48.0 9.0 550 3.8 2.100 1.290 4.800 2. 900 .5 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 2 FT/H 4 1 68 4 2 GR MWD 2 API 4 1 68 8 3 RPX MWD 2 OHMM 4 1 68 12 4 RPS MWD 2 OHMM 4 1 68 16 5 RPM MWD 2 OHMM 4 1 68 20 6 RPD MWD 2 OHMM 4 1 68 24 7 FET MWD 2 HOUR 4 1 68 28 8 NPHI MWD 2 P.U. 4 1 68 32 9 FCNT MWD 2 CNTS 4 1 68 36 10 NCNT MWD 2 CNTS 4 1 68 40 11 RHOB MWD 2 G/CC 4 1 68 44 12 DRHO MWD 2 G/CC 4 1 68 48 13 PEF MWD 2 BARN 4 1 68 52 14 47.8 First Name Min Max Mean Nsam Reading DEPT 3774.5 11224.5 7499.5 14901 3774.5 ROP 0.26 934.03 191.636 14707 3871.5 Last Reading 11224.5 11224.5 GR RPX RPS RPM RPD FET NPHI FCNT NCNT RHOB DRHO PEF 1 1 188 38.9 1 04 0 83 0 33 1 01 0 48 2 92 50.7 70.6 1.85 0.41 0.08 216.33 121.094 14712 1784.5 5.1634 14595 1329.02 5.37291 14595 2000 5.75604 14595 2000 6.37682 14595 9.74 1.2348 14572 52.14 39.916 14410 989.95 218.212 14410 42491.8 24454.2 14410 3.06 2.3297 13354 0.6 0.0432335 13354 12.99 3.4922 14549 3774.5 11130 3840 11137 3840 11137 3840 11137 3840 11137 3851.5 11137 3849.5 11101 3849.5 11101 3849.5 11101 3843 10519.5 3843 10519.5 3843 11117 First Reading For Entire File .......... 3774.5 Last Reading For Entire File ........... 11224.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/12/09 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/12/09 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 98/12/09 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File