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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: OPERABLE: Injector N-27 (PTD # 2071040) TxIA resolved Date:Tuesday, February 17, 2026 8:20:32 AM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Monday, February 9, 2026 12:36 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: OPERABLE: Injector N-27 (PTD # 2071040) TxIA resolved Mr. Wallace, As injection rates have stabilized, no observable TxIA communication was present. The well will now be classified as OPERABLE. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307) 399-3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, January 13, 2026 5:33 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <oliver.sternicki@hilcorp.com>; Torin Roschinger <torin.roschinger@hilcorp.com> Subject: UPDATE UNDER EVALUATION: Injector N-27 (PTD # 2071040) Additional 28 days monitoring Mr. Wallace, WAG injector N-27 (PTD #2071040) AOGCC MIT-IA passed on 01/02. The gas injection rate has not stabilized to determine if the well has slow TxIA communication. The AOGCC has agreed to reset the under evaluation clock for an additional 28 days of monitoring. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, December 16, 2025 5:28 PM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <oliver.sternicki@hilcorp.com>; Torin Roschinger <torin.roschinger@hilcorp.com> Subject: UPDATE UNDER EVALUATION: Injector N-27 (PTD # 2071040) Additional 28 days monitoring Mr. Wallace, WAG injector N-27 (PTD #2071040) per previous correspondence, the under evaluation has been reset to accommodate an additional 28 days of online monitoring post DGLV. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Wednesday, November 19, 2025 4:21 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <oliver.sternicki@hilcorp.com>; Torin Roschinger <torin.roschinger@hilcorp.com> Subject: UNDER EVALUATION: Injector N-27 (PTD # 2071040) TxIA communication All, WAG injector N-27 (PTD #2071040) IA pressure was found at ~1000 psi on 11/19. During DHD bleed, the IA liquid level was found to be at ~180’. The well is now classified as UNDER EVALUATION for slow TxIA communication and on a 28 day clock to be resolved. Plan Forward: 1. Slickline: Set extended packing DGLV 2. Well Integrity: Monitor IA re-pressurization / Further action as needed. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Wednesday, January 10, 2018 9:55 AM To: 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; AK, OPS GC2 Facility OTL <AKOPSGC2FacilityOTL@bp.com>; AK, OPS GC2 Field O&M TL <AKOPSGC2FieldOMTL1@bp.com>; AK, OPS GC2 OSM <AKOPSGC2OSM@bp.com>; AK, OPS GC2 Wellpad Lead <AKOPSGC2WellpadLead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS Prod Controllers <akopsprodcontrollers1@bp.com>; AK, OPS Well Pad HUQ <AKOPSWellPadHUQ@bp.com>; AK, OPS Well Pad LV <AKOPSWellPadLV@bp.com>; AK, OPS Well Pad MN <AKOPSWellPadMN@bp.com>; AK, OPS Well Pad RJ <AKOPSWellPadRJ@bp.com>; AK, OPS WELL PAD S <AKOPSWELLPADS@bp.com>; AK, OPS Well Pad SW <AKOPSWellPadSW@bp.com>; AK, OPS WELL PAD W <AKOPSWELLPADW@bp.com>; AK, OPS Well Pad Z <AKOPSWellPadZ@bp.com>; Ak, Ops West Area TL <AkOpsWestAreaTL@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; Bergene, Matthew <Matthew.Bergene@bp.com>; Frankenburg, Amy <Amy.Frankenburg@bp.com> Cc: 'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov>; AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWellIntegri@bp.com>; AK, GWO Projects Well Integrity <AKDCProjectsWellIntegrityEngineer@bp.com>; AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dempsey1@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Munk, Corey <Corey.Munk@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; O'connor, Katherine <Katherine.O'connor@bp.com>; Romo, Louis A <Louis.Romo@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Tempel, Joshua <Joshua.Tempel@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com> Subject: OPERABLE: Injector N-27 (PTD # 2071040) Injector Conversion All, Injector N-27 (PTD #2071040) is an Injector Conversion that is ready to be put on injection. Sundry #317-423 has been approved this conversion. The well is now classified as OPERABLE. Plan forward: 1. Operations: Put on injection 2. DHD – AOGCC witnessed MIT-IA once well is thermally stable Please respond with any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization – Alaska Office: 907-659-8110 Cell: 307-399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. W.H: N-D TIO Plot 190 180 Tubing 170 — On 160 3 ■ Bleed 150, #- Operable + Not Oper 140 a Under Eval 130 ■ Man. IA 120 —� Man. OA Man. -A 110 Man. OOOA %00 Man. WHT 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: UPDATE UNDER EVALUATION: Injector N-27 (PTD # 2071040) Additional 28 days monitoring Date:Tuesday, January 13, 2026 8:03:00 AM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, January 13, 2026 5:33 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UPDATE UNDER EVALUATION: Injector N-27 (PTD # 2071040) Additional 28 days monitoring Mr. Wallace, WAG injector N-27 (PTD #2071040) AOGCC MIT-IA passed on 01/02. The gas injection rate has not stabilized to determine if the well has slow TxIA communication. The AOGCC has agreed to reset the under evaluation clock for an additional 28 days of monitoring. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, December 16, 2025 5:28 PM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <oliver.sternicki@hilcorp.com>; Torin Roschinger <torin.roschinger@hilcorp.com> Subject: UPDATE UNDER EVALUATION: Injector N-27 (PTD # 2071040) Additional 28 days monitoring Mr. Wallace, WAG injector N-27 (PTD #2071040) per previous correspondence, the under evaluation has been reset to accommodate an additional 28 days of online monitoring post DGLV. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Wednesday, November 19, 2025 4:21 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <oliver.sternicki@hilcorp.com>; Torin Roschinger <torin.roschinger@hilcorp.com> Subject: UNDER EVALUATION: Injector N-27 (PTD # 2071040) TxIA communication All, WAG injector N-27 (PTD #2071040) IA pressure was found at ~1000 psi on 11/19. During DHD bleed, the IA liquid level was found to be at ~180’. The well is now classified as UNDER EVALUATION for slow TxIA communication and on a 28 day clock to be resolved. Plan Forward: 1. Slickline: Set extended packing DGLV 2. Well Integrity: Monitor IA re-pressurization / Further action as needed. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Wednesday, January 10, 2018 9:55 AM To: 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; AK, OPS GC2 Facility OTL <AKOPSGC2FacilityOTL@bp.com>; AK, OPS GC2 Field O&M TL <AKOPSGC2FieldOMTL1@bp.com>; AK, OPS GC2 OSM <AKOPSGC2OSM@bp.com>; AK, OPS GC2 Wellpad Lead <AKOPSGC2WellpadLead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS Prod Controllers <akopsprodcontrollers1@bp.com>; AK, OPS Well Pad HUQ <AKOPSWellPadHUQ@bp.com>; AK, OPS Well Pad LV <AKOPSWellPadLV@bp.com>; AK, OPS Well Pad MN <AKOPSWellPadMN@bp.com>; AK, OPS Well Pad RJ <AKOPSWellPadRJ@bp.com>; AK, OPS WELL PAD S <AKOPSWELLPADS@bp.com>; AK, OPS Well Pad SW <AKOPSWellPadSW@bp.com>; AK, OPS WELL PAD W <AKOPSWELLPADW@bp.com>; AK, OPS Well Pad Z <AKOPSWellPadZ@bp.com>; Ak, Ops West Area TL <AkOpsWestAreaTL@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; Bergene, Matthew <Matthew.Bergene@bp.com>; Frankenburg, Amy <Amy.Frankenburg@bp.com> Cc: 'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov>; AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWellIntegri@bp.com>; AK, GWO Projects Well Integrity <AKDCProjectsWellIntegrityEngineer@bp.com>; AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dempsey1@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Munk, Corey <Corey.Munk@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; O'connor, Katherine <Katherine.O'connor@bp.com>; Romo, Louis A <Louis.Romo@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Tempel, Joshua <Joshua.Tempel@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com> Subject: OPERABLE: Injector N-27 (PTD # 2071040) Injector Conversion All, Injector N-27 (PTD #2071040) is an Injector Conversion that is ready to be put on injection. Sundry #317-423 has been approved this conversion. The well is now classified as OPERABLE. Plan forward: 1. Operations: Put on injection 2. DHD – AOGCC witnessed MIT-IA once well is thermally stable Please respond with any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization – Alaska Office: 907-659-8110 Cell: 307-399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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:PB Wells Integrity Subject:RE: UPDATE UNDER EVALUATION: Injector N-27 (PTD # 2071040) Additional 28 days monitoring Date:Monday, January 12, 2026 11:34:50 AM Attachments:N-27.docx Ryan, Your request for an additional 28 days for monitoring and diagnostics is approved. 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: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Monday, January 12, 2026 10:12 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject: UPDATE UNDER EVALUATION: Injector N-27 (PTD # 2071040) Additional 28 days monitoring Mr. Wallace, WAG injector N-27 (PTD #2071040) 28 day monitoring period is set to end on 12/13. Injection pressure / casing pressure trends suggest there is no TxIA communication post setting DGLV and performing AOGCC witnessed MIT-IA on 01/02. However, injection pressure has not been static over the past weeks and continues to increase towards recommended injection rate. With permission, I would like to extend the Under Evaluation period for an additional 28 days to continue monitoring. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, December 16, 2025 5:28 PM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <oliver.sternicki@hilcorp.com>; Torin Roschinger <torin.roschinger@hilcorp.com> Subject: UPDATE UNDER EVALUATION: Injector N-27 (PTD # 2071040) Additional 28 days monitoring Mr. Wallace, WAG injector N-27 (PTD #2071040) per previous correspondence, the under evaluation has been reset to accommodate an additional 28 days of online monitoring post DGLV. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Wednesday, November 19, 2025 4:21 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <oliver.sternicki@hilcorp.com>; Torin Roschinger <torin.roschinger@hilcorp.com> Subject: UNDER EVALUATION: Injector N-27 (PTD # 2071040) TxIA communication All, WAG injector N-27 (PTD #2071040) IA pressure was found at ~1000 psi on 11/19. During DHD bleed, the IA liquid level was found to be at ~180’. The well is now classified as UNDER EVALUATION for slow TxIA communication and on a 28 day clock to be resolved. Plan Forward: 1. Slickline: Set extended packing DGLV 2. Well Integrity: Monitor IA re-pressurization / Further action as needed. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Wednesday, January 10, 2018 9:55 AM To: 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; AK, OPS GC2 Facility OTL <AKOPSGC2FacilityOTL@bp.com>; AK, OPS GC2 Field O&M TL <AKOPSGC2FieldOMTL1@bp.com>; AK, OPS GC2 OSM <AKOPSGC2OSM@bp.com>; AK, OPS GC2 Wellpad Lead <AKOPSGC2WellpadLead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS Prod Controllers <akopsprodcontrollers1@bp.com>; AK, OPS Well Pad HUQ <AKOPSWellPadHUQ@bp.com>; AK, OPS Well Pad LV <AKOPSWellPadLV@bp.com>; AK, OPS Well Pad MN <AKOPSWellPadMN@bp.com>; AK, OPS Well Pad RJ <AKOPSWellPadRJ@bp.com>; AK, OPS WELL PAD S <AKOPSWELLPADS@bp.com>; AK, OPS Well Pad SW <AKOPSWellPadSW@bp.com>; AK, OPS WELL PAD W <AKOPSWELLPADW@bp.com>; AK, OPS Well Pad Z <AKOPSWellPadZ@bp.com>; Ak, Ops West Area TL <AkOpsWestAreaTL@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; Bergene, Matthew <Matthew.Bergene@bp.com>; Frankenburg, Amy <Amy.Frankenburg@bp.com> Cc: 'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov>; AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWellIntegri@bp.com>; AK, GWO Projects Well Integrity <AKDCProjectsWellIntegrityEngineer@bp.com>; AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dempsey1@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Munk, Corey <Corey.Munk@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; O'connor, Katherine <Katherine.O'connor@bp.com>; Romo, Louis A <Louis.Romo@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Tempel, Joshua <Joshua.Tempel@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com> Subject: OPERABLE: Injector N-27 (PTD # 2071040) Injector Conversion All, Injector N-27 (PTD #2071040) is an Injector Conversion that is ready to be put on injection. Sundry #317-423 has been approved this conversion. The well is now classified as OPERABLE. Plan forward: 1. Operations: Put on injection 2. DHD – AOGCC witnessed MIT-IA once well is thermally stable Please respond with any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization – Alaska Office: 907-659-8110 Cell: 307-399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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: UPDATE UNDER EVALUATION: Injector N-27 (PTD # 2071040) Additional 28 days monitoring Date:Wednesday, December 17, 2025 7:45:14 AM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, December 16, 2025 5:28 PM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UPDATE UNDER EVALUATION: Injector N-27 (PTD # 2071040) Additional 28 days monitoring Mr. Wallace, WAG injector N-27 (PTD #2071040) per previous correspondence, the under evaluation has been reset to accommodate an additional 28 days of online monitoring post DGLV. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Wednesday, November 19, 2025 4:21 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <oliver.sternicki@hilcorp.com>; Torin Roschinger <torin.roschinger@hilcorp.com> Subject: UNDER EVALUATION: Injector N-27 (PTD # 2071040) TxIA communication All, WAG injector N-27 (PTD #2071040) IA pressure was found at ~1000 psi on 11/19. During DHD bleed, the IA liquid level was found to be at ~180’. The well is now classified as UNDER EVALUATION for slow TxIA communication and on a 28 day clock to be resolved. Plan Forward: 1. Slickline: Set extended packing DGLV 2. Well Integrity: Monitor IA re-pressurization / Further action as needed. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Wednesday, January 10, 2018 9:55 AM To: 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; AK, OPS GC2 Facility OTL <AKOPSGC2FacilityOTL@bp.com>; AK, OPS GC2 Field O&M TL <AKOPSGC2FieldOMTL1@bp.com>; AK, OPS GC2 OSM <AKOPSGC2OSM@bp.com>; AK, OPS GC2 Wellpad Lead <AKOPSGC2WellpadLead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS Prod Controllers <akopsprodcontrollers1@bp.com>; AK, OPS Well Pad HUQ <AKOPSWellPadHUQ@bp.com>; AK, OPS Well Pad LV <AKOPSWellPadLV@bp.com>; AK, OPS Well Pad MN <AKOPSWellPadMN@bp.com>; AK, OPS Well Pad RJ <AKOPSWellPadRJ@bp.com>; AK, OPS WELL PAD S <AKOPSWELLPADS@bp.com>; AK, OPS Well Pad SW <AKOPSWellPadSW@bp.com>; AK, OPS WELL PAD W <AKOPSWELLPADW@bp.com>; AK, OPS Well Pad Z <AKOPSWellPadZ@bp.com>; Ak, Ops West Area TL <AkOpsWestAreaTL@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; Bergene, Matthew <Matthew.Bergene@bp.com>; Frankenburg, Amy <Amy.Frankenburg@bp.com> Cc: 'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov>; AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWellIntegri@bp.com>; AK, GWO Projects Well Integrity <AKDCProjectsWellIntegrityEngineer@bp.com>; AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dempsey1@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Munk, Corey <Corey.Munk@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; O'connor, Katherine <Katherine.O'connor@bp.com>; Romo, Louis A <Louis.Romo@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Tempel, Joshua <Joshua.Tempel@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com> Subject: OPERABLE: Injector N-27 (PTD # 2071040) Injector Conversion All, Injector N-27 (PTD #2071040) is an Injector Conversion that is ready to be put on injection. Sundry #317-423 has been approved this conversion. The well is now classified as OPERABLE. Plan forward: 1. Operations: Put on injection 2. DHD – AOGCC witnessed MIT-IA once well is thermally stable Please respond with any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization – Alaska Office: 907-659-8110 Cell: 307-399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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: UPDATE UNDER EVALUATION: Injector N-27 (PTD # 2071040) Request extended monitoring period Date:Monday, December 15, 2025 10:43:30 AM From: Wallace, Chris D (OGC) Sent: Monday, December 15, 2025 10:42 AM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: RE: UPDATE UNDER EVALUATION: Injector N-27 (PTD # 2071040) Request extended monitoring period Ryan, Your request for additional 28 days monitoring and diagnostics is approved. 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: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Monday, December 15, 2025 10:32 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: UPDATE UNDER EVALUATION: Injector N-27 (PTD # 2071040) Request extended monitoring period Mr. Wallace, WAG injector N-27 (PTD #2071040) extended packing DGLV were run on 12/06 and the well was put on injection on 12/09. The current 28 day under evaluation period expires on 12/17. With permission, I would like to request an additional 28 days of monitoring starting 12/17 to determine if setting extended packing DGLV has resolved the slow TxIA. If the communication persists, we will perform AOGCC witnessed MIT-IA and apply for AA. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Wednesday, November 19, 2025 4:21 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <oliver.sternicki@hilcorp.com>; Torin Roschinger <torin.roschinger@hilcorp.com> Subject: UNDER EVALUATION: Injector N-27 (PTD # 2071040) TxIA communication All, WAG injector N-27 (PTD #2071040) IA pressure was found at ~1000 psi on 11/19. During DHD bleed, the IA liquid level was found to be at ~180’. The well is now classified as UNDER EVALUATION for slow TxIA communication and on a 28 day clock to be resolved. Plan Forward: 1. Slickline: Set extended packing DGLV 2. Well Integrity: Monitor IA re-pressurization / Further action as needed. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Wednesday, January 10, 2018 9:55 AM To: 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; AK, OPS GC2 Facility OTL <AKOPSGC2FacilityOTL@bp.com>; AK, OPS GC2 Field O&M TL <AKOPSGC2FieldOMTL1@bp.com>; AK, OPS GC2 OSM <AKOPSGC2OSM@bp.com>; AK, OPS GC2 Wellpad Lead <AKOPSGC2WellpadLead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS Prod Controllers <akopsprodcontrollers1@bp.com>; AK, OPS Well Pad HUQ <AKOPSWellPadHUQ@bp.com>; AK, OPS Well Pad LV <AKOPSWellPadLV@bp.com>; AK, OPS Well Pad MN <AKOPSWellPadMN@bp.com>; AK, OPS Well Pad RJ <AKOPSWellPadRJ@bp.com>; AK, OPS WELL PAD S <AKOPSWELLPADS@bp.com>; AK, OPS Well Pad SW <AKOPSWellPadSW@bp.com>; AK, OPS WELL PAD W <AKOPSWELLPADW@bp.com>; AK, OPS Well Pad Z <AKOPSWellPadZ@bp.com>; Ak, Ops West Area TL <AkOpsWestAreaTL@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; Bergene, Matthew <Matthew.Bergene@bp.com>; Frankenburg, Amy <Amy.Frankenburg@bp.com> Cc: 'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov>; AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWellIntegri@bp.com>; AK, GWO Projects Well Integrity <AKDCProjectsWellIntegrityEngineer@bp.com>; AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dempsey1@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Munk, Corey <Corey.Munk@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; O'connor, Katherine <Katherine.O'connor@bp.com>; Romo, Louis A <Louis.Romo@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Tempel, Joshua <Joshua.Tempel@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com> Subject: OPERABLE: Injector N-27 (PTD # 2071040) Injector Conversion All, Injector N-27 (PTD #2071040) is an Injector Conversion that is ready to be put on injection. Sundry #317-423 has been approved this conversion. The well is now classified as OPERABLE. Plan forward: 1. Operations: Put on injection 2. DHD – AOGCC witnessed MIT-IA once well is thermally stable Please respond with any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization – Alaska Office: 907-659-8110 Cell: 307-399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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: UNDER EVALUATION: Injector N-27 (PTD # 2071040) TxIA communication Date:Thursday, November 20, 2025 9:10:45 AM Attachments:N-27.docx From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Wednesday, November 19, 2025 4:21 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UNDER EVALUATION: Injector N-27 (PTD # 2071040) TxIA communication All, WAG injector N-27 (PTD #2071040) IA pressure was found at ~1000 psi on 11/19. During DHD bleed, the IA liquid level was found to be at ~180’. The well is now classified as UNDER EVALUATION for slow TxIA communication and on a 28 day clock to be resolved. Plan Forward: 1. Slickline: Set extended packing DGLV 2. Well Integrity: Monitor IA re-pressurization / Further action as needed. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Wednesday, January 10, 2018 9:55 AM To: 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; AK, OPS GC2 Facility OTL <AKOPSGC2FacilityOTL@bp.com>; AK, OPS GC2 Field O&M TL <AKOPSGC2FieldOMTL1@bp.com>; AK, OPS GC2 OSM <AKOPSGC2OSM@bp.com>; AK, OPS GC2 Wellpad Lead <AKOPSGC2WellpadLead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS Prod Controllers <akopsprodcontrollers1@bp.com>; AK, OPS Well Pad HUQ <AKOPSWellPadHUQ@bp.com>; AK, OPS Well Pad LV <AKOPSWellPadLV@bp.com>; AK, OPS Well Pad MN <AKOPSWellPadMN@bp.com>; AK, OPS Well Pad RJ <AKOPSWellPadRJ@bp.com>; AK, OPS WELL PAD S <AKOPSWELLPADS@bp.com>; AK, OPS Well Pad SW <AKOPSWellPadSW@bp.com>; AK, OPS WELL PAD W <AKOPSWELLPADW@bp.com>; AK, OPS Well Pad Z <AKOPSWellPadZ@bp.com>; Ak, Ops West Area TL <AkOpsWestAreaTL@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; Bergene, Matthew <Matthew.Bergene@bp.com>; Frankenburg, Amy <Amy.Frankenburg@bp.com> Cc: 'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov>; AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWellIntegri@bp.com>; AK, GWO Projects Well Integrity <AKDCProjectsWellIntegrityEngineer@bp.com>; AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dempsey1@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Munk, Corey <Corey.Munk@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; O'connor, Katherine <Katherine.O'connor@bp.com>; Romo, Louis A <Louis.Romo@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Tempel, Joshua <Joshua.Tempel@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com> Subject: OPERABLE: Injector N-27 (PTD # 2071040) Injector Conversion All, Injector N-27 (PTD #2071040) is an Injector Conversion that is ready to be put on injection. Sundry #317-423 has been approved this conversion. The well is now classified as OPERABLE. Plan forward: 1. Operations: Put on injection 2. DHD – AOGCC witnessed MIT-IA once well is thermally stable Please respond with any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization – Alaska Office: 907-659-8110 Cell: 307-399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: (907) 564-4891 06/01/2023 Mr. Mel Rixse Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Prudhoe Bay Surface Casing by Conductor Annulus Top-offs of Cement, Corrosion Inhibitor through 6/1/2023. Dear Mr. Rixse, Enclosed please find a copy of a spreadsheet with a list of Prudhoe Bay wells that were topped-off with cement, corrosion inhibitor in the surface casing by conductor annulus through 6/1/2023. Cement top-offs are executed as needed to mitigate the void space left at surface by minor cement fallback during the primary surface casing by conductor cement job. The remaining void space between the top of the cement and the top of the conductor is filled with a heavier than water corrosion inhibitor to reduce the risk of external surface casing corrosion. The attached spreadsheets include the well names, API and PTD numbers, treatment dates and volumes. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404 Report of Sundry Operations. If you have any additional questions, please contact me at 564-4891 or oliver.sternicki@hilcorp.com. Sincerely, Oliver Sternicki Well Integrity Supervisor Hilcorp North Slope, LLC Hilcorp North Slope LLC.Surface Casing by Conductor Annulus Cement, Corrosion Inhibitor Top-offReport of Sundry Operations (10-404)06/01/2023Well NamePTD #API #Initial top of cement (ft)Vol. of cement pumped (gal)Final top of cement (ft)Cement top off date Corrosion inhibitor (gal)Corrosion inhibitor/ sealant dateL-2072210815002923702003.371.31/23/2023123/1/2023L-2312230105002923746003.003.0-393/27/2023M-111810575002920589002.602.6-105/29/2023M-311920325002922256001.501.5-165/29/2023M-331941165002922504001.301.3-145/29/2023N-171830095002920898001.201.2-115/30/2023N-18A2081755002920906010.500.5-65/30/2023N-21A1961965002921342011.001.0-85/30/2023N-272071045002923365000.500.5-45/30/2023N-292141105002923521002.302.3-245/30/2023N-31215175500292356000-0--205/30/2023V-2342220045002923707006.3210.91/23/2023243/1/2023W-2412221545002923741002.502.5-263/1/2023Z-121891025002921977000.700.7-45/23/2023Z-34212061500292346900-0--155/27/2023Z-402111735002923462000.700.7-65/27/2023Z-46A2052035002923280010.500.5-35/23/2023Z-502120015002923463000.500.5-35/27/2023Z-662121955002923482000.700.7-85/27/2023Z-116211124500292345500-0--175/27/2023Z-210204181500292322600-0--125/27/2023Z-2292221045002923726003.8361.23/5/2023363/27/20230.500.5-5/30/2023N-272071045002923365004 MEMORANDUM TO: Jim Regg—� P.I. Supervisor Z �� FROM: Brian Bixby Petroleum Inspector Well Name PRUDHOE BAY UNIT N-27 Insp Num: mitBDB220117134836 Rel Insp Num: Well N-27 PTD 2071040 BBL Pumped: Interval Notes: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, January 21, 2022 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC N-27 PRUDHOE BAY UNIT N-27 Src: Inspector Reviewed By: P.I. Supry J7— — Comm API Well Number 50-029-23365-00-00 Inspector Name: Brian Bixby Permit Number: 207-104-0 Inspection Date: 1/17/2022 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min InJ wTVD 8350 Tubing 430 441 437 441TyPe " 'Type Test SpIrITest psi 2088 IA — 695 2316 - — 2291 - 2285- -- - 16 BBL Returned: 1.4 OA 236 432 - 420 - 413 - 4YRTST 1P/F P Friday, January 21, 2022 Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS K1tL;tevtu 1. Operations Performed Length. Size: MD: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shIKdW6q /Q Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing 11Change App m� Plug for Reddll ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Pulled ISO plug IZ 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work 30-110 15. Permit to Drill Number: 207-104 3. Address: P.O. Box 196612 Anchorage, Development ❑ Exploratory ❑ 9-6/8" 30-3222 AK 99519-6612 Stretigraphic ❑ Service 21 1 6. API Number: 50-029-23365-00-00 7. Property Designation (Lease Number): ADL 028282 S. Well Name and Number: PBU N-27 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools 708 4-1/2" 8795-9503 8416-9108 PRUDHOE BAY, PRUDHOE OIL 7500 11. Present Well Condition Summary: Contact Email: Julie.Wellman@bp.com Total Depth: measured 9505 feet Plugs measured 9200 feet true vertical 9110 feet Junk measured 9197 / 9200 feet Effective Depth: measured 9200 feet Packer measured 8728 feet true vertical 8811 feet Packer true vertical 8350 feet Casing: Length. Size: MD: TVD: Buret: Collapse: Structural Subsequent to operation: 10291 Conductor 80 20" 30-110 30-110 1490 470 Surface 3192 9-6/8" 30-3222 30-3067 6870 4760 Intermediate 8941 7" 26-8967 26-8584 7240 5410 Liner 708 4-1/2" 8795-9503 8416-9108 8430 7500 Perforation Depth: Measured tlepth. 9073-9192 feet True vertical depth. 8687-8803 feet Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 4-1/2" 12.8# 13Cr80 412" Baker S-3 Perm Packer HES MCx Ser.# M55B SSSV 24-8804 8728 2201 24-8424 8350 Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 11418 1959 Subsequent to operation: 10291 300 1881 14. Attachments: (r vire pr2l) MC 25.070.25.07, s 25 2s3) 15. Well Class after work: Daily Report of Well Operations Iv7 Exploratory ❑ Development ❑ Service M Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ 1 GSTOR ❑ WINJ ❑ WAG 21 GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: WA Authorized Name: Julie Wellman Contact Name. Julie Wellman Authorized Title: Production Engineer Contact Email: Julie.Wellman@bp.com Authorized Signature: ( J.4 Date: q Contact Phone. +1 907 564 4657 Fomn 10404 Revised 042017 • "i 5A1P%A1/" / Submit Original Only A RBDWL64iAR 2 8 2019 'WELL S/I UPON ARRIVAL`** (profile modification) DRIFTED W/ 3.80" GAUGE RING TO TOP OF MCX @ 2,180' SLM PULLED 4 1/2" MCX (M55B) FROM SSSV NIPPLE @ 2,201' MD DRIFTED W/ 3.69" CENT, 2.50" SAMPLE BAILER TO TOP OF ISO PLUG @ 9,080' SLM LRS LOADED TUBING W/ 170bbls CRUDE PULLED INTERWELL 325-450 PLUG FROM 9,102' MD SET 4 1/2" MCX (M-03,1.43" bean) IN SSSV NIPPLE @ 2,201' MD (verified w/ check set) 3/2/2019 'WELL LEFT S/I UPON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS*** ***WELL S/I UPON ARRIVAL*** (sssv maintenance) PULLED 4 1/2" MCX (M-03) FROM SSSV NIPPLE @ 2,201' MD SET 4 1/2" MCX (M55B) IN SSSV NIPPLE @ 2,201' MD 3/19/2019 ***CONT WSR ON 3/20/19*** ***CONT WSR FROM 3/19/19*** (sssv maintenance) PERFORMED SUCCESSFUL 450psi CLOSURE TEST ON MCX 3/20/2019 ***WELL LEFT S/I UPON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS*** TREE = 4-1/16" CNV WE-LHEAD = 1 V FMC ACTUATOR= BAKER KB. B -EV = 71.6' BF. B -EV = 45.8' KOP= 500' Max Angle = 26" @ 2180' Datum MD= 9162 Datum TVD= 88W SS 91.5#, H-40, ID = 19.124" 108' 7#. L-80 BTC -M. ID = 8.68" Min ID (N-27) = 3.70" @ 9014' - 9200' CTM MILLED CEMENT RETAINER & CEMENT 7- 4-112" TBG, 12.6#, 13CR-80 VAM TOP, .0152 bpf, D = 3.958' 26#, L-80 BTC -M, D=6.276" H 8967' PERFORATION SUAWRY REF LOG: SLB MVVLYGR ON 08/30/07 ANGLEAT TOP PERF: 12" @ 9073' Note: Refer to Production DB for historical pert data SIZE SPF NTHNAL Opn/Sqz DATE 2-7/8" 6 9073-9078 S 06/26/17 2-7/8" 6 9073-9078 O 07/14/17 2-718" 6 9086-9091 S 06/26/17 2-7/8" 6 9086-9091 O 07/14/17 2-7/8" 6 9109-9114 S 06/26/17 3-3/8" 6 9144-9164 S 06/26/17 2-7/8" 6 9144-9164 O 07/14/17 9172-9192 S 06/26/17 2-7/8" 6 9172-9192 O 07/13/17 2-718" 6 9214-9219 S 06/26/17 j4-1/2" TBG, 12.6#, L-80 IBT-M, _0152 bpf, ID = 3.958" 1 ^/� SAFETY NOTES: `"4-1/2" CHROME TBG `*WELL N 7 TWINNED TO N-06 FLOW LINE— ■ I 999 V 9-5/8' TAM PORT COLLAR. D = 8.75" 2201' 4-1/2- HES X NP, D=3.813' • GAS LFT MANDRELS ST MD I ND I DEV I TYPE I VLV I LATCHI PORT DATE 4 3811 3631 15 KBG2 DMY BK 0 01/14/16 3 6100 5827 16 KBG2 DMY BK 0 01/14/16 2 7637 7301 17 KBG2 0M1' BK 0 08/16/11 1 8629 8254 14 KBG2 DMY BK 0 01/14/16 J 8728' 1-17" -14-1/2" WILEG, X 4-1/2" BKR S-3 PKK D= 3.875" 8761' DATE REV BY CO&VIENTS 4-1/2" HES X NP, D = 3.813' 09/13/07 N7ES ORIGINALCOMPLETION 8792' 03/29/12 LFA/JMD 7" CSG DEPTH CORRECTION 4-1/2" HES XN NP, D = 3.725" 8795' 08/03/17 BTWJMD P03EFF(07/13-14/17) 7" X 5" BKR G2 ZXP IT—F, D = 4-440- .440" 4-1/2"WLEG, D=3.958" ELMD TT LOGGED (DATE) F 8813--T-17- X 5" BKR FLE)(-LOCK HGR. D = 4.440 ID = 3.70'(06128/17) FISH: 4-1/2" WRP PULLING TOOL & 3.69" WRP (01/20/16) (DEPTH CORRECTED Ot/19117) PRUDHOE BAY UNIT WB -L: W27 PERMIT No: F2071040 AR No: 50-029-233656-00 SED 8, T11 N, R1 3F 2285' FSL & 571' FWL DATE REV BY CO&VIENTS DATE REV BY COM HITS 09/13/07 N7ES ORIGINALCOMPLETION 08/03/17 MS/JMD SETCMTRETAINER(06/23/17) 03/29/12 LFA/JMD 7" CSG DEPTH CORRECTION 08/03/17 MSSUMD EvLLED CMT/CMT SOZ (06/28/17 01/25/16 RCT/JMD SET FISH (01/20/16) 08/03/17 BTWJMD P03EFF(07/13-14/17) 02/24/16 RCT/JMD GLV CJO (01/14116) 04/02118 NXW/JMD SET MHiA3-L RUG 07/05/16 BTN/JMI3 ADPE RFS (06/28/16) 03/19/19 RCB/JMD RATED 14TERWE LL PLLG BP Ecploration(Alaska) 01/19/17 JW/TLH FLUCVFtSH CORRECTION STATE OF ALASKA 0 ALASKA OIL AND GAS CONSERVATION COSIGN REPORT OF SUNDRY WELL OPENS APR 1 9 2018 1. Operations Performed Abandon ❑ Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Opera n fir.. 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Cham ralrf ❑li Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Set Plug 14 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 207-104 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service IZI 6. API Number: 50-029-23365-00-00 7. Property Designation(Lease Number): ADL 028282 8. Well Name and Number: PBU N-27 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 9505 feet Plugs measured 9102 feet true vertical 9110 feet Junk measured 9197/9200 feet Effective Depth: measured 9102 feet Packer measured 8727 feet true vertical 8715 feet Packer true vertical 8350 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 28-108 28-108 1490 470 Surface 3192 9-5/8" 28-3220 28-3065 6870 4760 Intermediate 8941 7" 26-8967 26-8583 7240 5410 Production Liner 708 4-1/2" 8795-9503 8416-9108 8430 7500 Perforation Depth: Measured depth: 9073-9218 feet True vertical depth: 8687-8829 feet SCANNED ' Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 23-8804 23-8424 Packers and SSSV(type,measured and 4-1/2"Baker S-3 Perm Packer 8727 8350 true vertical depth) 4-1/2"HES MCX38100 SSSV 2201 2045 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 5882 200 700 Subsequent to operation: 1300 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations EI Exploratory 0 Development 0 Service El Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data ❑ GSTOR 0 WINJ 0 WAG Ei GINJ 0 SUSP 0 SPLUG 0 Sundry Number or N/A if C.O.Exempt: 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Authorized Name: MATTHEW BERGENE Contact Name: MATTHEW BERGENE Authorized Title: PRODUCTION ENGINEER n Contact Email: MATTHEW.BERGENE(d1BP.CO Date: Gi 1(X I Is Contact Phone: +1 907 564 4849 Authorized Signature: -' (� `��ll Form 10-404 Revised 04/2017 K'7Z 4/2 6 11(J Y/�J��' RBDMS APR l 31018 Submit Original Only • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary April 18, 2018 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for the setting of a plug in well PBU N-27, PTD 207-104. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage,AK 99519-6612 • • Daily Report of Well Operations PBU N-27 ACTIVITYDATE SUMMARY ***WELL SHUT IN ON ARRIVAL***(SLB E-LINE SET INTERWELL ME PLUG) INITIAL T/I/O= 0/0/0 RIG UP LUBRICATOR, PT TO 3800 PSI RIH W/INTERWELL 325x450 MED-EXPANSION PLUG. OAL=28', OAW= 350 LBS, MAX OD= 3.27". TIE INTO SLB CEMENT BOND LOG DATED 28-NOV-2007 TOP OF PLUG SETTING DEPTH = 9102', ME= 9105', CCL TO TOP OF PLUG=6.7', CCL STOP DEPTH = 9095.3'. FINAL T/I/O = 0/0/0 PSI 3/30/2018 ***JOB COMPLETE, WELL LEFT SHUT-IN ON DEPARTURE*** T/I/O= 0/0/0 R/D IA Comp. blind & install new API 5000 blind. PT'd against IA gate to 4/6/2018 2500psi.(Passed). RDMO ***Job Complete***FWHP=0/0/0 ***WELL S/I ON ARRIVAL****(Wag Swap) LOCATE & BRUSH SVLN @ 2,201' MD W/3.805" G. RING &4-1/2" BRUSH SET 4-1/2" MCX(ser#: M55B, 1.40" bean) IN SVLN @ 2,201' MD SHEAR CHECK SET ON MCX @ 2,201' MD 4/14/2018 ***WELL S/I ON DEPARTURE*** Fluids Summary Bbls Type 2.00 DIESEL Tom= 4-1/16"CIW 1hF1LF64D= 11'FMC S N_2 7 FETY NOTES:® *' E•4-1/2"CHROME TOG**W ECL ACTUATOR= BAKER TO N-06 FLOW LIN ' KB.ELEV= 71.6' BF.REV= 45.8' I -KOP= 500' ""- Mix Angle= 28" 2180' — 1 991' -(9-5/8•TAM FORT COLLAR D=8.75• Datum M)= 9162 2201' -1 4-1/2•HE5 X NP,D=3.813• Datum1VD= 8800'SS • 20"CONCLICTOR,91.5#,H-40,13=19.124" H 108' 9-5/8'CSG,47#,1-80 BTC-M D=8.68* - 3222' 1 GAS LFT MANDRELS ST MD ND DEV TY FE VLV LATCH FORT DATE 4 3811 3631 15 KBG2 DAY BK 0 01/14/16 3 6100 5827 16 KBG2 DAY BK 0 01/14/16 7"CSG,26#,L-80 TCI XO TO L-80 BTC-M -1 4714' _ X X 2 7637 7301 17 KBG2 DIN BK 0 08/16/11 1 8629 8254 14 KBG2 CMY BK 0 01/14/16 Min ID (N-27)=3.70" @ 9014' -9200'CTM I I 8707' -14-1/2"HES XNIP,D=3813• MILLED CEMENT RETAINER &CEMENT X $—{ 8728' —{7'X4-1M'BKRS-3RCR D=3.875" ] I I 8761' -4-1/2 IES X NP,D=3.813" 8792' --;4-1f2"HES XN NP,D=3.725' I r1 8795' -IT X 5'BKR C-2 ZXP LTR,D=4.440" TOP OF T LNR –I 8796' ..A ` 8804' --14-1/2"\MEG,D=3.958' 4-1/2"TBG,12.6#,13CFt-80 VAM TOP, -{ 8804' - .0152 bpf,D=3.958" -{E3 NDTTLOGGa (DAT ) 8813' —I T X 5"BKR REX-LOCK HGR,D=4.440 8823' /15'X4-1/2'X0,D=3.940" 7"CSG,26#,L-80 BTC-M D=6.276" -1 8967' 1- "• 9014'-9200'CTM H 1 L.LED HES CEMENT RETAINER& (CEMENT,D=3.70'(06/28/17) ►' 1 9033' H4-1/2•MARI®2JOf1r o PERFORATION SUMMARY REF LOG:SLB MWdGR ON 08/30/07 ►� I ANGLEATTOP PERE:12' _,9073' ►� Note:Refer to Production OB for historical perf data ►� SIZE SPF INTERVAL Opn/Sqz DATE ►i 2-7/8" 6 9073-9078 S 06/26/17 ,4 9102' --,MfftWH_L 325-450 PLUG(03/30/18) 2-7/8" 6 9073-9078 0 07/14/17 2-7/8" 6 9086-9091 S 06/26/17 i� 2-7/8" 6 9086-9091 0 07/14/17 ►I 2-7/8" 6 9109-9114 S 06/26/17 ► 3-3/8" 6 9144-9164 S 06/26/17 j' I 2-7/8" 6 9144-9164 C 07/14/17 2-7/8" 1� I " V1 6 9172-9192 S 06/26/17 ►� I 2-7/8" t 6 9172-9192 C 07/13/17 9197' 1-FIS►!4-1/2"WRP PULLING TOOL&3.69 ' ►1'. . ` 2-7/8" 6 9214-9219 S 06/26/17 ►4,/114 4 (01/20/16)(DEPTH CORRECTED 01/19/17) ►11611111 PBTO 9417' :�i1:�;1. 111111 11111 4.1/2"TBG,12.6#,L-80 BT-M, .0152 bpf,D=3.958" -- 9503' .1�12. �i�1�1 DTE REV BY COMMENTS DATE PEV BY COMMENTS RWHOE BAY!INT 09/13/07 MBB ORIGINAL COMPLETION 08/03/17 MS/.1143 SET CMT RETAI(06/23/17) WEI L: N-27 03/29/12 LFA/JM) 7"CSG DEPTH CORRECTION 08/03/17 MES/JMD KILLED CMT/CMTSQZ(06/28/17) FERMI No: 2071040 0125/16 RCT/JM) SET FISH(01/20/16) 08/03/17 BT /JMO RBPBRF(07/13-14/17) AR Pb: 50-029-233656-00 0224/16 RCT/JM) GLV a0(01/14/16) '04/02/18 NX'NJM)SET MH2WE3 L RUG SEC 8,T11 N,R13E 2285'FSL&571'FW.. 07/05116 B1P.VJMD ADPERFS(0628/16) 01/19/17 JVN'il..H FLUGIRSH COR ECTUN BP E i ploration(Alaska) 1- f'--ittUEIVED STATE OF ALASKA • eLASKA OIL AND GAS CONSERVATION COMMIS. FEB 8 U 0 REPORT OF SUNDRY WELL OPERATIONS 2018 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing ❑ Operations shutAOGGC Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well ❑ Other:Convert to Injector 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 207-104 3. Address: P.O.Box 196612 Anchorage, Development ❑ Exploratory ❑ AK 99519-6612 Stratigraphic 0 Service Ed 6. API Number: 50-029-23365-00-00 7. Property Designation(Lease Number): ADL 0028282 8. Well Name and Number: PBU N-27 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 9505 feet Plugs measured 9200 feet true vertical 9110 feet Junk measured 9197/9200 feet Effective Depth: measured 9200 feet Packer measured 8806 feet true vertical 8811 feet Packer true vertical 8427 feet Casing: Length: Size: MD: ND: Burst: Collapse: Structural Conductor 80 20" 28-108 28-108 1490 470 Surface 3192 9-5/8" 28-3220 28-3065 6870 4760 Intermediate 8941 7" 26-8967 26-8583 7240 5410 Production Liner 708 4-1/2" 8795-9503 8416-9108 8430 7500 Perforation Depth: Measured depth: 9073-9218 feet True vertical depth: 8687-8829 feet Tubing(size,grade,measured and true vertical depth) 4-1/2",13Cr80 23-8804 23-8424 Packers and SSSV(type,measured and 5"Baker ZXP Top Packer 8806 8427 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNED Treatment descriptions including volumes used and final pressure: r, . 1 .,!:',N / 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 584 21452 234 1841 1109 Subsequent to operation: -15171 600 1233 14.Attachments:(required per 20 MC 25.070 25.071,a 25.283) 15.Well Class after work: Daily Report of Well Operations I3 Exploratory 0 Development 0 Service H Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil ❑ Gas ❑ WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ ❑ WAG m GINJ ❑ SUSP ❑ SPLUG 0 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: 317-423 . Authorized Name: Bergene,Matthew Contact Name: Bergene,Matthew Authorized Title: Production Engineer Challenger Contact Email: Matthew.Bergene@bp.com Authorized Signature: -----(1134— c.� - Date: 7 i s Contact Phone: +1 9075644849 rr, Form 10-404 Revised 04/2017 VTL 3/I / 4 g RETMS M J L-( FE - 9 2018 Submit Original Only • • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary February 7, 2018 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Conversion to Injector covered under Sundry Approval # 317-423 for Well PBU N-27, PTD # 207-104. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 • • c o - o •� . U01 D N a) a) m 0 a Co 4-- c a) o o) Q o f mu) o ° CO n. 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() 0 _ 0 0 @ .0 co a) � U) N co D O * 0 0_ CO1. a) Q) c0 p N o a) E a ca U vi = ° c co > E > ( c II N IX a) O EO 11 V) I.,, ° Q0 A ~ > > o o m a° v c o o o _ co L CI Q � o � F- - E -2 ° L o °) � �ca ccs ~ U � o CI U U 3 c ° ° � � inM 7Q .No0 > 0 in > Q � Q U cUo ° o c U cco co _o 0 c 0 .� 0-ao � o a 0 o > > Z. O - Y >, o d n>, n.� II a° c ov) ov) n ai a) C * QL oO - Ow � > c� (0 co u) N (n O O E a) N N D O 00- 5. 0 _ 5 0 S ("\J N N U a) > — a) L o = d) a) II II N o o -°p d II N 2@ U 11 @ U U 0 0 O Q O v 0 J m = O c 2 :$ II 0 a1 II V L * E 0 Ea U C > - U O F- 0) Ill0E- cr» '8 : _oY .2 � F- � 5 .CILC/) F- .EU) CD -\ 0 w 1-- < 1--- co 0o co co > O O o 0 o O V) co F- N N N N N N 0 i,- O N > (0 - N N V' CO N N F- i.:-.5 U Q TREE= 4-1/16"CM/ N _� S NOTES: "4-1 f2"CHROME TBG"WELL V1�U1 AD= 11"FMC ACTUATOR= �BAKER TWINNED TO N-06 FLOW LINE" KB.ELEV= 71.6' BF ELEV= 45.8' I Max Angl , 2180 +s--, 991' —19-5/8'TAM FORT COLLAR,D=8.75' ill e= 26Datum MD= 9162' 2201' H 4-112"HF5 X NP,D=3.813" Datum"ND= 8800'SS 0 20'CONDUCTOR,91.5#,1340,13=19.124" —I 108' 9-5/8'CSG,47#,L-80 BTC-M,D=8.68' — 3222' _A , GAS LFT MANDRELS ST PA) ND DEV TY FE VLV LATCH FORT DATE 4 3811 3631 15 KBG2 t)4Y BK 0 01/14/16 3 6100 5827 16 KBG2 DM' BK 0 01/14/16 7"CSG,26#,L-80 TCI XO TO L-80 BTC-M —1 4714' ----)K L x 2 7637 7301 17 KBG2 DMY BK 0 08/16/11 1 8629 8254 14 KBG2 DAY BK 0 01/14/16 8707' H4-1/2"FES X P,0=3.813" Min ID (N-27)=3.70" @ 9014' -9200'CTM r� M MILLED CEMENT RETAINER & CEMENT z z----i8728' 1-7'X4-1/2'BKR s 3 PKR D=3.875" I 8761' H4-1/2"FES X NW,D=3.813' ' 8792' H4-1/2"FSS XN NIP,D=3.725" 8795' H 7'x 5"BKR C-2 ZXP LIP,D=4.440" TOP OF 7"LPR — 8795' 1 ! 8804' —4-1/2"WLEG,D=3.958" 4-1/2"TBG, 12.6#,13CR•60 VAM TOP, —1 8804' .0152 bpf,D=3.958" --I alio TT LODGE) (DATE) 8813' —7'X 5'BKR FLEX-LOCK FHGR,D=4:440 8823' H5'X 4-1/2'XO,D=3.940" 7"CSG,26#,L-80 BTC-M H3=6.276" 1— 8967' ' 9014'-9200'CTM f—MILLED FES CBMENT RETAINER& CEMBNIT,D=3.70'(06/28/17) I4 PERFORATION SLL RY `� ' 9033' H41/2^MARKERJOfJT FIEF LOG:SLB MW YGR ON 08/30/07 ANGLE AT TOP MT:12'@ 9073' 1� Note:Refer to Rod uction DB for historical perf data I SIZE SPF I�tTERVAL Opn/Sqz DATE 14 i 2-7/8 6 9073-9078 S 06/26/17 114 } 2-7/8" 6 9073-9078 0 07/14/17 I( 2-7/8' 6 9086-9091 S 06/26/17 114 2-718" 6 9086-9091 0 07/14/17 Ft 2-7/8" 6 9109-9114 S 06/26/17 Et 111 3-3/8" 6 9144-9164 S 06/26/17 4 2-7/8" 6 9144-9164 0 07/14/17 I4 2-7/8' 6 9172-9192 S 06/26/17 If 2-7/8' 6 9172-9192 0 07/13/17 I." 9197' —F IStt 4-1/2'WRP PULLING TOOL&3.69"WTD 2-7/8" 6 9214-9219 S 06126/17 h 44�4`4'1 (01/20/16)(DEPTH CORRECTED 01/19/17) Ir/4444444 F/44* 4444 PBTD H 941r 11.4.4.4.► 1444444444 14-1/2'TBG,12.64,L-80 IST-M, .0152 bpf,ID=3.958"I— 9503' '.1.4`44.1 DATE REV BY COM U4TS DATE REV BY COMMENTS NTS PRUDHOE BAY UNIT 09113/07 NIES ORIGINAL COMPLETION 08/03/17 MS/JM) SET CMT RETAINER(06/23/17) WELL: N-27 03/29/12 LFA/JAD T CSG DEPTH COHRECTTON 08/03/17 MSS/AAD MILLED C14T/CMT SOZ(06/28/17) PERIAT N,:'2071040 01/25/16 RCT/JM) SET FISH(01/20/16) 08/03/17 BT?'UJM) FIS(07/13-14/17) AA No: 50-029-233656-00 02/24/16 FST/JM) GLV C/O(01/14/16) SEC 8,T11 N,R13E,2285'FSL&571'FWL 07/05/16 BTWJM) ADPERFS(06/28/16) 01/19/17 JW7TLH PLUG/FISH CORRECTION BP Exploration(Alaska) • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,February 06,2018 TO: Jim Regg I/ p,, P.I.Supervisor I4J I 6 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. N-27 FROM: Chuck Scheve PRUDHOE BAY UNIT N-27 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT N-27 API Well Number 5o-029-23365-0o-0o Inspector Name: Chuck Scheve Permit Number: 207-104-0 Inspection Date: 1/22/2018 "" Insp Num: mitCS180123103452 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well N-27 ` Type Inj w. TVD 8350 Tubing 368 - 718 748 767 PTD 2071040 Type Test SPT Test psi 2088 ' IA 424 2500 - 2503 • 2519 BBL Pumped: 1.8 -BBL Returned: 2.3 - OA 317 . 566 - 592 - 603 - • Interval 4YRTST PT P Notes: Post initial injection MIT per sundry#317-423. - SCANNED . v Tuesday,February 06,2018 Page 1 of 1 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,January 23,2018 TO: Jim Regg oi 1 2— P.I.Supervisor l t D SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. N-27 FROM: Chuck Scheve PRUDHOE BAY UNIT N-27 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry.1 - NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT N-27 API Well Number 50-029-23365-00-00 Inspector Name: Chuck Scheve Permit Number: 207-104-0 Inspection Date: 1/22/2018 Insp Num: mitCS180123103452 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well N-27 !Type Inj W TVD T 8350 Tubing 368 718 • 748 • 767 PTD 2071040 Type Test SPT Test psi 2088 • IA 424 2500 2503 ' 2519 - BBL Pum ed: 1,8 BBL Returned: 2.3 OA 317 566 592 603 Interval 4YRTST _--- - -- �P/F I P y Notes: —TA/0;j-e' Cc"Uf2 •-- 31-7 —4-z3 SCANNED 0 .tr • Tuesday,January 23,2018 Page 1 of 1 • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Wednesday,January 10, 2018 9:55 AM To: Wallace, Chris D (DOA);AK, OPS EOC Specialists;AK, OPS GC2 Facility OTL;AK, OPS GC2 Field O&M IL;AK, OPS GC2 OSM;AK, OPS GC2 Wellpad Lead;AK, OPS PCC Ops Lead; AK, OPS Prod Controllers;AK, OPS Well Pad HUQ;AK, OPS Well Pad LV;AK, OPS Well Pad MN;AK, OPS Well Pad RJ;AK, OPS WELL PAD S;AK, OPS Well Pad SW;AK,OPS WELL PAD W;AK, OPS Well Pad Z;Ak, Ops West Area IL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr; Bergene, Matthew; Frankenburg,Amy Cc: Regg,James B (DOA);AK, GWO Completions Well Integrity;AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Information;AK, OPS FF Well Ops Comp Rep;AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau;O'connor, Katherine; Romo, Louis A; Sternicki, Oliver R;Tempel,Joshua;Worthington, Aras J Subject: OPERABLE: Injector N-27 (PTD#2071040) Injector Conversion All, Injector N-27 (PTD#2071040) is an Injector Conversion that is ready to be put on injection. Sundry#317-423 has been approved this conversion.The well is now classified as OPERABLE. Plan forward: 1. Operations: Put on injection 2. DHD—AOGCC witnessed MIT-IA once well is thermally stable Please respond with any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization-Alaska Office:907-659-8110 SCANNED 4 *', Cell:307-399-3816 1 STATE OF ALASKA •LASKA OIL AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIO 1. Operations Performed Abandon ❑ Plug Perforations WI Fracture Stimulate 0 Pull Tubing ❑ Operations shutdown 0 Suspend 0 Perforate RI Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well El. Re-enter Susp Well 0 Other:Channel Squeeze IBJ 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 207-104 3. Address: P.O.Box 196612 Anchorage, Development WI Exploratory 0 AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-23365-00-00 7. Property Designation(Lease Number): ADL 0028282 8. Well Name and Number: PBU N-27 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools:PRUDHOE BAY,PRUDHOE OIL RECEIVED 11.Present Well Condition Summary: T r 7 Total Depth: measured 9505 feet Plugs measured 9200 feet OC I v �O�( true vertical 9110 feet Junk measured 9197/9200 feet /\c CC Effective Depth: measured 9200 feet Packer measured 8806 feet /� true vertical 8811 feet Packer true vertical 8427 feet --- - - Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 28-108 28-108 1490 470 Surface 3192 9-5/8"47#L-80 28-3220 28-3065 6870 4760 Intermediate 8941 7"26#L-80 26-8967 26-8583 7240 5410 Production Liner 708 4-1/2"12.6#L-80 8795-9503 8416-9108 8430 7500 Perforation Depth: Measured depth: 9073-9078 feet feet 9086-9091 feet 9109-9114 feet 9144-9164 feet 9172-9192 feet 9213-9218 feet True vertical depth: 8687-8692 feet feet 8700-8705 feet 8722-8727 feet 8756-8776 feet 8784-8803 feet 8824-8829 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 23-8804 23-8424 Packers and SSSV(type,measured and 5"Baker ZXP Top Packer 8806 8427 true vertical depth) 12.Stimulation or cement squeeze summary: SCANNED DEC 1 8 2017.1 Intervals treated(measured): 9073'-9078',9086'-9091',9109'-9114',9144'-9164',9172'-9192',9213'-9218'. Treatment descriptions including volumes used and final pressure: 235 Bbls 1%Slick KCL,50 Bbls 50/50 Methanol/Water,25 Bbls Fresh Water,21 Bbls 14.0 ppg Squeeze Crete Cement,21 Bbls 15.8 ppg Class G Cement,15 Bbls Gel,2510 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 584 21452 234 1841 1109 Subsequent to operation: Shut-In 0 0 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations RI Exploratory 0 Development I! Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil a Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG ❑ GINJ 0 SUSP 0 SPLUG ❑ 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: 317-059 Authorized Name: Bergene,Matthew Contact Name: Bergene,Matthew Authorized Title: Production Engineer Challenger ( Contact Email: Matthew.Bergene@bp.com Authorized Signature: Date: Z C�c �, Contact Phone: +1 9075644849 Form 10-404 Revised 04/2017 1/7"- 1 Z/1-/i9- p RBD IJ�q S 1,‘-' rt N34 - 2 2U17 Submit Original Only • s by 0 BP Exploration(Alaska)Inc. 900 East Benson Boulevard To: Alaska Oil and Gas Conservation Commission P.O.Box 196612 Anchorage,AK 99519-6612 333 West Seventh Avenue USA Anchorage, AK 99501-3572 Main 907 564 5111 RE: BP Exploration (Alaska), Inc. Reports of Sundry Well Operations Summary for wells N-01A and N-27 October 26, 2017 To Whom It May Concern: Please find attached the Reports of Sundry Well Operations for Channel Squeeze and Addition of Perforations for Wells N-01A (PTD # 204-113) and N-27 (PTD # 207-104). On August 31, 2017, the State received an additional request for Sundry Approval for each of the wells listed above. The purpose of this additional Sundry was to obtain current and valid Sundries for conversion to WAG injection. At that time, the wells were expected to be put on injection (P01) in September 2017 and after passing MITs a Report of Sundry Well Operations would have been submitted for both active Sundries; however, due to unforeseen facility work the wells have been unable to be POI. At this time, please find attached the Report of Sundry Well Operations for the well work portion only, referencing Sundries 317-024 and 317- 059 for N-01A and N-27 respectively. Additional Reports of Sundry Well Operations, referencing Sundries 317-422 and 317-423 for N-01A and N-27 respectively, will be submitted upon completion of a State witnessed Mechanical Integrity Test. Sincerely, Matthew C. ergene Production Engineer Challenger BP Exploration (Alaska), Inc. P. O. Box 196612 Anchorage, AK 995196612 Attachments: Form 10-404 for N-01A PTD#204-113 Form 10-404 for N-27 PTD# 207-104 • • _ c Cl) w a To Z U) o d .0 CC H ❑ -o • J O E o o• Q 0_is p 0 o C7 0 o ai eL o 3 0_ 2 cd U v o Q3 ' E LO cnJ 0 co °o 0 o a) O -e N o p D U F- : (/) 0) 17 0 II r ao U a) o) ,- c u) 0_' W 2 J (0 c O N � 9 u7) E a) W -i 1- m N N n a) C c Z in o_ o � N j u) n .WL11 W0U) - 0 a o a) 0 CT a ° rn pw0 O N a) -a 3 la Ta n o c`o — HIXp1- g a-0 O N H N Z1- U) 0) c ,_ L- OLn -0 O o O 2 O J Z U H « o c Q� al cYE, 0H UJmLU H U O w U m � Quo "O cf) co ° LO .c -O J O LLL J 0_ 4, c u) 0_ to O >- _i o Ninm Z � Zo i_ cC c en c'�a a) Y cc rn r- a) co E C RI Q � o m0 ¢ W M— ap w r � _ •- a) o '- 2JO U OO JU) UY = 0- Ua=. ._ sZ E C. 2u o (/) U) Y < Opr- ❑ N a) � o0 v O v >>, r1 cn Y O o - J 0_ L0 p N U) _ _@ c U * _ d N Q � coo r` � WU UPON Z p-Q � UU E Z a) E.Nw r � OU WOOS U)• = cu E QQ) (0 0 L ~ N 0 (!..)1 0_ S` N H • CO a sZ U p co O X •= o Z � p ib I a) or- °° p � aE c>3 3 o w O (n E o)o Lo u) o 2 mm -, o- oU 0) 1- 0 ._ oar- a) O @ N vi a) 0_ a) ob 0 w U) = — Cl-U a) Q' -c Q u) •Q N W N - Q N Z -L O_c o OU - .O J a) O_ a) 2 Z ❑ U) J O U) U) c U c re LL O L N > N W U) -J U co N -+ I p 9N in ' iXZOI-- W Qa O W Wiz, � U � o 2 a 2 rn0 a) a r.r_ Qm1 Z ❑ � oU o e3 Eo 0 I- p0' Q Q o -, U) 0- in c o 0 a) in s O c www — w H0 ❑ O W w = a) as a) o ca eLE = LLIZ WOW ILLI ~ 2 c c N Q) u) W 70 _Z I- � Q � � 2 o 0 E c) Q U) o)co O Z m ❑ ❑ L~L.I Z 0_ ii 0_ 0 U N o' , Q0 < -'' E c) z WQ O 5 � .a? 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U- 2 r` � � = ❑ ooO � m m � wOY � m °0cn op m a) a� OZ � Z � Z � Z00 ZXXJO OZZXXUpO * o � lo c c * ❑ W ❑ WDW Doo ...,- 0_ D __I * * O ❑ < Q * I' in ._ H ID LiJ : CC 0_ a' 0_ 20_ a' JJ > LL CC 2 < « 0Ct2a. Q' : I,- I 1- r- r r O r r O O O N N N N M It) r r r_ r r- r- r` • . • ! N >. C al O E �' E a) L D Q- C) C. O a N u- Z o m t a o a -E- 0 a) Ce E D .... CB a) E J 0 a) U U f a) (-9 U) O N U 3 C J N CD J a:I F Y ZD p 9 1 U 0 CO 0 U > � Q U Q Y w o O @ °� o o T v to a3 o 0 0 .- LtOr- LL <- CIr dm � � � o � `O <- `- 1.O ° LOo N- CO N N N N N f� N— 1 TREE_, " 4-1116"OW V1ELtF AD= 11'FMC . N_27 TYQtrINEDNOTES: TO N-06 FL W LINE** ACTUATOR= WELL ACTUATOR= BAKER KB.ELEV= 71®6' @ .H_l/= 45.8' f if/OP= -___ 500' Mix Angle= 26' 2180' 7,:I-- 991' H9-5/8"TAM PORT COLLAR,D=8.75" ii .... Datwn MD= 9162' 2241' H4-1/2"FSS X t+6",D=3.813' Datum TVD= 8800'SS Q 20"CONDUCTOR,91.5#,14-40,D=19.124" --I 108' 9-5/8"CSG,474,L-80 BTC-M,D=8.68' HI 3222' ___A ' GAS LIFT MANS ST MD ND DEV TY FE VLV LATCH FORT [ATE 4 3811 3631 15 KBG2 DMY BK 0 01/14/16 3 6100 5827 16 KBG2 CMY BK 0 01/14/16 7"CSG,26#,L-80 TCII XO TO L-80 BTC-M H 4714' X L 7K 2 7637 7301 17 KBG2 DAY BK 0 08/16/11 ' 1 8629 8254 14 KBG2 MY BK 0 01/14/16 ' I 8707 H 4-1/2"FES X NP,D=3.813" Min ID (N-27)= 3.70" @ 9014' -9200' CTM MILLED CEMENT RETAINER & CEMENT g 'X 8728' _7"X4-1/2"BKRS-3FKR,ID=3.875' I 8761' —4-1/2-FES X NP,D=3.813" M ' 8792' —4-1/2"t—XN NP,D=3.725" 8796' --17"X 5"BKR C•2 ZXP LTP,D=4.440' TOP OF 7"UNIR H 8795' \ji . 8804' 14-1/2"WLEG,D=3.958" 4-112"TBG, 12.6#,13CR-80 VAM TOP, — 8804' ---i- ' ',. ---1MD aTT LOGO (DATE) 0152bpf,D=3.958" 8813' H7"X 5"BKR FLEX-LOCK HGF D=4.440 8823' —{5"X 4-1/2"XO,D=3.940" 7"CSG,264,L-80 BTC-M D=6.276" H 8967' 9014' -9200'CTM —MLLED HES CB4E?(F RETAINER& CEMENT,D=3.70'(06/28117) 14 1 PERFORATION SUMMARY 14 r 9033' H4-1/2"MARKER JOfTT REF LOG:SLB MVYD+GR ON 08/30/07 `4 ANGLE AT TOP PERF: 12' i 9073' /l Note:Refer to production DB for historical perf data ) • SIZE SW IJTeRVAL Opn/Sqz DATE 1 I 2-7/8" 6 9073-9078 S 06/26/17 /I 2-7/8" 6 9073-9078 0 07/14/17 14 + 2-7/8" 6 9086-9091 S 06/26/17 ,4 2-7/8" 6 9086-9091 0 07/14/17 /4 2-7/8" 6 9109-9114 S 06/26/17 /4 I 3-3/8" 6 9144-9164 5 06/26/17 14 2-7/8" 6 9144-9164 0 07/14/17 11 2-7/8" 6 9172-9192 S 06/26/17 1+ I 2-7/8" 6 9172-9192 0 07/13/17 14 ,9 919T —FISFt 4-1/2"WRP PULLING TOOL&3.69"WRP 2-7/8" 6 9214-9219 S 06/26/17 10.•�4Y 1 (01/20/16)(DEPTH CORRECTED 01/19/17) 14 i���l444 ►i•$$ 4 i4•4 FFTD --I 9417 !1.1.4.4 t AIWA 4-1/2'TBG,12.6#,L-80 BT-M, .0152 bpf,D=3.958" — 9503' 10,4,0,< DATE REV BY COI'MNTS . DATE REV BY COMETS PRIDiOE BAY UNIT 09/13/07 MES _ORIGINAL COMPLETION 08/03/17 MS/.9.1) SET CMT RETAINER(06/23/17) WELL: N-27 03/29/12 LFA/JMD 7"CSG DEPTH CORRECT1ON 08103/17 MSS/JMD MLLE)CMI/CMT SQZ(06/28/17) PERMIT No:'2071040 01/25/16 RCT/..11.13 SET FISH(01/20/16) 08/03/17 BTTYJMD IAF(07/13-14/17) API No: 50-029-233656-00 02/24/16 RCT/JMD GLV GO(01/14/16) SEC 8,T11N,R13E,2285'FSL&571'FVC 07/05/16 BTNJMD ADFERFS(06/28/16) j 01/19/17 JW/TLH PLUG/FISH C 0f 11ON BP Exploration(Alaska) 1 • • , � THE STATE Alaska Oil and Gas ti °ALASKA Conservation Commission 333 West Seventh Avenue � , GOVERNOR BILL WALKER Anchorage, Alaska 99501 3572 Main: 907.279.1433 ()-A' ALAS Fax 907.276.7542 www.aogcc.alaska.gov Matthew Bergene Production Engineer Challenger SEP Zo�7, BP Exploration(Alaska), Inc. P.O. Box 196612 SCAMS Anchorage,AK 99519-6612 Re: Prudhoe Bay Field,Prudhoe Bay Oil Pool, PBU N-27 Permit to Drill Number: 207-104 Sundry Number: 317-423 Dear Mr. Bergene: 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, L(C-2D Hollis S. French Chair DATED thisl 2' day of September, 2017. RBDI IB Lt/sE' 1 9 2017 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIIIP N APPLICATION FOR SUNDRY APPROVALS 20 MC 25.280 1. Type of Request: Abandon El Plug Perforations ❑ Fracture Stimulate 0 Repair Well ❑ Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 • Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other Convert to Injector Il • 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 207-104 • Exploratory 0 Development a• 3, Address: P.O.Box 196612 Anchorage,AK 6. API Number: 50-029-23365-00-00 99519-6612 Stratigraphic 0 Service 0 • 7. If perforating: . 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? RECEIVED���'��D Will planned perforations require a spacing exception? Yes 0 No 0 PBU N-27 Property 9. Field/Pools: ADL 0 28282 Designation(Lease Number): 10. PRUDHOE BAY,PRUDHOE OIL • AUG 312017 11. PRESENT WELL CONDITION SUMMARY ��V�d Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): 9505 . 9110 ' 9200 8811 9200 9197/9200 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"91.5#H-40 28-108 28-108 1490 470 Surface 3192 9-5/8"47#L-80 28-3220 28-3065 6870 4760 Intermediate 8941 7"26#L-80 26-8967 26-8583 7240 5410 Production Liner 708 4-1/2"12.6#L-80 8795-9503 8416-9108 8430 7500 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment 4-1/2"12.6#13Cr80 13Cr80 23-8804 Packers and SSSV Type: 5"Baker ZXP Top Packer Packers and SSSV MD(ft)and TVD(ft): 8806, 8426.60 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary 0 Wellbore Schematic 0 13.Well Class after proposed work: Detailed Operations Program Ii BOP Sketch 0 Exploratory ❑ Stratigraphic 0 Development 0 Service ®• 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: c[tG�_f1'w''L1.— 7.--42'1-7 ❑ WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG H • GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Bergene,Matthew be deviated from without prior written approval. Contact Email: Matthew.Bergene©bp.com Authorized Name: Bergene,Matthew Contact Phone: +1 9075644849 Authorized Title: Production Engineer Challenger Authorized Signature: 6401,......,‘, Date: 3\ 4 _�3-{- ' t7 COMMISSION USE ONLY "�"JI Conditions of approval:Notify Commission so that a representative may witnessSundry Number: 3 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test Location Clearance 0 ` Other: Post Initial Injection MIT Req'd? Yes No 0 Spacing Exception Required? Yes 0 No qA Subsequent Form Required: / a 4 0 APPROVED BYTHE Approved by: (:4-.<11Q11, ''''''''---.. COMMISSIONER COMMISSION Date: ek ('z 1 -7. c � VTL 4/ii/i7 AlyR I G I NALRB®MS ) , 2017 "t' �'l7 .A.b 9. s--, r7 Submit Form and Attachments in Duplicate Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. • • by 0 BP Exploration(Alaska)Inc. 900 East Benson Boulevard P.O.Box 196612 Alaska Oil and Gas Conservation Commission Anchorage,AK 99519-6612 333 West Seventh Avenue USA Anchorage, AK 99501-3572 Main 907 564 5111 RE: BP Exploration (Alaska), Inc. Application for Sundry Approval for Conversion to Injection Wells N-01A and N-27 August 30, 2017 iG��' P/rvrrvv5 /'k5'104 To Whom it May Concern: 6Y! d, q �€v,..4, is f,,'l) vqf' I l7 Attached pleas find the Application for Sundry Approvals to convert wells N-01A(PTD#204-113) and N- 27 (PTD # 207- 04) to injectors. N-01A and N-27 were th subject of previously approved sundries for conversion numbered 315-330 and 315-332 respectively; Since the initial Sundries were approved on 06/19/2015,a significant amount of additional well work was required than expected to prepare the wells , for injection. The well work is the subject of two additional sundries, 317-024 for N-01A and 317-059 for N-27. The well work that was required included a cement squeeze of the liners to remediate channels behind pipe within the Ivishak Formation. This work was recently completed and the wells are now ready to put on injection; however, since more than 12 months has passed since the initial Sundries for Conversion (315-330 and 315-332) were approved, it is requested that new, current sundries are . approved. Sincerely, Matthew C. Bergene Production Engineer Challenger BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage,AK 99519-6612. Attachments: Form 10-403 Application for Sundry Approval for N-01A Conversion to Injector Form 10-403 Application for Sundry Approval for N-27 Conversion to Injector Area of Review for N-01A and N-27 • • d N co CCI N CV CO CO , N t CO iO 6) 00 CO ch 0 0 0 CO I--Lo O coCNI O CO I� I� I� r,-, CO CO CO CO N N I— o_ O I- tY Cr) v_ 0) LC) co .c CA CO . N CO N- O- (fl (fl N CO C'7 Ma 0 co COI` co > O co co 00Ncoc 0 > al wrX a D O wCO Z UJ LU O w o a 11.1 °' 55Y v0 0 m O O w Y X 2 _ ( _ J U 0 w W 4 CL CO O) '— N C)) Q Q Q 0_ d 0 Z 0 W 0 CI rn CD rn rn rn rn 000 _1Z Z Z O r J _i p E R Q Q Q = 0 a a Ili n O O 0 W -C w w w 0_ I- I- Q Q C.) N. 2 2 2 0 co cn cocn co N 0. Q I Z 0 c = « co (00) - (Nco O co0- I- CO O V I� W d 0 0 ,— N. CN }r ^ 0 CA 0) (A CA 0) 03 1.L y al d O 2 _� v_) = 0 0 u) LY L 2 2 2 0 cn cncu~) cn cn cn O O. 0) v 0 0 c LL u_ N LL LL C/) iv 0- a_ CJaa- d a) < < 0) < < CO O. 0 a) a) a 0 w J I— D o N d cn n J RI ti N- I` I` ti ti 0 0 O Q c C) 0 CD 0 C) 0 WW J J Z LL O N N N N N N Z 0. 0. < W W O W N N LL fi • t7" CO cr co co 0 W W W J W W C) S S N N Z °' 0 �7 U W W LL W O. N- N- CO N- N- CO0 0 O m o cLccJ J O O W W < < m m LL LL co cn Q_ cG m E co z Imo- I- N- ti N- N N N N N NI� a 0 Cn m 0- 0- J 00 W dZZZZZZ < < m CO L.L. L.T. u) co o ,T1 = 4-1/16"CNV • S NOTES: **4-112"CHROME TBG**WELL VI43_LtEAD= 11'FMC N 2 7 TWINNED TO N-06 FLOW LINE* ACTUATOR= BAKER a KB.TELEV= 71.6' BF ELEV= 45.8' I KOP= 500' i ...... Max Angle= 26°g 2180 .7.---I991" --19-5/8"TAM PORT COLLAR,D=8.75" Datum MD= 9167 2201' —14-1/2"HES XNDP,D=3.813' Datum TVD= 8800 SS (7) I 20"CONDUCTOR,91.5#,H-40,D=19.124" H 108' 9-5/8"CSG,47#,L-80 BTC-M,ID=8.68" H 3222' _A , GAS LFT MANDRELS ST MD TVD DEV TY FE VLV LATCH PORT LATE 4 3811 3631 15 KBG2 DMY BK 0 01/14/16 3 6100 5827 16 KBG2 DMY BK 0 01/14/16 7"CSG,26#,L-80 TCD XO TO L-80 BTC-M —1 4714' --)K7 7K 2 7637 7301 17 KBG2 DMY BK 0 08/16/11 1 8629 8254 14 KBG2 MY BK 0 01/14/16 ■ r 8707' —4-1/2'HES X NDP,D=3.813" 1 Min ID (N-27)=3.70" @ 9014' -9200' CTM �I MILLED CEMENT RETAINER & CEMENT Z 8728' H7"X4-1/2"BKR S-3PK}.D=3.875" I i 8761' —14-1/2"HES X NDP,D=3.813" ' ' 8792' FES S XN NP,D=3.725" 8795' —r X 5"BKR C-2 ZXP LTP,ID=4.440" TOP OF 7"LNR —.1 8795' i, k ''°' 13804' —14-1/2"WLEG,D=3.958' 4-1/2"TBG,12.6#,13CR-80 VAM TOP, —{ 8804' 0152 bpf,D=3.958" --{ELMD TO T LOG (LATE) 8813' H 7"X 5"BKR FLEX-LOCK HGR,D=4.440 8823' H5"X 4-1/2"XO,D=3.940" 7"CSG,26#,L-80 BTC-lug ID=6.276" —{ 8967' H—', ' 9014'-9200'CTM H Mt.LED HES CEMENT FETAENER& CENT,ID=3.70"(06/28/17) V / PERFORATION SUMMARY t 9033' —j41/2"MARECE2JOINT REF LOG:SLB MWTYGR ON 08130/07 ► ' ANGLE ATTOP FE F:12°@9073' ►f Note.Refer to Roduction DB for historical pert data ► * SIZE SPF INTERVAL I OpNSgz DATE (f I 2-7/8" 6 9073-9078 S ' 06/26/17 If 2-7/8" 6 9073 9078 " 0 07/14/17 f 2-7/8" 6 9086-9091 S 06/26/17 /# 2-7/8" 6 9086-9091 • 0 07/14/17 4 2-7/8" 6 9109-9114 - S 06/26/17 ►f I 3-3/8" 6 9144-9164 S 06/26/17 1l 2-7/8" 6 9144-9164 • O 07/14/17 ►1 I 2-7/8" 6 9172-9192 S 06/26/17 ►4 2-7/8" 6 9172-9192 • 0 ' 07/13/17 I I4.4 ."`f 9197' =FISH 4-1/2"WRP PULLING TOOL&3.69"WRP 2-718" 6 9214-9219 • S 06/26/17 ►I t.;4441• (01/20/16)(DEPTH CORRECTED 01/19/17) 14 14444441. PBTD —{ 9417' 4.4W4 FI-1/2" ►4444444444 (T-1/2"TBG,12.6#,L-80 EHT-M, .0152 bpf,D=3.958" — 9503' 0.' DATE REV BY COMMBYTS DATE REV BY COMMENTS FRUDHOE BAY tJNT 09113/07 N7ES ORIGINAL COMPLETION 08/03/17 MS/JMD SET CMT RETAINER(06/23/17) WELL: N-27 03/29/12 LFA/JMD 7"CSG DEPTH COf ON 08/03/17 MSS/JMD MFLED CMT/CMT SQZ(06/28/17) PER 1T No:"`2071040 01/25/16 RCT/JMD SET FISH(01/20/16) 08/03/17 BTWJMD REFERF(07/13-14/17) AR Nb: 50-029-233656-00 02/24/16 RCT/JMD GLV(70(01/14/16) SEC 8,T11N,R13E,2285'FSL&571'FM. 07/05/16 BTNIJMD_ADPEFFS(06/28/16) 01/19/17 JW/TLH FLUG/FtSH CORRECTION BP Exploration(Alaska) i • • Area of Review PBU Wells N-01A (API No: 50-029-20079-01) N-27 (API No: 50-029-233656-00) This Area of Review is required prior to the conversion of N-01A, N-07A and N-27 from producers to WAG injectors. This AOR discusses wells within 1/4 mile of each well's entry point into the Sag River formation. Current Status: N-01A is currently an operable producer. The last well test on 09/08/2015 indicated 607 bopd, 61% watercut, and 20,722 scf/bbl GOR. N-27 is currently an operable producer. The last well test on 10/09/2015 was 584 bopd, 29% watercut, and 36,729 scf/bbl GOR. Both of these wells were initially scheduled to be converted to WAG injectors in 4Q 2015 as part of the N-pad UZI (Updip Zone 4 Injection) Project, prior to that work beginning sundries for conversion were approved on 06/19/2015 (315-330 and 315-332). The UZI Project targets remaining oil where the gas cap has expanded into zone 4, and the gravity drainage process is less efficient. The UZI Project achieves improved recovery through pattern injection of water and/or MI. The area of UZI potential is generally identified as immediately upstructure of the existing WF/EOR area. The planned facility work to install MI and water injection headers was completed slightly behind schedule, and one of the three conversion wells, N-07A, was put on injection July 10, 2016. Due to conformance issues with N-01A and N-27, the wells were not ready to • be put on injection until recently. Since more than 12 months lapsed between the initial sundry approvals and the completion of the well work, these wells have not been put on injection until a new sundry for conversion is approved. N-01 A N-01A Completion: N-01A is a conventional (max angle is 68°) well that was sidetracked in September 2004 in zone 4. It was sidetracked with future UZI injection potential in Z4 as part of that justification. The well was pre-produced between 09/2004 and 09/2015, while waiting for approval and construction of the UZI project. The well has been SI and disconnected from the production system since 09/29/2015. N-01A is completed with 4-1/2", L-80 tubing and production liner (wellbore schematic Figure 1). The original well was drilled in 1970 and it was sidetracked in 2004. A CBL shows that the cement behind the original 9-5/8" casing was poor. However during the sidetrack in 2004, a new 7" liner was installed from 8,968'MD to 7181' MD' with a 7" scab liner cemented in place from 7181' to 2426'MD. The liner was cemented with 35 bbls of • • 15.8 ppg Class G cement. The estimated TOC is 7,884'MD. There are no cement bond logs for this section of pipe, but no abnormalities occurred with this cement job. 4-1/2" tubing was installed from surface to TD @ 9748'MD. It was cemented with 27 bbls of 15.8 ppg Class G cement. No abnormalities occurred with this cement job although—15 bbls were circulated back to surface. After the initial sundry for conversion was approved in 2015 (315-330), a caliper was run on January 13, 2016, indicating that there was corrosion across the L-80 production liner. On February 24, 2016, a borax/RPM log was run. The log indicated channeling across the proposed perforation interval. A remedial cement squeeze (sundry 317-024) was attempted on June 22, 2017. As part of the approved program, coil tubing attempted to first mill a restriction at 9185' MD, milling was unsuccessful and no more progress was made past 9202' MD, at this point the squeeze was cancelled and the coil tubing unit rigged down off the well. On 15 July, 2017, slickline drifted the well with a variety of tool strings, and confirmed that we do not have access to the wellbore below 9202' MD. There is a potential hole in the liner at —9185' MD, this depth is located in the 46P,just below the Shublik Shale, within the Ivishak formation. It is planned to operate N-01A as a WAG injector, we believe it to be suitable based on the most recent integrity tests, which are: 01/14/2016: MIT-IA Passed to 4000 psi 12/22/2012: MIT-T to 2,500 psi passed (plug @ 8,807'MD) 01/29/2004: MIT-OA to 2,500 psi - passed N-01A Area of Review The wells within 1/4 mile of N-01A are listed in the table below (Map showing wells within 0.25 mi radius from N-01A figure 3). The measurements were made at the closest points between the wells within the Prudhoe Oil Pool. Three individual wells (including the N-01 parent) enter the AOR and the tables below summarize conditions. PBU Well API Number Distance Annulus integrity Name (ft) N-01A 50-029-20079-01 ---- TOC calc to be above injection zone behind 7" N-01 50-029-20079-00 1010 7/24/1974 CBL indicated fair cement quality above the Sag. The cement was poor quality in most places - however there was a good section (50') of cement existing (between 8,660- 8,710), combined with production history that had no evidence of barium scaling (which would be indicative of communication with the Cretaceous). These factors indicate zonal isolation. N-14B- 50-029-20594-70 1230 Only plugback is in AOR & it was cemented. PB1 However the TOC for the 7" liner of the parent well is calc to be above injection zone N-17 50-029-20898-00 1280 TOC calc to be above injection zone behind 9- 5/8" • • Well Name Csg Hole Volume of Cement Csg Top of size Size shoe Sag (MD) depth (MD) N-01A 7" 8-1/2" 35 bbls of 15.8 ppg Class G 8,968 8,957 N-01 9-5/8" 12-1/4" 9,309 8,613 82 bbls of Class G cement 310 bbls Class G gel N-14B-PB1 7" 8-1/2" PB: 8 bbls of 17 ppg class G 9,405 9,524 7" Liner: 59 bbls of premium Class G 15.7 ppg N-17 9-5/8" 12-1/4" 206 bbls 15.8 ppg Class G 8,720 8,758 23 bbls 15.7 ppg Arctic Set I NOTE: All calculated TOC's assume 30% washout of hole. N-27 N-27 Completion: N-27 is a conventional (max angle is 26°) well that was rotary drilled and completed in • November 2007 in zones 3 & 4. It was drilled with future UZI injection potential in Z4 as part of that justification. The well was pre-produced between 12/2007 and 10/2015, while waiting for approval and construction of the UZI project. The well has been SI and disconnected from the production system since 10/31/2015. N-27 is completed with 4-1/2", 13-Cr tubing and 4-1/2", L-80 liner (wellbore schematic Figure 2). When the well was drilled and completed in 2007, a 4-1/2" L-80 liner was run from 8,795 to 9,503'MD and cemented with 24 bbls of Class G cement. The 7" casing was run from 26' to 8,967'MD and cemented with 132 bbls of 12 ppg Lite Crete and 38 bbls of 15.8 ppg Class G. A CBL was run on September 12, 2007 in the 7" casing and it indicated an adequate cement bond with the TOC at 6,350'MD. A subsequent CBL run on November 28, 2007 showed a good to poor cement bond in the production liner. After the initial sundry was approved in 2015 (315-332), a caliper was run on January 12, 2016, indicating that there was corrosion across the L-80 liner. On June 28, 2016, a borax/RPM log was run. The log indicated channeling across the proposed perforation interval. A remedial cement squeeze (sundry 317-057) was performed on June 28, 2017. On 14 July, 2017, a subsequent borax log indicated that we had successfully fixed the channeling, and now have the desired conformance in upper zone 4. It is planned to operate N-27 as a WAG injector, we believe it to be suitable based on the most recent integrity tests, which are: • • 06/23/2017: MIT-T Passed to 2590 psi 01/14/2016: MIT-IA Passed to 4000 psi 07/09/2011: MIT-OA to 1200 psi passed N-27 Area of Review The wells within 'A mile of N-27 are listed in the table below (Map showing wells within 0.25 mi radius from N-27 figure 3). The measurements were made at the closest points between the wells within the Prudhoe Oil Pool. Two individual wells enter the AOR and the tables below summarize conditions. PBU Well API Number Distance Annulus integrity Name (ft) N-27 50-029-23365-00 9/12/2007 CBL indicated TOC @ 6,350'MD with an adequate bond . N-16 50-029-20886-00 710 TOC calc to be above injection zone behind 9- -3D 5/8". p4-�scje4v 07 • N-30 501029-23523-00 1200 TOC calc to be above injection zone behind 7" Well Name Csg Hole Vol Cement Csg Top of size Size shoe Sag (MD) depth (MD) N-27 7" 8-1/2" 132 bbls of Litecrete & 38 bbls of 8,967 8,964 Class G N-16 9-5/8" 12-1/4" 296 bbls Class G with gel 13.2 ppg 9,686 9,688 102 bbls Class G 15.8 ppg 23 bbls Arcticset 15.7 ppg N-30 7" 8-1/2" 47.3 bbls 15.8ppg Class G 9,151 9,150 NOTE: All calculated TOC's assume 30% washout of hole. Plan Forward: 1) Obtain Sundry for conversion of both wells to WAG injection. 2) Place N-01A on water injection in September 2017 3) Place N-27 on water injection in September 2017 4) AOGCC witnessed MIT-IA to 2500 psi on each well after injection has stabilized. • • TREE= 4'ON VYBINFAD• ILYVOY SAFELY NOTES:"••OOOA HAS 1440 CSG MAX ACfl.P TOR BAKER N-0 1 A IMT-000A 1200 PSI"' 19a t3Ey= 6210 "'"4-1/2"CHROME 1H0'•• 6F BEV= 43.19 KOH'= 3900 L 1100• 1--I13-3Ar DV PKRi Mix An.= s8.9 9277 Dat m PD= 91ST A Datum 8800 SS f/f 2147' 4-1/2"1�X NP,D=3.813' = 2201• �104.314 TN PKR 20"CSG,1330/940,PC-811 1 1440,D=19.121' H .4 .4•_, .565R• 10"64 r$1,5111"x11 1 10.9+4"can,w.cs.1.110,o-•.,s-H 2424" I• 2438 -1 TOP of Ca 'Nf(r Tt®ACIC L • 1!1Qt5 GAS LFT M1s { Y ST MU TVD OE3/ TYPE VLV LATCH PORT DATE H I1 5 3289 3288 3 K002 MAY BK 0 061416 13-318'C8O,866,K-56,D=12 416' -I 4200' 1/ 4 6 5569 0 103G2 MN M( 0 01114716 1 3 7208 7201 2 KBG2 MN BK 0 12721/12 14 2 793.5 7908 27 Kt40 ON BK 0 08104104 Minimum ID-3.725" 8807' • I. 1 8589 8392 50 163G2 DIM M( 0 0614716 4-1I2"HES XN NIPPLE t II 1 1 7171' I-r SKR'SMACK SEAL ASSY *OAT FORTS,V=6.19' I r TACK CSG 286,1-80 BTG D=8.278" ; 7181' 7171' 9.516'X r BKR ZXP LNR TOP RIR &MIC LNR HICA,D=8.261• I9 516''MM'5100( H 7318 j MLLOUT WINDOW 7316' 7332' I4.616•F7S1/(A7/7601)H 7316' Ilea STLA3(07103104) mu' $1 2 Mit 1 X NP, 3.613- N. 8762' -II'x4-1/2'BKRS-3PKRD=3.675' I III, $766' 174-1/2-FES X NP,Da 3.813" ..."-''..`,41 �. 8807' 3 _..-.-14.i/7 HES XN NIP,D.3.725" 19-518'CSG,474,P480,D 8661' 9301" I 5818' F r x 5'BKR ZXPLtw TOP R(R a MIC,LIR il►0i4i4a4i�i4'-i . FfJtOZ D=3-956' 6}��I. S — _ 11/41011.....111177"."*- PBtFORATDNSUNIARY — ' ' D=3456' 1 t a k H1F LOG:SYS-BM(S ON t t3V9I70(1701?) 4t'4141•ti444444��4411 ` 8636' j-5'x 4.1/7 xo, 1(85--'/A 0 ANCLEATTOP FEW:67'®9355' \ D=3956' Noir:Refer to Reduction 06*or pe Aaiorical rt data 4-112'7710,12.60,13CR TCI, 8819' 1 SIZE ^SPF INTERVAL 91427 041E SQZ 0152 big,D=3.956' 7/ 6 9380-9375 0 04/216106 2- I T LND R,284,1-80 BIC,0383. bp'. =6 276- 6966'_,. N. .. 2-7788"` 6 9380-9381 0 04/26106 2-78" 8 9380-9420 0 09/18701 2-7+8' 6 9394-9417 0 02/18108 2-716" 6 9430-9455 0 06121704 I FWD 1 9662 Iv -40, 1,24-i/7'T6G,12b6.1-80187-M,-0152 WI,D-346r 1---f,_.....1701{' DATE REV BY COMBOS LATE 141/f1Y 03449J18 I FRLDHOE BAY SMT 07/2414 ORIGINAL COMPLETION 12/27/12 RKT/,A.D GLV 00-SET TON PLUG(1221-Z WELL:N-OIA 00110817 MHO 01/28113 TFs'8.M) 'FEE 00(01/12713) I PERM-P '1041130 0//07104 N7E6 -SEETRICK(W01A) 41/28713 AMU) RILL TON PLUG aGLV 00(01724 AR Pb:50.029-20079-01 04/26106 GIB7PJC PERF CORRECTION(2/18706) 01/26+16 SW0,11,0 GLV 00(01/14716) SEC 8.T1114 R13E 1513 FSL a 550 FY6. 04726/06 GJBIPJC AOPB6' 09/05/08. .L)PJG PERF(07/25108) 9P EX/Aeration(Alaska) Figure 1 — N-01A Wellbore Schematic • • TREE= 4 4/18'CAN SAFETY NOM:'"4-1 Cr CHROME TOG**W ELL W8IFEAD= 11'FAC N_2 7 TWINNED TO N-06 ROW LAMP" ACTIATOR- :..., KB ELEv= 71.6' BF.ELEV= 45.8' I KOP= 5017 Ito Angle_ 26' 21817 =-I 991' H9-sts•TAM POFft COLLAR D=6.75' I DalumMD4 9162' I 2201' H4-1/7HES XHP.D"3.8131 LIumNO • 0 N-Pad UZI Injector 114 Mile Radius Map F._ . ...M�148 0 500 1000 •a•- 1 U.S.surveyor's feet •14A1464.09A 5970000 13 P: 14 _-04A t .148 — 4 ; 0 y �� `'a 5969000 t Ake." � All -07A t � 07 � 5968000 4 , -20.A d1 '�t,' a.. -20 a ' y •t , -02 ei ...I\ s �k 32;'-, 5967000 10t i 11 t I -27 ` t „;-21 5966000 a r a -12 / a -16 -30 a ,� • y � '' ,uJ 5965000 L "„A SA , . i _} 05 • 632000 634000 636000 638000 640000 Figure 3—Map showing wells within 0.25 mi radius from N-01A, N-07A & N-27 ! # 0C i �- N 4° N f / a) �a / N I a /I -O cco \\\di__..__—-——--- s_ a / I lip , rilifri F. 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CC ^ 'E' > I ►,: _ CI) c �`,, f0 � > a'' () Er, a) c a) o O r p c O ,„Q, F co • K O a = > o a0 0 ... C t. + d' M Q al O_ N C Q r.. ;.. ,x W U LL LL U LL 3 p a cc, a ° a a a ~ �` r� U a a �� o La.! MM W to UJ U I> 1W fGy U Q \' �` W30 0 , a VD M t/SN �'�„ co u FLL O J O J J o J J J Z W d 3 3 W 41t")", 4. w w Q a < < a < a < g CO Y CO CO CO CO CO CO m Q W D W W W W w W w z 0 Y 0 0 0 0 0 0 0 1 4.11 p I Q 2 S 2 2 2 = S 0Z 0 0 0 0 0 0 0 a L.-1 = O > > > > > > Qceccreccrecece 1 4-, vl s a. a a a a a a a \1C a o 0 I"... W t0 N ....CO to O N X N _ U'7 LU �',', p N O 1!') • N t0 Q� (V 0 0 0 0 0 0 0 0 1pcn O O O O O O O O O MIN 0 0 0 0 0 0 0 0 0 0 �-' W (I " 3a2om2moo a) ` m _ ai (' O w r p O p 0 0 0toea W = x ^ ° a O Q W 0CO U 0 Cr Lc) O coO O O O O O O O Q O) a0 N r If) N CO N) C) 3 0 tO CO O S CO N CD O N N CD 0 CD N CO CO O N N N N N N N N N N C C c F.:- O O) Cn O) O O) O) m O) O N N N N N N N N N C O Q) ° 99coco O O O N �. C V 0 0 0 0 0 0 0 0 0 y, 4'' N CO C Cl) N t[) N N N t() to N Q -0aJ a) CO W W Y w 1' N U Y --1 CD U a n � � 'O �� Z aJ '"+ Q M 'm7 N — L m Q r N N a) C N w e K N fr1 2 0 N r O '- O N M +,E co h U cc Ca Q O N W O Z ,_ ,- O V V Z 'a IA Z N 0 'c C� p u cco C o c a c • OF Tit • �.P" Iy;,- s,, THE STATE Alaska Oil and Gas N�'►, of�T ® c Conservation Commission Ll 1 V s ' t =. 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 S�P Main: 907.279.1433 Fax: 907.276.7542 ALA www.aogcc.alaska.gov Julie Wellman Production Engineer BP Exploration(Alaska), Inc. SCMIHESMAR ` P.O. Box 196612 Anchorage,AK 99519-6612 Re: Prudhoe Bay Field,Prudhoe Bay Oil Pool,PBU N-27 Permit to Drill Number: 207-104 Sundry Number: 317-059 Dear Ms. Wellman: 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, P Cathy P Foerster Chair DATED this (C: day of March, 2017. RB 1"^ S t_ MA,? 2 3 2017 '.. ECEIVED • STATE OF ALASKA FEB 0 1 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION 3 APPLICATION FOR SUNDRY APPROVALS � 17 t 20 AAC 25.280 .t�1 j 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Repair Well Q • Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Appr8ve`drrogram 0 /' Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other ChanneVpCCgqueez✓eH Q • 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 207-104 . Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development Q. 3. 6. API Number: 50-029-23365-00-00 • 99519-6612 Stratigraphic 0 Service 0 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No Q PRUDHOE BAY UNIT N-27 - 9. Property Designation(Lease Number): 10. Field/Pools: ADL 0028282 • PRUDHOE BAY.PRUDHOE OIL 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): 9505 • 9110 • 9417 9023 9197 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"91.5#H-40 28-108 28-108 1490 470 Surface 3192 9-5/8"47#L-80 28-3220 28-3065 6870 4760 Intermediate 8941 7"26#L-80 26-8967 26-8583 7240 5410 Production Liner 708 4-1/2"12.6#L-80 8795-9503 8416-9108 8430 7500 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment 4-1/2"12.6#13Cr80 13Cr80 23-8804 Packers and SSSV Type: 5"Baker ZXP Top Packer Packers and SSSV MD(ft)and TVD(ft): 8806, 8426.60 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary 0 Wellbore Schematic Q 13.Well Class after proposed work: Detailed Operations Program Q BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 Service Q• 14.Estimated Date for Commencing Operations: 3/15/17 15. Well Status after proposed work: Oil, l,( WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 „-'' WAG Q • GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Wellman,Julie be deviated from without prior written approval. Email Julie.Wellman@bp.com Printed Name Wellman,Julie Title Production Engineer Signatures) �- ( Phone +1 9075644657 Date 1/31/17 V\.J COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: t—‘c 3 I% S I a Post Initial Injection MIT Req'd? Yes 0 No Spacing Exception Required? Yes 0 No ri Subsequent Form Required: /0 ---<H>4- Approved by: ..9„4.4.4.4_,Cie, COMMISSIONER COMMISSION Date: 3-( _/ u Hi 1 [/7L 3/l S/ P APPROVED BYTHE ,..R G I )GIN !'� �,,, [^y P Irl .l S L .,a y? 2 •i 2017 Ale .24/7 � �_L: t7 Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • • Wel!work Procedure Request To: Well Services Operations Team Lead Date: 10/06/2016 Wireline Operations Team Lead AFE: From: Josh Allely -Well Intervention Engineer IOR: Est. Cost: Subject: N-27 Channel Squeeze Please perform the following steps 1. E Tag TD. Set composite retainer. 2. F A/EL: Load Tubing. MIT-T. 3. C Cement Channel Squeeze. 4. C Mill Composite Retainer and Cement. 5. E Reperf. Borax Log. IPROF. Set Packer 6. F A/EL: Injectivity. Borax Log. 7. SP Change out orifice insert Current Status: Minimum ID: 3.725" at 8792' MD. HES XN Nipple Max Deviation: 26deg at 2180' MD Top Perf Deviation: 12deg at 9073' MD. Injectivity 5.0 bpm at 500 psi WHP (observed during borax log) Last TD Tag: 04/01/16: SL tagged TD with 3-3/8" dummy guns at 9184' SLM. Last Downhole Op: 06/28/16: EL adperf/ borax log. SBHP/SBHT: 09/16/13: 3220 psi and 221degF at 8800' TVDSS. Latest H2S: 03/15/15: 6 ppm. AnnComm Status: Not-Operable due to injector conversion. No annular communication. Program Contacts Contact Phone -Work Phone -Mobile/Home Interventions Engineer Josh Allely 907-564-5732 907-350-7362 Pad Engineer Julie Wellman 907-564-4657 907-265-4397 Page 11 of 9 E-line Drift. Set composite retainer. 1. Drift to the top of the WRP /WRP pulling tool for depth determination with a GR/CCL. 2. Arrange to have LRS load tubing with 290 bbls of 1% KCI followed by 70 bbls of diesel for freeze protect (extra needed for CT displacement). 3. Set HES 4-1/2" composite cement retainer at 9046' MD. Caliper indicates that the tubing has full ID to this depth and SL has drifted past this depth with a 3.67" centralizer. 4. Have LRS perform a MIT-T to 2750 psi applied / 2500 psi target. LLR if test fails. Coiled Tubing Cement Channel Squeeze. 5. Perform a block cement squeeze of the liner with a combination of HES FineCem and class G cement. See [Appendix A] for a detailed procedure. Coiled Tubing Mill Composite Cement Retainer and Cement. 6. Mill through composite retainer and cement down to top of WRP. This is roughly 145' of milling (9046'-9190' MD). 7. Pressure test cement E-line Perf. Borax Log 8. Perf per attached perf sheet. 9. Borax Log Parameters • 100 bbls of Borax (do not pump more borax into the formation than necessary to complete the log). • 650 bbls of 1% KCI. i. 210 bbls for the initial kill (if necessary ii. -20 bbls for baseline passes iii. 140 bbls for borax displacement iv. 280 bbls for overflush • Interval to log 9000-9190' ELMD (PBTD). 10. MU and RIH with RST logging tool with fullbore spinner. RIH to just above TD. 11. Establish injectivity with -30 bbls of diesel or methanol with max pressure of 1600 psi. Well needs at least 0.5 bpm of injectivity at 1600 psi to perform log. 12. Liquid pack the well bore with 210 bbls (1.5x volume to perfs) of 1% KCI • This step can be skipped if the well remains liquid packed after perforating which is highly likely. 13. Lower rate rate to -1.0 bpm (or whatever injectivity is at 1600 psi) and log one baseline pass at 20 fpm followed by a repeat baseline pass at 60 fpm over interval 9190-9000' MD. 14. Pump -100 bbls of borax followed by 1% KCI at -5.0 bpm. 15.After injecting 30 bbls of borax into the formation, lower rate to rate to -1.0 bpm (or whatever Page 1 2 of 9 • injectivity is at 1600 psi) and log a borax pass at 60 fpm over interval 9190'-9000' MD. 16. RBIH to 9190' MD and increase pump rate such that 60 bbls has been displaced into the perfs when toolstring is at the bottom interval. 17.After injecting 60 bbls of borax into the formation, lower rate to 1.0 bpm and log a repeat borax pass at 60 fpm over the same interval. Volume from TD to top of interval is -4 bbls. This leaves over 35 bbls of extra borax to perform the last pass. 18. Send data to david.itter@bp.com. Call APE with field splits for decision on which insert, if any, to run in packer. 19. Pump an additional 280 bbls of 1% KCI to flush the borax from the near wellbore. 20. Freeze protect well with 38 bbls of diesel. 21. RIH w/ packer with 2-7/8" nipple with any orifice insert specified by APE. Set with mid element at 9903' ELMD. Slickline Contingent pull blank/set orifice insert- 1 month after E-line step 22. If a blank insert was set in step 21, pull blank insert 23. Set choke insert in packer nipple. Size to be determined by APE using results of IPROF and initial injection rate. Page 13 of 9 • • APPENDIX A: CT Operation for N-27 From: Josh Allely— Intervention Engineer Contact: 907-350-7362 Notes: • The objective of this procedure is to perform a channel squeeze so that the "UZI" perfs can have - hydraulic isolation from the Z4 perfs and to achieve isolation between the UZI perf sets. • Given the poor condition of the liner, this job is designed as a block squeeze through a cement retainer to keep the cement in place. This will increase the odds of success even if a true "squeeze" is not obtained. • This job is designed as a "two stage" cement job (though the cement will all be pumped at the same time) where the mircofine cement will be pumped first to try and fill the channels with cement, followed by class G to create perf nodes and trap the FineCem cement in the channel. Cement Design (FineCem Cement): BHST—220 deg F. SBHP— 3250 psi. BHCT—220 deg F Cement: FineCem. Batch mixed with onsite QC. Density: 13 ppg Thickening time: 7-10 hours API Fluid Loss: 5-15 cc Free Water: 0 Compressive Strength: Minimum of 2000 psi Requested Volume: 20 bbls - The slurry should be smooth and homogenous. - There should be no free water or gelation of the slurry. Cement Design (Class G): BHST—220 deg F. SBHP — 3250 psi. BHCT—200 deg F Cement: Class G cement. Batch mixed with onsite QC. Density: 15.8 ppg Thickening time: 7-10 hrs. API Fluid Loss: 160-240 cc. (80-120 cc/30 min TEST) Free Water: 0 Filter Cake: 0.75"-1.0" Compressive Strength: Minimum of 2000 psi Requested Volume: 20 bbls - The ratio of cake thickness to filtrate volume should be consistent with lab results. - The filter cake should be firm and dry. - The slurry should be smooth and homogenous. - There should be no free water or gelation of the slurry. Page 14 of 9 • • Cement Ramp Time Druation Temp Pressure Activity 0:00 2 90 0 Mix/Shear 2:00 0.5 90 0 QC Cement 2:30 1 90 4000 Pump 3:30 1 200 3300 Laying in 4:30 1 220 4000 Contaminate 5:30 220 4000 Done Planned Procedure 1. MIRU CT. 2. MU and RIH with cement retainer stinger (no check valves). 3. Well should be a closed system so returns will need to be taken from the backside while RIH. Sufficient freeze protect should be in place in the well such that when the BHA reaches the retainer, the well will still have a full 2500' of freeze protect. 4. RIH and set down on retainer at 9046' ELMD. 5. Establish injectivity into the formation by injection fluid into the reservoir. 6. Pressure up the backside to verify no communication. 7. Batch mix 20 bbls of FineCem cement and 20 bbls of class G cement. 8. After cement passes QC, pump the following schedule down CT: a. Freshwater spacer. b. 20 bbls of FineCem c. 20 bbls of class G cement. d. Displacement fluid. 9. Downsqueeze cement into the formation until a squeeze is achieved, defined by 2000 psi of CT pressure and minimal pump rate, or until 1-2 bbls of cement remains in the CT (do not overdisplace cement). 10. Unsting from retainer and lay in 1:1 the remaining cement above the retainer. This cement will immediately be contaminated so it is not necessary to get any cement above the BHA; PUH keeping cement below BHA. 11. PUH to safety and prepare to reverse out cement. 12. Reverse out cement to 10' above the retainer pumping slick 1% KCI down the backside and up the CT. 13. POOH and FP well to 2500' MD. Wait on cement to reach 500 psi compressive strength. 14. MU and RIH with a 3.700" OD motor/mill assembly. 15. Tag TOC and correct depth to 9036' ELMD. This is the cement retainer set depth minus the 10' of cement placed on top. Verify these depths in the previous CT WSR report. 16. Mill cement down to WRP at 9197' ELMD using Powervis and 1% slick KCL. There should be a significant change in ROP when the WRP is reached. When this is seen, stop and POOH. Avoid milling excessively in the same spot near the WRP depth to minimize the sidetracking potential. If 9207 is reached without finding the WRP, stop and POOH. 17. POOH chasing returns at 80%. Page I5of9 • • Liner section to be cemented: Depth:9116.09 to 9159.9! Display Mode:Rotated Length:35.00 Davi81i0n:14 Rotation:302 Avg.Diameter:4.02 Min.Diameter:4.00 Max Pen.:17% 1 'i. �. I T Di,met�l ra,nn�nai.15 ass .to OE f 4., ; I .g ILVI) 415 G' 3.85 : : • . : � � : . , : � . : . : : : : : . : 3.15 1000 8100 .110 8V8 8188 9110 ' 1 , 1 ' ' 1 8100 Page 16 of 9 • • Schlumberger Company: BP Exploration (Alaska),Inc. Well: N-27 Field: Prudhoe Bay Borough: North Slope State: Alaska Slim Cement Mapping Tool v 5 SCMT / GR / CCL LL 28-Nov-2007 co 2286 FSL&4709'FEL Elev.: K,B 71.6 ft as z At Surface G L (7) ' o O u� a F D.F • u' Permanent Datum: MSL Elev.: 0 ft Z a. cd• z m -jt� Log Measured From: FEB 71.6 ft above Perm. Datum • o Drilling Measured From: FEB a • 6 76E API Serial No. Section Township Range m LE -J S t 50-029-23365-00 8 11N 13E Logging Date 28-Nov-2007 Run Number 1 Depth Griller 9418 ft Schlumberger Depth Bottom Log Interval 9418 ft Top Log Interval 8450 ft Casing Fluid Type Brine Salinity Density 8.6 Ibm/gal Fluid Level BIT/CASING/TUBING STRING Bit Size From To Casing/Tubing Size 4,500 in Weight 12.6 Ibm/ft Grade L-80 From 0 ft To 9503 ft .... ___......_ _..._.. ._ ._ _ Maximum Recorded Temperatures Logger On Bottom i Time 28-Nov-,2007 3:40 Unit Number ; Location 2150 Prudhoe Bay Onnnsrl rte/Qir T Q:mr,.,00 I fl Page 17 of 9 III • , o et r , . . -r.. t . . i P , , , , ,, . . + .,. . ... __ tl. 4 4 4 . t , i . _. ...,. . . . . . , .., . . , . . , I , r- '.. , , , . , . { . �''�• . : illi ' , t..m . ._. _.....-..gym,. t r.. T ...= ' t ' ' --t.'"*.' 1.4111111111 .. pi.... , , „ . ,..,. . It.' s_ - .. . -, E-Line Set Composte , -. . , . . Cement Retainer } - Mid Element at 9045' ., . -1,4115, . , , ,,: WI MD i i .. .. ._ mss • I R ' Page 1 8 of 9 • • ' [ I I I - Al ' + SSM ,-ct.c. 4 , p .. . ... . .... } i } Post Squeez c Perfs ill , .♦ i 9100 j} .4... I Set packer mid I element at 9103' .. ;. _ _ ELM© • 1,1 :, , 1 _ _, ,.. . i ‘ :. .' , ' .- ItTf Iraqi; Post Squeeze t- Rerss 8 !Ilii► !}:- #t. t i } • ?_} i 1 f � 1 j _.: - -# L IiUi lSat t t « t , • t • t 1 t 1 in P' ' i i i i ...9 I . .„ /I . . , k 1 i .,, : 4 !! Page 1 9 of 9 • ao Co N m N N CO CO L CO LO O) CIO N Cfl vcoLOocw y O) O N r` „ N o CO N- N- r` co ❑ CO co 00 co co H a 0 I- co O) IC) co t O) CO N CO Cfl N CO CO Ch • CO a) In co N W in CO CO CO CO CO O w 0 O 0 w z w Lu w 0 w 0 H H J 0_ W a) gg v0 0' m O O w Y Y 2 co - CO — C4' N CO J J J Q < (n W = N a) 00O O N _0 0 _0 W w w Z ❑ 0 (� 0 O) 0 z Z Z 0 J J a cya Q Q < = DO 0 d H E ~ 2 00 0 a a� a Z 0 Z H H < J < 2 2 2 O co co coca cn cn Q a MQ o W co co CA �Y N CO aN- 000 r-- O CD CD CD N W ❑ CS) O) ()) (S) (3) (3) Ca 00 cn co co co co cu CL 0 0 C • d d W C_ W OL Q Q Q Q CL 00 a 0 a, d a y H MCOC° oo � O CD❑ c- r r o c C) 0 0 r, O W J Z O N N N N Z IL 1 1 Q W 0 WJOJJ W NCV CV u d N N CV Z CL .7 J '7 WW W IL W O CO CO CO CO 0 1 ❑ W J J 0 Q m 0_ m cn IL rai c a ce a) E ca z N- N- N- ` r` r` N N N N N N N m a a C./) 0_ 0 -100 0 w a Z Z Z Z Z Z < < CO m IL cn cn d 0_ TREE 4-1/16"'CIW • SA NOTES: **4-1/2"CHROME TBG**WELL WELLHEAD= 11'FRAC ACTUATOR= BAKE N_2 7 TWINNED TO N-06 FLOW LINE** KB.ELEV711.6' BF.ELEV= ass' � KOP= 500' Max Angle= 26'@ 2180 .�--I 991' —f 9-518"TAM PORT COLLAR D=8.75" Datum MD= 9162* 2201' —�41/2'HES X NP,D=3.813" Dbtum1VD= 8800'SS V 20"CONDUCTOR,91.5#,H-40,D=19.124" —{ 108' 9-5/8"CSG,47#,L-80 BTC-M,D=8.68" —i 3222' , GAS LFT MAN BELS ST MD TVD DEV TYPE VLV LATCH FORT DATE 4 3811 3631 15 KBG2 DW BK 0 01/14/16 3 6100 5827 16 KBG2 OMY BK 0 01/14/16 7"CSG,26#,L-80 TC!XO TO L-80 BTC-M H 4714' )K X 2 7637 7301 17 KBG2 CMY BK 0 08/16/11 1 8629 8254 14 KBG2 DMY BK 0 01/14/16 ' , 8707' —14-112"FES X NP,D=3.813" Minimum ID (N-27)=3.725" @ 8792' 4-1/2" HES XN NIPPLE g ><- 8728' H 'X4-1/2"BKR S-3PKR,D=3.875" I 8761' H4-1/2"HES X NP,D=3.813" ' 4-1/2"HES XN NP,13=3.725" 8795' --+7"X 5"BKR C-2 ZXP LTP,D=4.440' TOP OF 7"LN2 —I8795' $804' —14 112"WLEG,D=3.958" 4-112"TBG,12.6#,13CR-80 VAM TOP, — 8804' .0152 bpf,ID=3.958' —I EOM TT LOGGED (DATE) 8813' —17"X 5'BKR FLEX-LOCK HGR,D=4.440 8823' --I5"X 4-1/2"XO,D=3.940" 7"CSG,26#,L-80 BTC-M,ID=6.276" —I 8967' • I 9033' H4-112"MARKER JONT PERFORATION SL Mr1A RY / REF LOG:SLB MMXGR ON 08/30/07 ANGLE AT TOP PERF:12"@ 9073' Note:Refer to Aoduction DB for historical perf data SIZE SPF INTERVAL Opn/Sgz DATE 2-7/8" 6 9073-9078 O 06/28/16 2-7/8" 6 9086-9091 0 06/28/16 2-7/8" 6 9109-9114 0 06/28/16 3-3/8" 6 9144-9164 0 11/27/08 2-7/8" 6 9172-9192 0 11/28/07 2-718" 6 9214-9219 O 11/28/07 9197' —HSIt 4-1/2"WRP PULLING TOOL&3.69"WRP (01/20/16)(DEPTH CORRECTID 01/19/17) PBTD — 9417' 1••••♦ 4-1/2"TBG,12.6#,L-80 BT-M, .0152 bpf,ID=3.958" -I 9503' DATE REV BY COMMENTS DATE REV BY CONSENTS FRUDHOE BAY UNIT 09/13/07 MES ORIGINAL COMPLETION 01/25/16 RCT/JMD SET FISH(01/20/16) WELL: N-27 12/04/08 TFA/PJC PERFORATIONS(11/27/08) 02/24/16 RCT/J14) GLV CO(01/14/16) PERMT No:t071040 07/31/09 RRO/PJC SET WRP(07/03/09) 07/05/16 BTNJMD ADPEFFS(06/28/16) API No: 50-029-233656-00 08/17/11 GJB/PJC GLV C/O(8/16/11) 01/19/17 JW/TLH PLUG/FISH CORRECT1ON SEC 8,711N,R13E,2285'FSL 8 571'FWL 09/20/11 TA!PJC GLV C/O(09/07/11) 03/29/12 LFA/JMD 7"CSG DEPTH CORRECTION BP Exploration(Alaska) (2-01- vo,k RECEIVO w 21555 IPliiiIl SEP 12 2016 PRINT DISTRIBUTION LIST BAKER HUGHES AOGCC Please sign and return one copy of this transmittal form to: COMPANY BP Exploration Alaska Inc. BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 DATA LOGGED °l/184/201(0 WELL NAME N-27 900 E. Benson Blvd. M K.BENDER Anchorage,Alaska 99508 FIELD Prudhoe Bay Unit to acknowledge receipt of this data. COUNTY North Slope Borough LOG TYPE RPM:PNC3D BHI DISTRICT Alaska --- LOG DATE June 28,2016 AUTHORIZED BY Paul Canizares EMAIL Paul.Canizares@bakerhughes.com TODAYS DATE September 9,2016 Revision STATUS Final Replacement: No Details: Rev. Requested by: COMPANY FIELD/ FINAL CD/DVD FINAL PRELIM LOGS (las,dlis,PDF,META, SURVEY REPORT ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS CGM,Final Surveys) (Compass) PERSON ATTENTION #OF PRINTS #OF F'HIN I S #OF COPIES #OF COPIES #OF COPIES n 1 BP North Slope. 0 0 0 0 0 EOA,PBOC,PRB-20(Office 109) D&C Wells Project Aids Agatha Rutka&Barbara Glassmaker 900 E.Benson Blvd. Anchorage,Alaska 99508 2 ConocoPhillips Alaska Inc. 0 1 1 0 0 Attn:Ricky Elgarico ATO 3-344 700 G Street Anchorage,AK 99510 3 ExxonMobil,Alaska 0 1 1 0 0 Attn:Lynda M.Yaskell and/or Lisa Boggs 3201 C Street,Suite 505 Anchorage,AK 99503 4 State of Alaska -AOGCC 0 1 1 0 0 Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *** 0 I 1 1 0 0 Attn:James Hyun 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 to*Stamp"confidential"on all material deliver to DNR 6 BP Exploration(Alaska)Inc. 0 I 0 1 0 0 0 Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 Attn:David Itter SCANNED NOV 0 4 2016 TOTALS FOR THIS PAGE: 0 4 4 0 0 TOTALS FOR ALL PAGES: 0 4 4 0 0 • • Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWelllntegrityCoordinator@bp.com> Sent: Tuesday,August 23, 2016 4:08 PM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M TL;AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers;AK, OPS PCC Ops Lead;Cismoski, Doug A; Daniel, Ryan;AK, GWO SUPT Special Projects;AK, GWO SUPT Slickline;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS Well Pad MN; 'chris.wallace@alaska.gov' Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R;Wellman,Julie; Regg,James B (DOA) Subject: NOT OPERABLE:Injector N-27 (PTD#2071040)Injector Conversion All, Injector N-27 (PTD#2071040) has been reclassified as Not Operable. As part of the injector conversion program, logging indicated channeling behind pipe. This well will require remedial cementing operations prior to conversion to injection. Thanks, Jack Lau (Alternate:Adrienne McVey) BP Alaska-Well Integrity Superintendent NOV 0 82.01B W:907.564.5102 C: 907.943.0296 H: x2376 From: AK, GWO SUPT Well Integrity Sent: Monday, July 04, 2016 2:18 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan; AK, GWO SUPT Special Projects; AK, GWO SUPT Slickline; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad MN; 'chris.wallace@alaska.gov' Cc: AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Wellman, Julie; 'Regg, James B (DOA) (jim.regg@alaska.gov)' Subject: OPERABLE: Injector N-27 (PTD #2071040) Injector Conversion All, Injector N-27 (PTD#2071040) has been reclassified as Operable.An MIT-IA passed on January 14th 2016 verifying two competent well barrier envelopes. Injection conversion surface piping work is complete and well is ready to be placed on injection. Plan forward: 1. Operation: Put on Injection 2. Fullbore:AOGCC MIT-IA once thermally stable Please call with any questions or concerns. 1 • Thanks •• • Ryan Holt Well Integrity—GWO Alaska (Alternate:Lee Grey) 0:(907)659-5102 H:2376 Email: AKDCWelllntegritvCoordinator@BP.com From: AK, D&C Well Integrity Coordinator Sent:Thursday, December 31, 2015 4:45 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Vohra, Prachi; AK, OPS Well Pad MN; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Sayers, Jessica; Dickerman, Eric; 'Regg, James B (DOA) (jim.reclg@alaska.gov)' Subject: NOT OPERABLE: Injector N-27 (PTD #2071040) Injector Conversion All, Injector N-27 (PTD#2071040) has been reclassified as Not Operable until well is ready to be brought online after completing the conversion from Producer to WAG Injector well.Sundry#315-332 have been approved for this conversion, with an AOGCC witnessed MIT-IA required once the well has stabilized on injection. Plan Forward: 1. Slickline:Set Dummy Gas Lift Valves, Caliper, RPM log, Pull WRP 2. Fullbore: MIT-IA 3. Electric line: Set CIBP 4. Fullbore: Injectivity test 5. Operations: POI 6. Fullbore:AOGCC witnessed MIT-IA once well has stabilized Please call with any questions or concerns. Kevin Parks BP Alaska-Well Integrity Coordinator GVV Global Wells Organization Office: 907.659.5102 WIC Email:AKDCWelIIntegrityCoordinator@bp.com 2 2.--1 ,-ai E • 2'"1 3 65 f'%'r JUL 07 201u BAKER PRINT DISTRIBUTION LIST HUGHES ADGCC Please sign and return one copy of this transmittal form to: COMPANY BP Exploration Alaska Inc. BP Exploration(Alaska)Inc. Petrotechnical Data Center, LR2-1 DATA LOGGED WELL NAME N-27 900 E.Benson Blvd. -7 N>S'/2mG ;vi. K.BENDER Anchorage,Alaska 99508 FIELD Prudhoe Bay Unit to acknowledge receipt of this data. COUNTY North Slope Borough LOG TYPE RPM:PNC3D BHI DISTRICT Alaska --- LOG DATE June 28,2016 AUTHORIZED BY Paul Canizares EMAIL Paul.Canizares@bakerhucihes.com TODAYS DATE July 3,2016 Revision STATUS Final Replacement: No Details: Rev. Requested by: COMPANY FIELD/ FINAL CD/DVD FINAL PRELIM LOGS (las,dlis,PDF,META, SURVEY REPORT ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS CGM,Final Surveys) (Compass) PERSON ATTENTION #OF PRINTS #OF H-IN I S #OF COPIES #OF COPIES #OF COPIES 4 4 4 4 4 4 1 BP North Slope. 0 0 I 0 0 I 0 BOA,PBOC,PRB-20(Office 109) D&C Wells Project Aids Agatha Rutka&Barbara Glassmaker 900 E.Benson Blvd. Anchorage,Alaska 99508 2 ConocoPhillips Alaska Inc. 0 1 I 1 0 0 Attn:Ricky Elgarico ATO 3-344 700 G Street Anchorage,AK 99510 3 ExxonMobil,Alaska 0 1 1 0 0 Attn:Lynda M.Yaskell and/or Lisa Boggs 3201 C Street,Suite 505 Anchorage,AK 99503 4 State of Alaska -AOGCC 0 1 1 0 0 Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *** 0 1 1 0 0 Attn:James Hyun 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 ***Stamp"confidential"on all material deliver to DNR INEMBI 6 BP Exploration(Alaska)Inc. 0 0 I 0 I 0 I 0 Petrotechnical Data Center,LR2-1 DEC /! 20i16 900 E.Benson Blvd. SCANNED V Anchorage,Alaska 99508 Attn:David Itter TOTALS FOR THIS PAGE: 0 4 4 0 0 TOTALS FOR ALL PAGES: 0 4 4 0 0 • • Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Sent: Monday,July 04, 2016 2:18 PM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M IL;AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers;AK, OPS PCC Ops Lead;Cismoski, Doug A; Daniel, Ryan;AK, GWO SUPT Special Projects;AK, GWO SUPT Slickline;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS Well Pad MN; 'chris.wallace@alaska.gov' Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R;Wellman,Julie; Regg,James B (DOA) Subject: OPERABLE:Injector N-27 (PTD#2071040)Injector Conversion All, Injector N-27 (PTD#2071040) has been reclassified as Operable.An MIT-IA passed on January 14th 2016 verifying two competent well barrier envelopes. Injection conversion surface piping work is complete and well is ready to be placed on injection. Plan forward: 1. Operation: Put on Injection 2. Fullbore:AOGCC MIT-IA once thermally stable Please call with any questions or concerns. Thanks, Ryan Holt Well Integrity—GWO Alaska (Alternate:Lee Grey) ED DEC 0 9 2U16 0:(907)659-5102 H:2376 Email: AKDCWellIntegritvCoordinatorPBP.com From: AK, D&C Well Integrity Coordinator -nt:Thursday, December 31, 2015 4:45 PM To: OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; AK, OPS PCC Ops Leal, ismoski, Doug A; Daniel, Ryan; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Su.= 'ntendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Vohra, Prachi; AK, OPS Well Pad MN; 'chris. . .ce@alaska.gov' Cc: AK, D&C Well Integrity •:• dinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; •icki, Oliver R; Morrison, Spencer; Sayers, Jessica; Dickerman, Eric; 'Regg, James B (DOA) (jim.regg@)alaska.gov)' Subject: NOT OPERABLE: Injector N-27 (PTD • 171040) Injector Conversion All, Injector N-27 (PTD#2071040) has been reclassified as Not Operable unti -II is ready to be brought online after completing the conversion from Producer to WAG Injector well.Sundry#315- - ave been approved for this conversion,with an AOGCC witnessed MIT-IA required once the well has stabilized on.•'ection. Plan Forward: 1. Slickline:Set Dummy Gas Lift Valves, Caliper, RPM log, Pull WRP 1 • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Thursday, December 31, 2015 4:45 PM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M TL;AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers;AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services Operations Superintendent;AK, D&C Wireline Operations Superintendent;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;Vohra, Prachi;AK, OPS Well Pad MN;Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator;AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Sayers,Jessica; Dickerman, Eric; Regg,James B (DOA) Subject: NOT OPERABLE:Injector N-27 (PTD#2071040)Injector Conversion All, Injector N-27 (PTD#2071040) has been reclassified as Not Operable until well is ready to be brought online after completing the conversion from Producer to WAG Injector well.Sundry#315-332 have been approved for this conversion,with an AOGCC witnessed MIT-IA required once the well has stabilized on injection. Plan Forward: 1. Slickline: Set Dummy Gas Lift Valves, Caliper, RPM log, Pull WRP 2. Fullbore: MIT-IA 3. Electric line: Set CIBP 4. Fullbore: Injectivity test 5. Operations: POI 6. Fullbore:AOGCC witnessed MIT-IA once well has stabilized Please call with any questions or concerns. Kevin Parks (Alternate: Whitney Pettus) BP Alaska-Well Integrity Coordinator GW Global Wells Organization SCANNED SEP 1 9 2015 Office: 907.659.5102 WIC Email:AKDCWellIntegrityCoordinator@bp.com 1 Loepp, Victoria T (DOA) From: Bailey, Denise G <denise.bailey@bp.com> Sent: Thursday, June 25, 2015 2:18 PM To: Loepp,Victoria T (DOA) Subject: Clarification to Sundry#315-330, 315-331 & 315-332 Follow Up Flag: Follow up Flag Status: Flagged When I submitted the 10-403's& associated documents for the conversion of N-01A, N-07A& N-27 from producers to injectors, it specified that the AOGCC witnessed MITIA will be at 4000 psi. This was incorrect-the AOGCC witnessed MITIA will be at 2500 psi. Please advise if this affects the sundry approval and/or what additional documentation you need. Thanks, Denise Bailey H, N, D&Q Pad Engineer (907)564-4749 denise.bailey(abp.com SCANNED JUL 2 12015 1 • of T14, I/j, Alaska Oil and Gas �� THE STATE OfAT ASKA Conservation Commission uttft = 333 West Seventh Avenue cetot wh GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALAS'' Fax: 907.276 7542 S�ANNEQ JUL 0 Q 205 www.aogcc.alaska.gov Denise Bailey Pad Engineer �} O '7— / 9- BP Exploration (Alaska), Inc. " P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU N-27 Sundry Number: 315-332 Dear Ms. Bailey: 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, Daniel T. Seamount, Jr. Commissioner //lit DATED this / day of June, 2015 Encl. RECEIVED STATE OF ALASKA MAY 2 7 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION \`A'4 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request' Abandon❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown❑ Suspend❑ Perforate❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well ❑ Re-enter Susp Well ❑ Other Convert to Injector • 0 2.Operator Name: 4 Current Well Class: 5.Permit to Drill Number: BP Exploration(Alaska),Inc Exploratory ❑ Development 0 • 207-104-0 . 3.Address. -6.Stratigraphic ❑ Service ❑ API Number. P.O.Box 196612,Anchorage,AK 99519-6612 50-029-23365-00-00 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? PBU N-27 , Will planned perforations require a spacing exception? Yes El No 9 Property Designation(Lease Number). 10 Field/Pool(s). ADL0028282 ' PRUDHOE BAY, PRUDHOE OIL . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft). Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft). Plugs(measured): Junk(measured): 9505 9110 • 9208 8819 9208 None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"91.5#H-40 29.26-109 26 29.26-109 26 Surface 3192 9-5/8"47#L-80 28.86-3221.18 28 86-3066.34 6870 4760 Intermediate 8941 7"26#L-80 25 68-8966.76 25 68-8583 28 7240 5410 Production None None None None None None Liner 708 4-1/2"12.6#L-80 8794.99-9502.76 8415.66-9107.67 8430 7500 Perforation Depth MD(ft). Perforation Depth TVD(ft): Tubing Size: Tubing Grade' Tubing MD(ft): See Attachment See Attachment 4-1/2"12.6#13Cr80 13Cr80 23.41-8803 85 Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD(ft)and TVD(ft): See Attachment for Packer Depths No SSSV Installed No SSSV Installed 12.Attachments: DescrOtion Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service Cl ' 14.Estimated Date for 15.Well Status after proposed work Commencing Operations: Oc-fo64 ' O I5 OIL ❑ WINJ El WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG 0 . GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17 I hereby certify that the foregoing is true and correct to the best of my knowledge Contact Denise Bailey Email Denise.Bailey@BP.Com Printed Name Denise Bailey Title Pad Engineer Signature06.frIl'il e7, Phone 564 4749Date Prepared by Garry Cation 564-4424 5P3/1.5COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number 32Plu315- 332- Plug g Integrity ❑ BOP Test r-, Mechanical Integrity Test /' Location Clearance ❑ Other: 0._a_ fc W/ fv7 c55 tCJ / J 7--//f rz',tv,r 1.4-7"-e-,---- S- bili cJ ' ] c 'cn., Spacing Exception Required? Yes ❑ No Ln Subsequent Form Required it - 4 G 1 APPROVED BY / /1 Approved by: 4 ).71.-----.. COMMISSIONER THE COMMISSION Date: !lG_ / Ls- yrL 6,/i k J! 5.- ORIGINAL ORIGINAL Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the date of r val. Submit Form and Attachments in Duplicate RBDM JUN 2 5 2015 , 67/o/c Perforation Attachment ADL0028282 Well Date Perf Code MD Top MD Base TVD Top TVD Base N-27 11/27/08 APF 9144 9164 8756 8776 N-27 11/28/07 PER 9172 9192 8784 8803 N-27 7/3/09 BPS 9213 9218 8824 8829 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF Packers and SSV's Attachment ADL0028282 Well Facility Type MD Top Description TVD Top N-27 PACKER 8727 4-1/2" Baker S-3 Perm Packer 8350 N-27 PACKER 8806 5" Baker ZXP Top Packer 8427 Area of Review PBU Wells N-01A (API No: 50-029-20079-01) N-07A (API No: 50-029-20137-01) N-27 (API No: 50-029-233656-00) This Area of Review is required prior to the conversion of N-01 A,N-07A and N-27 from producers to WAG injectors. This AOR discusses wells within 1/4 mile of each well's entry point into the Sag River formation. Current Status: N-01 A is currently an operable producer. The last well test on 05/02/2015 indicated 590 bopd, 57% watercut, and 21,281 scf/bbl GOR. N-07A is currently an operable producer. The last well test on 10/06/2013 indicated 0 bopd, 100% watercut. N-27 is currently an operable producer. The last well test on 04/26/2015 was 655 bopd, 28%watercut, and 33,962 scf/bbl GOR. All three of these wells are scheduled to be converted to WAG injectors in 2015 as part of the N-pad UZI (Updip Zone 4 Injection) Project. The UZI Project targets remaining oil where the gas cap has expanded into zone 4, and the gravity drainage process is less efficient. The UZI Project achieves improved recovery through pattern injection of water and/or MI. The area of UZI potential is generally identified as immediately upstructure of the existing WF/EOR area. If planned facility work to install MI and water injection headers is completed as scheduled, N-07A will be ready for injection as early as Q3 and N-01 A and N-27 in Q4 2015. N-01A N-01A Completion: N-01A is a conventional (max angle is 68°) well that was sidetracked in September 2004 in zone 4. It was side-tracked with future UZI injection potential in Z4. It is currently being pre-produced while waiting for approval and construction of the UZI project. N-01A is completed with 4-1/2", L-80 tubing (wellbore schematic Figure 1). To convert it to an injector, a plug will be set above the existing zone 4 perforations to ensure zonal isolation and new perforations will be shot in the bypassed oil lens in zone 4. The original well was drilled in 1970 and it was sidetracked in 2004. A CBL shows that the cement behind the original 9-5/8" casing was poor. However during the sidetrack in 2004, a new 7" liner was installed from 8,968'MD to 7181' MD' with a 7" scab liner cemented in place from 7181' to 2426'MD. The liner was cemented with 35 bbls of 15.8 ppg Class G cement. The estimated TOC is 7,884'MD. There are no cement bond logs for this section of pipe, but no abnormalities occurred with this cement job. 4-1/2"tubing was installed from surface to TD @ 9748'MD. It was cemented with 27 bbls of 15.8 ppg Class G cement. No abnormalities occurred with this cement job although—15 bbls were circulated back to surface. Operation of N-01 A as a WAG injector is not seen as an issue as long as the well passes an MIT-IA. The most recent integrity tests are: Dec. 22/2012—MIT-T to 2,500 psi passed(plug @ 8,807'MD) 12/21/2012 —MIT-IA to 2,500 psi passed 1/29/2004—MIT-OA to 2,500 psi -passed N-01A Area of Review The wells within 1/4 mile of N-01 A are listed in the table below. The measurements were made at the closest points between the wells within the Prudhoe Oil Pool. Three individual wells (including the N-01 parent) enter the AOR and the tables below summarize conditions. PBU Well API Number Distance Annulus integrity Name (ft) N-01A 50-029-20079-01 ---- TOC calc to be above injection zone behind 7" N-01 50-029-20079-00 1010 7/24/1974 CBL indicated fair cement quality above the Sag. The cement was poor quality in most places- however there was a good section (50') of cement existing (between 8,660- 8,710), combined with production history that had no evidence of barium scaling (which would be indicative of communication with the Cretaceous). These factors indicate zonal isolation. N-14B- 50-029-20594-70 1230 Only plugback is in AOR & it was cemented. PB1 However the TOC for the 7" liner of the parent well is calc to be above injection zone N-17 50-029-20898-00 1280 TOC calc to be above injection zone behind 9- 5/8" Well Name Csg Hole Volume of Cement Csg Top of size Size shoe Sag (MD) depth (MD) N-01A 7" 8-1/2" 35 bbls of 15.8 ppg Class G 8,968 8,957 N-01 9-5/8" 12-1/4" 9,309 8,613 82 bbls of Class G cement 310 bbls Class G gel N-14B-PB1 7" 8-1/2" PB: 8 bbls of 17 ppg class G 9,405 9,524 7" Liner: 59 bbls of premium Class G 15.7 ppg N-17 9-5/8" 12-1/4" 206 bbls 15.8 ppg Class G 8,720 8,758 23 bbls 15.7 ppg Arctic Set I NOTE: All calculated TOC's assume 30% washout of hole. N-07A N-07A Completion: N-07A is a conventional (max angle is 66°)well that was sidetracked in July 2004 in zone 2B and 2C. It was side-tracked with future UZI injection potential in Z4, and was pre-produced while waiting for approval of the UZI project. N-07A was online as a producer from 2004 until 2013 when it reached high GOR. An unsuccessful squeeze was attempted in mid-2013 and the well has been offline since. N-07A is completed with 4-1/2", 13-Cr tubing & 4-1/2", L-80 liner(wellbore schematic Figure 2). To convert it to an injector, a plug will be set above the zone 2 perforations to ensure zonal isolation and new perforations will be shot in the bypassed oil lens in zone 4. The original well was drilled in 1974 and it was sidetracked in 2004. CBL's were run in 1974 and 1985. Both confirmed good cement for the 9-5/8" casing above 10,150'MD, with the TOC above 9,650'MD. The 9-5/8" casing was cemented with 1270 sacks of Howco Light cement and 41 bbls of Class G cement. As part of the July 2004 sidetrack, a 7" scab liner was installed from surface to 8,921' MD. This was cemented with 106 bbls of 12.5 ppg Litecrete followed by 57 bbls of 15.8 ppg Class G cement. A 4-1/2" L-80 liner was run from 9,826' to 10,832'MD and cemented with 27 bbls of 15.8 ppg Class G cement. No cement bond logs were run in the liner as the tubing wasn't pulled. However a Borax log to look for channeling was run in 2006 and it indicated some channeling around the current perforations only. Operation of N-07A as a WAG injector is not seen as an issue as long as the well passes an MIT-IA. The most recent integrity tests are: 7/7/2013 MIT-IA to 2500 passed 9/17/2013 —cmt sqz— MIT-T to 1500 psi passed 7/22/2004 - MIT-T to 3500 psi passed 3/24/2001 MIT-OA to 1500 psi passed N-07A Area of Review The wells within 'A mile of N-07A are listed in the table below. The measurements were made at the closest points between the wells within the Prudhoe Oil Pool. Two individual wells (including the N-07 parent) enter the AOR and the tables below summarize conditions. PBU Well API Number Distance Annulus integrity Name (ft) N-07A 50-029-20137-01 3/29/85 CBL indicated TOC above 9,650'MD with a good bond N-07 50-029-20137-00 95 3/29/85 CBL indicated TOC above 9,650'MD with a good bond N-20A 50-029-21320-01 600 The 9-5/8" casing doesn't have good cement (according to CBL) in the N-20 parent wellbore. However the casing and parent wellbore is outside the AOR. Only the liner of N-20A sidetrack is in the AOR. There are no CBL's or Borax logs to show quality of cement in liner- however after 11 years of production, the well is still competitive and there's no communication with the GOC in the heel. This means that the 2000' of cement(based on volumes pumped) above top perfs provides isolation from the heel (and thus parent well). Well Name Csg Hole Size Vol Cement Csg Top of size shoe Sag (MD) depth (MD) N-07A 7" 8-1/2" 41 bbls of Class G 10,642 10,005 1270 sacks of Howco Light N-07 7" 8-1/2" 41 bbls of Class G 10,642 9,998 1270 sacks of Howco Light N-20A 4-1/2" 6" 70 bbls of Class G cement 12,585 9,315 NOTE: All calculated TOC's assume 30% washout of hole. N-27 N-27 Completion: corGtJ'. fee. P440"/ 4'04 of ce'P- (Pf4VV%j— N-27 is a convention�max/ange is 2yq6 well that was rotarydrilledll d and completed in November 2007 in zones 3 & 4. It was drilled with future UZI injection potential in Z4 and was pre-produced while waiting for approval of the UZI project. N-27 is completed with 4-1/2", 13-Cr tubing and 4-1/2", L-80 liner(wellbore schematic Figure 3). To convert it to an injector, the wireline retrievable plug (set in 2008 to isolate water in zone 3 perfs) will be pulled if possible, a new plug will be set above the existing zone 4 perforations (to ensure zonal isolation) and new perforations will be shot in the bypassed oil lens in zone 4. When the well was drilled and completed in 2007, a 4-1/2" L-80 liner was run from 8,795 to 9,503'MD and cemented with 24 bbls of Class G cement. The 7" casing was run from 26' to 8,967'MD and cemented with 132 bbls of 12 ppg Lite Crete and 38 bbls of 15.8 ppg Class G. A CBL was run on September 12, 2007 in the 7" casing and it indicated an adequate cement bond with the TOC at 6,350'MD. A subsequent CBL run on November 28, 2007 showed a good cement bond in the liner. Operation of N-27 as a WAG injector is not seen as an issue as long as the well passes an MIT-IA. The most recent integrity tests are: - 8/16/2011 MIT-IA to 3000 psi passed 7/9/2011 -MIT-OA to 1200 psi passed No MIT-T N-27 Area of Review The wells within '/4 mile of N-27 are listed in the table below. The measurements were made at the closest points between the wells within the Prudhoe Oil Pool. Two individual wells enter the AOR and the tables below summarize conditions. PBU Well API Number Distance Annulus integrity Name (ft) N-27 50-029-23365-00 9/12/2007 CBL indicated TOC @ 6,350'MD with an adequate bond N-16 50-029-20886-00 710 TOC calc to be above-injection zone behind 9- 5/8" — N-30 50-029-23523-00 1200 TOC calc to be above injection zone behind 7" Well Name Csg Hole Vol Cement Csg Top of size Size shoe Sag (MD) depth (MD) N-27 7" 8-1/2" 132 bbls of Litecrete & 38 bbls of 8,967 8,964 Class G N-16 9-5/8" 12-1/4" 296 bbls Class G with gel 13.2 ppg 9,686 9,688 102 bbls Class G 15.8 ppg 23 bbls Arcticset 15.7 ppg N-30 7" 8-1/2" 47.3 bbls 15.8ppg Class G 9,151 9,150 NOTE: All calculated TOC's assume 30% washout of hole. Plan Forward: 1) Obtain Sundry for conversion of all three wells to WAG injection. 2) Complete installation of produced water and MI headers. 3) Complete downhole work to convert wells to injectors. 4) Place N-07A on water injection in Q3 2015 (depending on timing of completion of surface work) 5) Place N-01 A on MI in Q4 2015 6) Place N-27 on water injection in Q4 2015 7) AOGCC witnessed MIT-IA to 4000 psi on each well after injection has stabilized. TREE= 4"C1W _—..---------.-._. ..._------- VIEI_LHEAD--_MCH,OY N'O 1 A SAFETY NOTES:"'OOOA HAS H-40 CSG MAX ACIL1A TOR- BAKING M1T-000A1200 P51" KB Fl EV- 62 117 "4-112'CHROME TBG ' BF ELEV- 43.19 KOP= 3900 - _. 1900* Fj3-3Rt ON PKR-1 Mot Angle= 68'@ 9277 --_ _ - - OktunMD= 9487 Datum TVD= 8800'SS 21 BT 41-112'F£S2 NI',I1)=3-81'3 7=1 2291' j4410-1.312;4.: -I to yd'w cuH 1 120'CBO,13381114k 11.116!410,D 19 124' 2088' ,t. v .� ?s,' I-{16 514 .9.518^X9-I [10.3/1 C10,55 50 NI10_D 9 953'J-L ?428' ; Ili 2426' --Tc)p OF r:f��tr•ur.:r trisnr:l(i NRI .._ 0 1i [,✓1.111 I AA N 1d I', _ i srA gt 1xC) 1Vb Otv{n'tt. VIV Anal PR Ix TE f 1 S :�9 3268 3 KBG2 DOME' BK 16 01/26/13, (13-3/8'CSC,8191,K-56,D=12 415' 1 { �0O' $ �I 4 5596 5589 0 ;11.13G2 00LE BK 20 01/26/13;. �. 3 7208' 7201 2 'KBG2 CAN BK 0 12/21/12] ii 2 7935 1908 27 IK8G2 MY BK 0 0604/04:' 3 Minimum ID=1725" @ 8807' ` 1 1' 1 a9 8392 SO ;KBG2 DAN BK 0 12/21/12, 4-112"HES XN NIPPLE ti li I t i 7171' 7'BKR MACK SEAL ASSY ... w/CMt FORTS.D=6 19' (7"TEBACK CSG 268.L-80 BTC,O=6.276' H 7181 L7171' 9-5/8'X 7'BKR ZXP LNR TCP PKR 8 FMC LN3 FN[3R,D=6,261' 19.5/B'wr;5,oac (-j 7318' - i MILLOUT WINDOMW 1318'-7332 1 (dam-ncv(mr7sxu)H 7336' 1 STUB(07103/041 i-�14'-1III‘ a742' M1/2'F4'SXfix,D=3.813' _ _ 87st I-1-77')t 4-1/2"p(RS-3 PKR 0=3 STY ( * _x_788'x4-112 HESXNP,D=3.811' ..-z. _ •' Ili 8801' ( {4 112"1103 XN NP,D-3 725' 9-511"CSG,476,N-80.IN-8 681' H 9309' I (�TOPPKRaFflncLnn ,4�VON,�A& ` MGR,D=3.958" 8818' 7'X5"BKRZXPLNR'' emereeee 8819' '4 1/2'WIG, F13fORATDN SUMAAR/ \ D.3 958' FEE LAG:SVS-81tS ON 10/09770(9-097) 4d.1141j1 j.�i4ij14 ` 8838' —i5-x4-1/2"Xo, ANGLE AT TOP PEW:67'0 9355' , I0=3.9:x6' Note_Refer to Production Cafe(tpeiorgd pert dale f 4-1/2*TBG 12 Qk 13GR TCII H 8819' I SEE SPF INTERVAL SI-IDT DATE SOZ .0152 opt D-3.ss8^ ` 1318' 6 9355 9375 0 07/25106 2a18' 6 9380-9394 0 04126106 17•1„.I .261 1-ao BTC. 0393 bp' n-6276" 1 1......8888' ! ` 2-718" 6 9380-9420 0 001181)4 2-718' 6 9394•9417 0 02118,06 2-710' 6 9430.9455 0 .0921104 (FOTO -1 116132' 441,111% , 14-112'T9G,12.80,L-80 BT-M,.0152 bpf,D=3.958' H... 9748'7 DATE REV BY COMENTS DATE F4A1 BY C011.1146T1TS 1 RU)HOE RAY LAST 07124/74 •IORIGIK LCOMPLETION 12/27/12 I0CT7.U) GI.VDO-SET XXNRLTG(12I21-Z Aft N-01A 06/10187 jFtWO 01/28113 TRP1AD TREE 00(01/12113) PERatNo`2041130 08107104 WEB 1SIOETRACK(140111) -01128/13 AMMO JUL XXN PLUG&GLV 00(01124 AR No 50-u79-260T9-Ot 04,2611)6 (30'PJC i PERE CORRECTION(2/18/06) SEC 8.Ti IN R13E 1519'Fs_A 556 FV(t. 04126/06 G.E/PJC AOPHE 09105108 JDPJC,PERF(07125(08) 1P E xpioratlon(Aka ka) Figure 1 —N-01A Wellbore Schematic • FREE= 4'FMX; SAFETY NOTES:•""4-1/2"CHROME TBO"'• WELLHEAD= MCEVOY,;. N-O i A ACTUATOR= BAKER'% MAL KB.ELE 6140" BF ELEV= 41.84' KOP- _ 3100' Max Angle- 66'at 10568' Mum LE-, 10401' t 4um TVD= 880055.; 2048' �-+95+8'PBR� I I 2119' 1 14-112"HES Y,NP,O=3.813'J '---"-'�.r..._ 2800' -t'BT TOC OF 9 570'X r ANNALS I 13-318'CSG 724,N-8D D 12.347 j F 2617 . 4 4 4 GAS LFT MANDRELS 4 ST. M1 TV f1 F/ TYRE I V1 V IATTH FORT DATE lir Minimum ID=3.726"@ 9811' 4 + 3315 3309 13 KBG-2 DOLE BK 16 09/18/13 4 3 6313 5578 47 KBG2 SO BK "20 0908113 4-112"HES XN NIPPLE 4 2 8434 7190 34 KBG2% OMY BK ' 0 07/23/34 1 96/7 8230 31 KBG-2 Oho' BK ' 0 07/23/34 7'8-7-01.13 LFR 284,L-80,.383 bpf,0=6.278' 1 892 4 ITOP or r on 8924' 4 .4 8931' -19.5/8'x r UNOUE OVERSHOT I 01-5/11-C210,4/0,1-00,0=8.841-�_49635• - 1 9748' H4-1'2•HFSX NP D-3813' , :1 11 9767' I jrX4-I7rSKRS-3ROL0=3-875" I 8790' --{41/2"145 x NP.115-3.613' 1 9811' _4-1/2-HES XN NP,0=3.725' 14-1/2"TBG,12.98.13CR-90,.0152 W,D=3.958" 9824' j 9824' `-14-1/7 WLEG,D=3.956' I 9828' --Ir X S"BKR ZXP LNR TOP RCR d FNGR,D=4 47 REF L SOB RST7SIG1N4 ON 08J04/01 9848" 1-1.9-X 4-1/2"X0.0"3 980/' r ANGLE AT TCP PERE.65'@ 10606' Note:Rater to Production OB for hsbrcal pert data MI l OUT V1M4]OW 10DY1 10031' 1 SIZE SPF MERVAL 1 Cpn/Spz SHOT 1., SO2 3-3/8" 6 10539-10559 S 08/10/34 '09/14113 ---:--- 33/8" 6 10571 10596 { S 08/10/04 109/141310479' 4112"MARKER 30NF I 7-/18" 6 10606 10676 0 09/71/13 3-3/5" 6 10634 10639 S 06/10814 i 09714/13 S II 13-117 TBG,9.34,N-80,D=2.882' i-1 10481' LPf1T0 i ; 10653' r4e�44es4 NNN41' s., ►lN.414l4 .,�• L r LW;294,N•BQ,D=6,194" —1 10642' ,A PM I-I 10745' ' 41. • 4-112'LNR 12.E 8 1-86. 0152 bpi,D=3 958" �'-+ 10832' DATE 4 REV BY COWEN/5 DATE REV BY COL/LENTS FFRU DHOEBAY IK 01/24)77 ORIGINAL COMPLETION 0926/13 V'.WJ.O GLV CO(09/19/13) WELL-N-07A 03/21189 I R*O 0926113 ATO/.4.0 ACPERFS(09/21713) FAW-"10 IT 41050 07/2S(W{JAF/TLH SIDETRACK(14-07.4) -- API P41 500292013/01 0601/04 t 4511/II H GI V 110 SFC 8,(11N,N13/,7219 F5) d 5/1'WN 0/,I/L 17 PJFYJMI A1171-0 14441-FB-F LAN-(0/726112) (917(o13 .1GLJ 4) CZvii SR3Z(09/14113) 111 --- 13P BtploralI0n(Ata4Aa) Figure2—N-07A Wellbore Schematic TREE= 4.1/16'CW YYF --D -----F -- SAFETY NOTE&•"4-112"CHROME TBG"WELL Lth£A - 11 MC! 84 NEO TON-0O FLOWLMIE"' ACTL.IATOR- BAKER' N-27 TW KB.ELEV= 718'1 BF ELEV= 458' f KOP" 500', Mex Angle- 26' 2180' 991' H9 518"TAM PORT COLLAR,10=8 75" I -Deur!,MD. 9162' 2201' H4112-1165XNP10=3813- I Datum TVD- 8800'551 20'CONDUCTOR,91-54.N40,10=19.124" 't I9-518"CSG,470,1-8013TC-14 0=888" H 9222' GAS LET MANDRELS ST NU IVO DEV TYPE VLV LATCH PORT DATE 4 3811 3631 15 K802 DONE BK 16 CO/137111 3 6100 5827 16 MG/ SO BK 20 09!07111 I7 CSG 780,L 80 T G XO To 1-80 BTC-M IJ I 4714' I--Ir C 7K 2 7637 7301 17 KBG2 DAN BK 0 06/16/1 1 1 8629 8254 14 KBG2 DAN BK 0 06/16111 1 8707' x41/2-HES X NP 0=3 813- I .� Minimum ID(N-27)•3.725"@ 8792' 4-112" HES XN NIPPLES ana' 7"X4-117'BKFS-3PKR0=3875 1 1, 4 117111' H 4-1 J2-HE.S X NP,0=3.813- I 1 1 8792' 4.117 HES XN NIP,10=3 725"I 8796 H7"X5"BKR C-2ZXPLTP,ID=4440" I ITOPOFT'LNR} { 8796'.. J 1 114 4112'TBC 12.84 13CR-00 VAM TOP 8804' 8804' 41/2 WLEG,10=3.958" 01 52 t1pf_ID-3958' �F iHMDTTOGGED CY1Tq 8813' H TE X 5"8KRLFLEX-LOCK HDR,ID=4(.440 I 8829' H5"X 4-112"X0 0-3 940'I IT CSG.269..L-60 BTC-M ID•6.278" 119F-=i77-1----41 IL iip--I 0099' H 411r mg Wel Jorr1 J PERFORATION SUMMARY REF LOG:SLB MOOR ON 08/30/07 ANGLE AT TOP PERF 12.0 9144' 14 Note:Rater to Production 0B for historical perf data SIZE SOF M-ERVAL Opn/Sqz 0,TE 3-318' 6 9144-9164 O 11/27/08 2-7/8" 8 9172-9192 0 11/28107 1.._..9208' H369"WRP(0743/09) I 2-7E' 6 9214-9219 C 11/26/07 PBTD 9417' ii1pe1r.r1 111111111 4,112'160. 1 12 60, -80 113T M, 0152 opt 0-3.958'F 9503' 110,14, DATE REV BY CONIVENTS DATE REV BY CONMENTS PRI.OHOE BAY UNIT 09113/07 N7E88 ORIGINAL COMPLETION 090105 JLJ/PJC GLV 0/0106/25/03) WELL N-27 11/26/07 JLJIPJC GLV GO 1204/08 TEA/PJC PERFORATIONS(11/271061 PERMIT ND"2071040 12/15107 TEL/PJC PEW ORATIONS(11/2E937) 07/31/8 RRLYPJC SET1ARP(07/0309I API No 50-029-233656-00 01/14/07 GLM'PJC ORLG DRAFT COFIRECTIONS 06117/11 GJB/PJC GLV C/O(8116/11) SEC 8,1-11/4,R13E,2285'FSL 6571 FWL 03/19/08 JCR/PJC IJRLG DRAFT CORRECTIONS 09/2111 TA/PJC GLV C/O 109107/11) 07/181108 KSB/JND GLV GO(07/0E08) 03129112 1FA/JN0 T'CSG DEPTH CORRECTION OP Exploration(Mask al Figure3—N-27 Wellbore Schematic N-Pad UZI Injector 114 Mile Radius Map ..,- t „-- -14B 0 500 1000. t1 U.S.surveyor's feet rl4A 5970000 sItIIui; 148P= 14 .20 ,� --.. .� ')j• `Y.02A 5967000 r 1 r 27 1 *. -21 5966000 ! ' - -12 16 • L - 30 09 -_ „. ' 5965000 44 A 05 632000 634000 636000 638000 640000 Figure4—Map showing wells within 0.25 mi radius from N-01A,N-07A & N-27 Roby, David S (DOA) From: Bailey, Denise G <denise.bailey@bp.com> Sent: Wednesday,June 10, 2015 3:38 PM To: Roby, David S (DOA) Cc: Richmond, Diane M; Lastufka, Joseph N Subject: RE: Sundry applications for conversion of PBU N-01A (PTD204-113), PBU N-07A (PTD 204-105), and PBU N-27 (PTD 207-104) Please see my answers below. Please call at 907-564-4749 if you need further clarification. Thanks, Denise Bailey H, N, D&Q Pad Engineer (907) 564-4749 denise.bailey@bp.com From: Roby, David S (DOA) [mailto:dave.roby©alaskc ] Sent: Tuesday, June 09, 2015 11:08 AM To: Bailey, Denise G Subject: Sundry applications for conversion of PBU N-01A (PTD204-113), PBU N-07A (PTD 204-105), and PBU N-27 (PTD 207-104) Denise, I'm reviewing your application to convert the three subject wells from producers to injectors and have a couple of questions for you. 1) If I'm looking at things correctly it appears that you're establishing a new flood patern and that these wells will be the initial injectors in this pattern, is this correct?Yes—these will be UZI (updip zone 4 injection) patterns. 2) It's pretty much a no brainer to convert the N-07A well to an injector since it has watered out but the other two wells are still pretty decent producers with reasonable GORs and water cuts. Why were these specific wells chosen for conversion? BP has had the idea for an UZI project in development for 8+years. There is oil stranded on the shale lenses that these injectors would sweep towards producers surrounding them. To complete this project, we've drilled new injectors(N-28& N-29) and are in the process of installing an MI and PW header to tie-in the converted producers&new injectors. The UZI injection on N-pad(including N-01A, N- 07A, N-27, N-28&N-29)is meant to cover most of N-pad, particularly the areas where lenses have been seen in surrounding wells. The UZI reserves model indicates that the incremental reserves recovered by converting N-27&N-01A(and losing current production)are greater than if we leave them as producers. N- 27 well was drilled as a future injector-we just pre-produced it while waiting for the UZI project to materialize. N-01A was side-tracked earlier than N-27, but its secondary objective was to maintain options for UZI injection. The UZI project has been sanctioned by partners and has been included in the GPB IPA Plan of Development for the last few years. Thanks in advance, 1 Dave Roby Sr. Reservoir Engineer Alaska Oil and Gas Conservation Commission (907) 793-1232 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 Dave Roby at(907)793-1232 or dave.robydalaska.gov. 2 Image Projeet Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~~ - F U ~' Well History File Identifier Organizing (done) ^ Two-sided III IIIIIIIIIII IIIII ^ Rescan Needed III IIIIIIIIII 111111 RE AN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: BY: Maria _ Project Proofing BY: Maria DIGITAL DATA iskettes, No. 1 ^ Other, No/Type: Date: ~ ~.. Date: i ~~ Scanning Preparation ~ x 30 = BY: `Maria Date: `a ~ Production Scanning OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: ~~j lsl Illlllillllllllllll ~ a 8 /S/ + ~ =TOTAL PAGES (Count does not include cover sheet) ~ /fin Q /s/ ~ r ~ IIIIIIIIIIIIIIIIIII Stage 1 Page Count from Scanned File: _~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES BY: Maria Date: 1 ~-, ` °~1 D g Stage 1 If NO in stage 1, page(s) discrepancies were found: YES BY: Maria Date: Scanning is complete at this point unless rescanning is required. NO !s/ NO "hiimmiiRUu ReScanned BY: Maria Comments about this file: Date: Quality Checked iiuiuiiiauu 10/6/2005 Well History File Cover Page.doc El „ 0 CI 0 0 0 CI 0 CI 0 0 0 0 OCCIO U; "' • 0 0 0 0 0 0 0 0 0 0 0 0 u u u u 't, .-I .I -I .i s..; .. \ O il U y. r til /-e ••• I O U 'U o M tt r � cu ? ti I Z * • i ( }-+ o = is +-' 7 fa) ' �' * W o_ N s Z. E-4 0 (3) • • Z '....")„,c\ Q? to r,) , z 1 c E ° 14 SCJ.1 r� ' ,7 OC ra U' Oro wl V 111 i X 0. ', i = C 1J1 Y R/ CI) oC) 1y N N N N N N N N N N N N I"' N N N N 4...1 < V r— •r- e--1 c-1 r1 c-1 c-1 ci c-I <- 0 c-1 c-1 c-1 �--I N N Q� 0 1 i _ — I > +�' 00 — d0 !? o. CC tic OU GO 4! f9 ,- (--, LU a _ c.1 o -, ? 0 v a> > 0 -- < < <0 f� �`' . , ° cn (' - Z9 < Q v1 v1 7 Z v o ,,• ) 0 O < N ON OM M M O� ci N J c4-1 N N N 51 C (� W �) r N LL 2 Q 'L c9' a a-, a il▪ l N O s .I- I- H I- I- U) U) CO Cn I- I- I- I- I- I- H Cr) O F- N H H fi. CC CC Ce CC cr cc cc. LL LL LL. 'L u_ U- u_ U- LL u. u_ w . O O O O O O O O O O O O 5, u_ tL '� w O O.O O H I— H H H H H H H H H F c H H H H 000000000000 * 0000 i W W W W w w w LUw w w W * LU LU LU LU ;ire, 1 U i =;'� X X X X X X X X X X X X X X X X 7V 1 ' 3t #H lii L w` U I— B w{ 1 CtJri ,, r� , e j Q' 6 ry M 1,0 Gl N N 00 a--1 N ifl1 IUU 0 co o ,� 9 m > ,� a1 CS _ _ °0 v. ,, o.. `{ �O-1 N m X Q LD-d- >- W - > ami 00 O w• o m U U U v, m: U m U m m U U m m U U O 00 -o u1 O Ln N • - > 61 OD cr) a fB m Ql lin Cr'.0 N CD • C c--1 C Q fp _ Y Z 9 to C '-7 qQ��ty-Z2 .0C • a t7 p O m m CO / M O 0 W -5 (-6y 1' a te _ � 'n r m � � � o o r� oo � N r> N M v a 0 u UNDER EVALUATION: Producer N -27 (PTD# 2071040) Sustained Casing Illessure Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator ©bp.com] Sent: Friday, July 22, 2011 11:51 PM 7 /?° ( a To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, RES GPB West Wells Opt Engr; AK, D &C Wireline Operations Team Lead; AK, RES GPB East Wells Opt Engr; AK, D &C Well Services Operations Team Lead; AK, OPS Prod Controllers; AK, OPS GC2 Field O &M TL; AK, OPS GC2 OSM; AK, OPS GC2 Ops Lead; Cismoski, Doug A; Daniel, Ryan; AK, OPS Prod Controllers; AK, D &C Well Integrity Coordinator Cc: Phillips, Patti J; Grey, Leighton (CH2M Hill); Townsend, S. Eliot; Reynolds, Charles (ALASKA) Subject: UNDER EVALUATION: Producer N -27 (PTD# 2071040) Sustained Casing IA Pressure Attachments: N -27 TIO Plot.doc; N- 27.pdf All, Producer N -27 (PTD #2071040) has confirmed sustained IA casing pressure due to TxIA communication during proration. The wellhead pressures were tubing /IA/OA equal to SSV /2200/0 on 07/22/11. The well failed a TIFL on 07/22/11. The well has been reclassified as Under Evaluation. The plan forward is as follows. 1. Slickline Dummy Gas Lift Valves 2. Fullbore MIT -IA SeP - 3o, s P 3. WIE Evaluate results for continued diagnostics /lace vk pc, C ?41Z- A TIO plot and wellbore schematic have been included for reference. «N -27 TIO Plot.doc» «N- 27.pdf» Please call if you have any questions or concerns. Thank you, Taylor Taylor Wellman filling in for Mehreen Vazir /Jerry Murphy ILA,N1 E JL, 2 Ali;', Office: 659 -5102 Pager: 659 -5100 x 1154 7/28/2011 PBU N -27 PTD 2071040 7/22/2011 TIO Pressures Plot Wef: N -27 4,000 3.000 f- Tbp — 21 — LA 2,000 — . - OA OOA — +— 000A On 1 .000 a �itY�... _t..,.*"/ 0E/03/10 09/03/10 10/04/10 11/04/10 12/05/10 01/05/11 02/05/11 03/00/11 04/08/11 05/09/11 06/09/11 07/10/11 • �Il�i TREE »» 4-1/16" CM/ WELLHEAD = 11' FMC • SAFETY S: "4-1/2" CHROME TBG** WELL ACTUATOR = BAKER N -2 7 TWINNED TO N-06 FLOW LINE- . . .... KB. ELEV = 71.6' BF. ELEV = 45.8' KOP = 500' Max Angle= 26"@21&Y -.. = 991' H9-5/8" TAM PORT COLLAR, ID = 8.75" 1 Datum MD = ---- 9162' -8.£366.'s -----I 2201' H4-1/2" HES X NIP, ID = 3.813" 1 120" CONDUCTOR, 91.5#, H-40, ID = 19.124" H 108' 19-5/8" CSG, 47#, L-80 BTC-M, ID = 8.68" H 3222' IA I, GAS LIFT MANDRELS ST MD 1VD DEV TYPE VLV LATCH PORT DATE 4 3811 3631 15 KBG2 DOME BK 16 08/25/08 3 6100 5827 16 KBG2 DOME BK 16 08/25/08 17" CSG, 26#, L-80 TCII XO TO L-80 BTC-M H 4714 1 ).< x 2 7637 7301 17 KBG2 DOME BK 16 08/25/08 4-1/2" HES XN NIPPLE ) 1 8629 8254 14 KBG2 SO BK 24 08/25/08 r---I 8707' H4-1/2" HES X NIP, ID = 3.813" 1 Minimum ID (N-27) = 3.725" @ 8792' 8728' H7" X 4-1/2" BKR S-3 PKR, D = 3.875" 1 I 1 1 8761' H4-1/2" HES X NIP, ID = 3.813" 1 ir ---I 8792' H4-1/2" HES XN NIP, ID = 3.725" 1 111 8795' HT X 5" BKR C-2 ZXP LTP, ID = 4.440" 1 'TOP OF 7" LNR H 8795' . . / " !!.. I 8804' j---14-1/2" WLEG, ID = 3.958" 1 4-1/2" TBG, 12.6#, 13CR VAM TOP, 8804' '*; .0152 bpf, Or 3.958" I HB_MDIT LOGGED (DATE) 1 8813' j—I R, 7" X 5" BKR FLEX-LOCK HG ID = 4.440 1 8823' H5" X 4-1/2" XO, 0 = 3.940" 1 17" CSG, 26#, L-80 BTC-M, ID = 6.276" j--I 8867' I A ■ NtIte 72 1 90' H4-112" MARKER JOINT I PERFORATION SUMMARY REF LOG: SLB MWD/GR ON 08/30/07 I ANGLE AT TOP PERF:12° @ 9144' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 9144 - 9164 0 11/27/08 I 9208' 1-13.69" WRP (07/03/09) 1 2-7/8" 6 9172 - 9192 0 11/28/07 2-7/8" 6 9214 - 9219 C 11/28/07 I 1 PBTD I 9417' I • • 14-1/2" TBG, 12.6#, L-80 IBT-M, .0152 bpf, ID = 3.958" H 9503' , A. .....k DATE REV BY COMMENTS I DATE REV BY COMMENTS PRUDHOE BAY UNIT 09/13/07 N7ES ORIGINAL COMPLETION 09/01/08 JLJ/PJC GLV C/O (08/25/08) WELL: N-27 11/26/07 JLJ/PJC GLV C/O 12/04/08 TFA/PJC PERFORATIONS (11/27/08) PERMIT No: '2071040 12/15/07 TEL/PJC PERFORATIONS (11/28/07) 07/31/09 RRD/PJC SET WRP (07/03/09) API No: 50-029-233656-00 01/14/07 GLM/PJC DRLG DRAFT CORRECTIONS SEC 8, T11N, R13E, 2285' FSL & 571' FWL 03/19/08 JGR/ PJC DRLG DRAFT CORRECTIONS 07/18/08 KSB/JMD GLV C/O (07/06/08) BP Exploration (Alaska) 1 ,~~ ~~,. ~. u.~ ~~~ ~~.: ~-- ~ "' 4 ~ ~ ~ ~ ` ~~ ~ ~~~ ~ ,~ ~ '~ A ~ ~; _ ~t .. - ,. ~`~~ MICROFILMED 6/30/201.0 DO NOT PLACE ANY NEW MATERIAL .UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc r ~ ~ ~~ ~ ~ STATE OF ALASKA ~,~,/v A>LAS IL AND GAS CONSERVATION COMMI ON I~~v REPORT OF SUNDRY WELL OPERATIONS i:~~T 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ Other Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate Q ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~ - Exploratory 207-1040 3. Address: P.O. Box 196612 Stratigraphic I` Service ~~ 6. API Number: Anchorage, AK 99519-6612 50-029-23365-00-00 7. KB Elevation (ft): 9. Well Name and Number: 71.6 RT PBU N-27 - 8. Property Designation: 10. Field/Pool(s): ADLO-028282 - PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 9505 - feet Plugs (measured) None Junk (measured) None true vertical 9109.87. feet y~.~ hl~~~ L~l~f ~"~~~, ~l~ c~' ~~Lf av~l . Effective Depth measured 9417 - feet true vertical 9023.47 - feet Casing Length Size MD TVD Burst Collapse Conductor 108' 20" 91.5# H-40 Surface - 108' Surface - 108' 1490 470 Production 3221' 9-5/8" 47# L-80 29' - 3221' 29' - 3066' 6870 4760 Liner 8584' 7" 26# L-80 26' - 8967' 26' - 8584' 7240 5410 Liner 708' 4-1/2" 12.6# L-80 8795' - 9503' 8416' - 9108' 8430 7500 Perforation depth: Measured depth: SEE ATTACHMENT - _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13CR-80 Surface - 8804' 0 0 - Packers and SSSV (type and measured depth) 7-1/2"X4-1/2" BKR S-3 8728' 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): 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: 292 4049 3391 185 Subsequent to operation: 156 2437 1837 1185 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~ Development ~ Service Daily Report of Well Operations X 16. Well S tus after proposed work: /' ~ Oil ~ Gas WAG ~ GINJ WINJ ( DSPL 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: N/A Contact Gary Preble ~~~ ~ ~oa~ Printed Name Gary Pre Title Data Management Engineer Signature Phone 564-4944 Date 12/5/2008 Form 10-404 Rev 04/2006 ~ ~/a~ Submit Original Only N-27 207-104 PERF ~4TT~4CHMENT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base N-27 11/28/07 PER 9,172. 9,192. 8,783.65 8,803.2 N-27 11/28/07 PER 9,213. 9,218. 8,823.73 8,828.62 N-27 11/27/08 APF 9,144. 9,164. 8,756.29 8,775.83 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • .. N27 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 11/26/2008 ***WELL SHUT-IN ON ARRIVAL*** INITIAL T/I/0= 1200/1720/0. CURRENTLY RIGGING UP ELINE UNIT FOR PERFORATING. ***JOB CONTINUED ON 27-NOV-2008 WSR*** 11/27/2008 T/I/O = 1900/2020/0. Temp = 138*. OA FL (OA FL campaign). AL is connected & online. OA FL @ 42' (1.25 bbls). SV =closed. WV, SSV, MV =open. IA, OA = OTG. NOVP. 11/27/2008***JOB CONTINUED FROM 26-NOV-2008*** PERFORATED W/ 3-3/8" POWER JET 3406 HMX GUN 6SPF 60* PHASING rl"fl1AI AA AAl f1A I±A1 TIED INTO SHORT JOINT ON SCMT LOG DATED 28-NOV-2007. TD NOT TAGGED. PAD-OP NOTIFIED OF VALVE POSITIONS UPON DEPARTURE. FINAL T/I/0= 1200/1700/0 ***GAVE WELL BACK TO POP/ JOB COMPLETE*** FLUIDS PUMPED BBLS 1 diesel 1 Total DATA SUBMITTAL COMPLIANCE REPORT 11 /19/2008 Permit to Drill 2071040 Well Name/No. PRUDHOE BAY UNIT N-27 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23365-00-00 MD 9505 TVD 9110 REQUIRED INFORMATION Completion Date 11/28/2007 Completion Status 1-OIL Current Status 1-OIL UIC N Mud Log No Samples No Directional Survey Yes r' DATA INFORMATION Types Electric or Other Logs Run: DIR / GR, DIR / GR /RES / PWD, DIR / GR /RES / NEU /DEN, SCM Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Type Med/Frmt Number Name Scale Media No 25 Blu 25 Blu 5 Col ~E D Asc Directional Survey pt Directional Survey Log Cement Evaluation 5 Col 1 7ED C Las 15681 Induction/Resistivity QED C Lis 15711 Induction/Resistivity UI,Og 15711 Induction/Resistivity /Log 15711 Induction/Resistivity Log Cement Evaluation Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORM~ION Well Cored? Y(~(.Dl-]'~ Daily History Received? Y Chips Received? ~L/-AI1 Formation Tops / N Analysis Y1~li Received? 1 (data taken from Logs Portion of Master Well Data Maint Interval OH / Start Stop CH Received Comments 0 9505 Open 9/20/2007 0 9505 Open 9/20/2007 0 9416 Case 9/28/2007 CBL, SCMT, GR, CCL 12- Sep-2007 100 9504 Open 11/9/2007 DRHB, RPM, GR, NPHI, ROP, RPS w/PDS Graphics 100 9504 Open 11/27/2007 LIS Veri, GR, ROP, FET, RPS, RPM, DRHO, NPHI w/ PDS and Tif graphics 100 9505 Open 11/27/2007 MD Vision Service 100 9505 Open 11/27/2007 TVD Vision Service 8450 9418 Case 1/22/2008 SCMT, GR, CCL 28-Nov- 2007 Comments: DATA SUBMITTAL COMPLIANCE REPORT 11/19/2008 Permit to Drill 2071040 Well Name/No. PRUDHOE BAY UNIT N-27 Operator BP EXPLORATION (ALASKA) INC MD 9505 TVD 9110 Completion Date 11/28/2007 Completion Status 1-OIL Current Status 1-OIL Compliance Reviewed By: __ API No. 50-029-23365-00-00 UIC N __-..__ ---_ _--- ----- r~ - Date ~ _ VU ~ ---_= -_ OPERABLE: N-27 (PTD #20740) TxIA Communication ~ Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com]~~ ~. Sent: Friday, July 11, 2008 9:05 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; Engel, Harry R; NSU, ADW Well Operations Supervisor; NSU, ADW WL & Completion Supervisor; Zamora, Chris A; GPB, Optimization Engr; GPB, Wells Opt Eng; Rossberg, R Steven Cc: Holt, Ryan P (ASRC); NSU, ADW Well Integrity Engineer; Winslow, Jack L. Subject: OPERABLE: N-27 (PTD #2071040) TxIA Communication All, We11 N-27 {PTD #2071044) has passed a TIFL after changing out the orifice gas lift valve confirming tubing integrity has been restored. The well has been reclassified as Operable and may be returned to production with convenient. Please let us know if you have any questions. Thank you, Anna ~?u6e, ~? ~. Well Integrity Coordinator GPB Wells Group Phone: {907} 659-5102 Pager: (907} 659-5100 x1154 8/28/2008 UNDER EVALUATION: N-2~TD #2071040) TxIA Communication Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~P~q Sent: Thursday, June 26, 2008 6:50 PM (( / To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; Engel, Harry R; NSU, ADW Well Operations Supervisor; NSU, ADW WL & Completion Supervisor; Zamora, Chris A; GPB, Optimization Engr; GPB, Wells Opt Eng Cc: NSU, ADW Well Integrity Engineer; Roschinger, Torin T. Subject: UNDER EVALUATION: N-27 (PTD #2071040} TxIA Communication Attachments: N-27.pdf; N-27 90-day TIO Plot.doc All, Well N-27 (PTD #2071040) has been found to have sustained casing pressure on the IA. The TIOs were 2000/2000/0 psi on 06/26/08 when the well failed a TIFL. The well has been classified as Under Evaluation and placed on a 28-day clock. The plan forward for the well is as follows: 1. D: TIFL -FAILED 2. S: Change out S/O @ 6100' MD ~ 3. D: Re-TIFL A wellbore schematic and TIO plot have been attached for reference. «N-27.pdf» «N-27 90-day TIO Plot.doc» Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 8/28/2008 TREE= 4-1116" CIW WELLHEAD = 11' FMC ACTUATOR= BAKER KB. ELEV = 71.6' BF. ELEV = 45.8' KOP = 500' Max Angie = 26' @ 2180' Datum MD = 9162' Datum TV D = ~. ~. ~_ 8800' SS 20" CONDUCTOR, 91.5#, H-40, ID = 19.124" 9-5/8" CSG, 47#, L-80 BTGM, ID = 8.68" 7" CSG, 26#, L-80 TCII XO TO L-80 BTGM 7 SA~ NOTES: **4-112" CHROME TBG ** W ELL N ~2 f TWI ED TO N-06 FLOW LINE** 991' ~19-5(8" TAM PC?RT COLLAR, ID = 8.75" >.201' 4-1/2" HESXNIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3811 3631 15 KBG2 DOME BK 16 11/26r'07 3 6100 5827 16 KBG2 SO BK 20 11/26!07 2 7637 7301 17 KBG2 DMY BK 0 09li3/07 1 8629 8524 14 KBG2 DMY BK 0 09!13!07 Minimum Id (N-27) = 3.725" @ 8792' 8707' -j4-112" HESXNIP, ID=3.813" 4-112" HES XN NIPPLE 8728' 7" X 4-112" BKR S-3 PKR, ID = 3.875" $761' 4-112" HESXNIP, ID = 3.813" $792' 4-1/2" HES XN NIP, ID = 3.725" 8795' 7" X 5" BKR G2 ZXP LTP, b = 4.440" TOP OF 7" LNR 8795' 8804° 4-112" WLEG; ID = 3.958" 4-112" TBG, 12.6#, 13CR-80 VAM TOP, $804' QMD TT LOGGED (DATE) .0152 bpf, ID = 3.958" 8813' 7" X 5" BKR FLEX-LOCK HGR, ID = 4.440 8823' 5" X 4-1/2" XO, ID = 3.940" 7" CSG, 26#, L-80 BTGM, ID = 6.276" 9033' ~-j4-1l2" MARKERJOINT PERFORATK3N SUMMARY REF LOG: SLB MWDIGR ON 08/30107 A NGLE AT TOP PERF: 12` @ 9172' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnlSgz DATE 2-718" 6 9172 - 9192 O 1112$107 2-718" 6 9214 - 9219 O 11/28/07 PBTD 4-1;2" TBG, 12.6#, L-80 IBT-M, .0152 bpf, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS 09f13107 N7ES ORIGINAL COMPLETION 19726107 JLJIPJC GLV C!O 12/15/07 TELIPJC PERFORATIONS {11/28!07} 01114!07 GLMdPJC DRLG DRAFT CORRECTIONS 03119/08 JGRJ PJC DRLG DRAFT CORRECTIONS PRUDHOE BAY UNff WELL N-27 PERMCr No: 2071040 API No: 50-029-233656-00 SEC 8, T11 N, R13E, 2285' FSL & 571' FWL BP Exploration (Alaska) O p~ N 0~ ~ ~ ~~~ , ~~i r'`a _,+,. Li ? t~ ~~ ('~- r ~~ ~~ ~1 "'~. V r '~ L1~ ~~"t O {~'r3 ~iM U~ ~~ ~~ ~a _~ -~ n~ ~~ ~~1~ V r ''k V r~1 _~~ C'~! r '~3' V i~_~ ~E _~ L! 1 "ti-. '~i i_i ~~ try} ~~ ~ C~ O Q ~ 1 =Y ~ ~ ,. 'st' ~' 1 {\I ~- 12/28/07 ~ctumbr~~r NO. 4542 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Lisburne, Orion Well .Inh $ Inn rlacerin4inn Ih4c RI Cnlnr Ch Z-15 11968824 PROD PROFILE 12117/07 1 L1-02 11982424 PROD PROFILE 12/12/07 1 GNI-04 N/A DIGITAL SHEAR SONIC TOOL (~'~- 11108/07 1 N-27 .11962771 SCMT ~- -~ 11/28/07 1 A-12 11975740 USIT (~ - ~ ~ 12/03/07 1 03-36A 40015115 OH MWD/LWD EDIT ~ ~-= (~ (~ 04130/07 2 1 V-210 11963075 MEMORY INJECTION PROFILE 12118/07 1 r LGirJC Mlinr~vvvLCNVC RCI+CIr' I DT All? nllryV HIVU Kt I UKIVIIVt7 VIVt IiVYT tAtil•1 1 V: 8P Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: =~.~'L LY, n ,~,~~.II, -_U~ ~. Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: I~'C:3ANICAL INTEGRITY R :PORT BUD u'.'"_ : ~`~Z~O"~ nPFr2 ~ FZELD ~~ ~ ~~~ _ ., _ Ct ~1.-~_~`, ;,ALL NUMBEt2 ~ '~ _.~G ::~..~:.~. T n ~ LL DA T~ TD . et.~Q~ .?~.. alt ~~ TVD ; . BTD . ~~\~'1 ~ ~lO~3TVD ~:asi^.g ~ shoe. ~~01 MD ~SS~y TvD; inv. :~ -T4-D ~.,.,et . ~` a- Shoe . ~~~~ '~ ~~o~ Tz~ ; ':'Gr . ~'~5~-iv ~-! 1~ ~`iJ ~cb'--='° L1_ l~- P2cicer ~51~~~ TVD; Set ~t ~yy ole S~~e ~' ._._~ ana ~ ~ ~ Perks ~\'17 to ~~ .. y" = Ci=..e1?~ =C~.1, INTEGRITY - ?A.RT # I .~nnul4s ?ress Test: Z? ?5 min ~0 min. Coc~ents : ~"'Jh~ ~~ ~~ ~~sSVC~ ~-~ '~1C`~rC T'~ \33~o~~S 'x*'GH?N1C~_%, ! NTEGRIT~ -PART # 2 ~~.ye~,\S ~ 3~bh~5 Cement Volumes s Aunt. :.finer t\~S~ Csg ~-~S(~~~; DV ~Ot. C.u` ;ro to cover aer,s 1 - ~OVCc ~ ~f'~S `~ 5O~ eoretical TCC ~~c-C~~Ct ~ c c~,,.~~--rte ~ ~t~CCl~.cf`~ Cement Bond Log (Yes or No)-~; In AOGCC File~~~- CBL Evaluation, gone above perfs ~cc`~~oc'~e~~~~_ cs.~O©vct cxr~ ._~ Production 'Log. Type Evaluation _ CQ~T~LJS i0t1S ?art ; 1 : ~i``~~-~~~ ~ ~.~ ~ ~`s'c -~r~ F--~C ?art j2: ~.~ -- ~~~I ~i~~-o~ STATE OF ALASKA ~ ~~ I p~ ALASKA~L AND GAS CONSERVATION COM~StON ~°" WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~ ~ ~ ~~ l~ ~ ~ ~ '~ 2(~Q7 ~~ 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended zoAAC zs.,os zoAAC zs.,,o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One S I `' ' "" Devel~~Y~ Exploratory '"'~~ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 11/28/2007 ' 12. Permit to Drill Number 207-104, 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 8/30/2007 ~ 13. API Number 50-029-23365-00-00 4a. Location of Well (Governmental Section): Surface: 2285' FSL 4709' FEL SEC 08 T11N R13E UM 7. Date T.D. Reached 9/11/2007 ~ 14. Well Name and Number: PBU N-27i • , , . , , , Top of Productive Horizon: 253' FSL, 4765' FEL, SEC. 08, T11N, R13E, UM 8. KB (ft above MSL): 71.6' Ground (ft MSL): 43' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 188' FSL, 4741' FEL, SEC. 08, T11N, R13E, UM 9. Plug Back Depth (MD+TVD) 9417 9023 Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 634413 y- 5968189 Zone- ASP4 10. Total Depth (MD+ND) 9505 9110 16. Property Designation: ADL 028282 TPI: x- 634400 y- 5966157 Zone- ASP4 Total Depth: x- 634425 y- 5966091 Zone- ASP4 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: 18. Directional Survey ®Yes ^ No Submit electronic and rioted information er 20 AA 25.05 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): DIR / GR, DIR / GR /RES / PWD, DIR / GR /RES / NEU /DEN, SCMT 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 1.5# H-40 urface 08' rf 1 42" 2 0 sx Arctic Set A rox. 9-5/8" 47# L-80 29' 3221' 29' 3066' 12-1/4" 671 sx Dee Crete Lite 223 sx'G' 7" 26# L-80 26' 8967' 26' 8584' 8-1/2" 286 sx LiteCrete 182 sx Class 'G' 4-1l2" 1 L-80 8795' 9503' 41 1 8' 6-1/8" 115 sx Class 'G' 23. Open to production or inject ion? ®Yes ^ No 24. TUBING RECORD If Yes, list each interval open (MD+TVD of Top & Bottom; Pertoration Size and Number): SIZE DEPTH SET MD PACKER SET MD 2-7/8" Gun Diameter, 6 spf 4-1l2", 12.6#, 13Cr80 8804' 8728' MD TVD MD TVD 9172' - 9192' 8784' - 8803' 9214' - 9219' 8825' - 8830' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 2200' Freeze Protect w/ 77 Bbls of Diesel 26. PRODUCTION TEST Date First Production: December 8, 2007 Method of Operation (Flowing, Gas Lift, etc.): Gas Lift (Pre-Produced Injector) Date Of Test: 12/25/2007 HOUfS Tested: 12 PRODUCTION FOR TEST PERIOD OIL-BBL: 552 GAS-MCF: 1,323 WATER-BBL: 1,063 CHOKE SIZE: 176 GAS-OIL RATIO: 2,397 Flow Tubing Press. 250 CaSing PreSS: 1,460 CALCULATED 24-HOUR RarE • OIL-BBL: 1,104 GAS-MCF: 2,646 WATER-BBL: 2,126 OIL GRAVITV-API (CORK): 24 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Cores Ac wired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None ,~> - ~ D~. Form 10-407 Revised 02/2007 CONTINUED ON REVERSE SIDE ~~?? p /" ~~ ~}~~ ~ O 2008 (vi 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AND ERS ENCOUNTERED): 29. FORMATION TESTS NAME TVD Well Teste ^ Yes ®No Permafrost Top Surface If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base 2022' 1955' detailed test information per 20 AAC 25.071. Sag River 8964' 8581' None Shublik 8996' 8612' Sadlerochit 9047' 8662' 42N /Zone 4A 9151' 8763' Top of CGL /Zone 3 9213' 8824' Base of CGL /Zone 2 9313' 8922' 25N /Zone 26 9399' 9006' 22N /Zone 2A 9454' 9060' Formation at Total Depth (Name): 22N /Zone 2A 9454' 9060' 30. List of Attachments: Summary of Daily Drilling Reports and Post Rig Perf Operations Summary, Well Schematic Diagram, Surveys 31. I hereby certify that the fore ing is true and correct to the best of my knowledge. ~7 Signed Terrie Hubble ~ Title Drilling Technologist Date ~ ~/~/ ~Q PBU N-27i 207-104 Prepared eyName/Number. Terrie Hubble, 564-4628 Well Number Drilling Engineer: John Rose, 564-5271 Permit No. / A royal No. INSTRUCTIONS GeNeRA~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only BP EXPLORATION Page 1 of 1 Leak-Off Test Summary Legal Name: N-27 Common Name: N-27 Test Date Test Type ' Test Depth (TMD) ~ Test Depth (TVD) 9/4/2007 FIT 3,245.0 (ft) 3,100.0 (ft) 9/9/2007 FIT (ft) (ft) 9/10/2007 FIT 8,968.0 (ft) 8,585.0 (ft) AMW Surface Pressure __ ~_ 'Leak Off Pressure (BHP) --- EMW 8.80 (ppg) 385 (psi) 1,802 (psi) 11.19 (ppg) (ppg) (psi) (Psi) 11.19 (ppg) 8.40 (ppg) 982 (psi) 4,728 (psi) 10.60 (ppg) Printed: 10/3/2007 2:26:50 PM BP EXPLORATION Page 1 of 10 Operations Summary Report Legal Well Name: N-27 Common Well Name: N-27 Spud Date: 8/30/2007 Event Name: DRILL+COMPLETE Start: 8/25/2007 End: 9/24/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/13/2007 Rig Name: NABOBS 7ES Rig Number: Date From - To ~ Hours Task ,Code NPT ' Phase Description of Operations 8/25/2007 12:00 - 13:30 I 1.501 MOB P PRE Prepare to move Rig to N-27i 13:30 - 23:00 ', 9.50 ~ MOB 23:00 - 00:00 ~i 1.00 MOB 8/26/2007 00:00 - 04:00 li ~~ 4.00 i i MOB i 04:00 - 16:00 12.00 MOB 16:00 - 22:45 'I 6.75 MOB 8/27/2007 i 8/28/2007 00:00 - 20:30 j 20.50 MOB 20:30 - 00:00 3.50 MOB 8/29/2007 00:00 - 03:00 3.00 RIGU 03:00 - 06:00 3.00 RIGU 06:00 - 12:00 6.00 ~ RIGU 12:00 - 18:00 6.00 RIGU 18:00 - 00:00 6.00 RIGU 8/30/2007 00:00 - 05:00 , 5.00 ~ RIGU 22:45 - 00:00 1.25 ~ MOB 00:00 - 05:30 5.50, li MOB 05:30 - 10:00 i 4.50 MOB 10:00 - 00:00 14.00 i MOB 05:00 - 06:30 !. 1.501 RIGU -Install Jeep on Pits, Satellite camp & Shop for move. P PRE Move Shop, Pits and Satellite camp to N-Pad. -Insatall 20" Diverter on N-27i conductor with 3rd party crane. -Vac wash water f/ berms & sumps. -Install Pipe skate guard. -Mic Draw works drum bearings. -Plywood road at soft shoulders. -Waiting on Matting of road to proceed with Rig move. P PRE Lay Plywood for Rig move. P PRE Lay Plywood on road (soft shoulders) to exit DS -1 for Rig move. -Laying Matting on Lake Coleen road. -Move Rig past East check point. N MISC PRE Substructure broke through the road and stuck between East check point and Peak Base. -Lay Dunnage, Plywood under Rig & lay Mats ahead of Rig. -Connect Sows to front of Substructure & pull Rig onto Mats. N MISC PRE Move Substructure. When off Mats Sub started sinking into road. -Stop, & back up onto Mats. -Mat road & move Sub onto Exxon Pad. N MISC PRE Lay Mats from Exxon Pad returning to East check point. N MISC PRE Move Rig from Exxon Pad to East check point. -Wait on High line power to be disconnected. -CPS working on breakers to de-energize High lines at FS-1. N MISC PRE Move Rig on Mats up to East check point. N MISC PRE Wait on Matting and CPS to de-energize High line power @ FS - 1. Move sub to DS-1 wait for power line maintenance to de-energize West Dock road. P PRE Move Rig to N-27i from DS- 1 via West Dock Rd to K Pad road to Spine RD to N-Pad . P PRE Assemble BOPs, prepare location. P PRE Place mats under rig. Berm cellar w/herculite. Spot rig over N-27i. P PRE Inspect derrick. Raise derrick. Rig up cattle chute. Rig up floor. Spot pits. Rig up interconnect. P PRE Bridle down, pin top drive to blocks, finish installing service loop. RU tongs, slips and elevators. P PRE Hold N27i pre-spud meeting with day tour hands, Directional Driller, Mud Engineer, Toolpusher, Geologist and Well Site Leader. Continue to rig up subs, bails, calibrate Epoch system, test gas detectors, load pipeshed with 4" HT-40 drill pipe. P PRE Accept rig at 18:00. MU riser, flowline, diverter line, install valves on conductor pipe, take on fluids to pits, take on spud mud. PU drill pipe and stand back. Hold N27i pre-spud meeting with day tour hands, Directional Driller, Mud Engineer, Toolpusher, Well Site Leader. P ~ PRE .Function test diverter. PU 81 jts 4" HT-40 DP & 24 jts 4" HWDP f/mousehole. RIH w/muleshoe and tag up on cement in 20" conductor at 101'. Stand drill pipe back in derrick. P PRE Test diverter. Witnessed by AOGCC representative Lou ~ Grimaldi, WSL Lowell Anderson, NAD Tourpusher Lenward Printed: 10/3/2007 2:26:56 PM • • BP EXPLORATION Page 2 of 10 Qperations Summary Report Legal Well Name: N-27 Common W ell Name: N-27 Spud Date: 8/30/2007 Event Nam e: DRILL+C OMPLE TE Start : 8/25/2007 End: 9/24/2007 Contractor Name: NABOB S ALASK A DRI LLING I Rig Release: 9/13/2007 Rig Name: NABOB S 7ES Rig Number: Date ~ From - To Hours I Task Code' NPT Phase Description of Operations ~ 8/30/2007 05:00 - 06:30 1.50 i RIGU P PRE Toussant. 06:30 - 13:00 t 6.50 RIGU N WAIT PRE Function test diverter. Bent diverter line would not allow proper function of diverter "knife valve". Mobilize another section of j ~ ! diverter pipe f/NAD Deadhorse yard. ' 13:00 - 15:00 ! 2.001 RIGU ~ N SFAL PRE C/O diverter line section and repair diverter knife valve. 15:00 - 16:00 ~ 1.00; RIGU N SFAL PRE Function test diverter and knife valve. AOGCC Lou Gremaldi, '~ BP WSLs Joey LeBlanc and Duncan Ferguson, NAD TP Larry Wurdemen witnessed test. 16:00 - 16:30 0.501 RIGU P PRE PU 4" HWDP and jars. 16:30 - 17:00 0.50 RIGU P PRE RU Gyrodata/Sperry wireline sheave and line. 17:00 - 21:45 4.75 RIGU P ~ PRE PU and orient UBHO/motor/MW D for drilling BHA #1. UBHO j sub for gyro surveys. 21:45 - 23:00 1.25 DRILL P SURF Drill out 20" conductor cement f/101' to 104' w/viscosified H2O circulated f/pill pit. Overboard 11.2 pH H2O. Spud well at i 21:54. Continue drilling 12.25" surface hole f/104" to 26T, 350 to 500 gpm 650 psi 45 rpm. 23:00 - 23:30 0.50, DRILL j P SURF Run Gyrodata/Sperry wireline survey at 26T. L 23:30 - 00:00 0.50~i DRILL ; P SURF Drill 12.25" surface hole directionally in Gubik gravel beds f/ ! I 26T to 353'. 500 gpm, 750 psi, 1 K tq. See 153 bbls of gravel I returned f/53 expected bbls hole volume. Lost 40 bbls fluid t/section f/day. 8/31/2007 00:00 - 00:30 ! 0.50 ', DRILL N STUC SURF POH to PU drill collars, stabilizer and reposition jars. Pipe ~ ~ stuck at 270'. Connect topdrive. Attempted to circulate, and 00:30 - 01:00 0.50 ~ DRILL N STUC SURF work pipe down, and apply torque to attempt to free pipe. Work pipe downhole and regain circulation and free pipe. Circulate large amounts of gravel out of hole. 250 gpm, 260 psi. Circulate until hole clean. 01:00 - 23:00 22.00 DRILL P SURF Conttinue POH and pick up drill collars, stabilizer and reposition jars to complete BHA. 02:30 - 02:45 0.25 DRILL P SURF RIH to 353' with drilling BHA #1. 02:45 - 06:00 3.25 DRILL P SURF Slide/rotate drill directionally f/353' to 725'. PU 60K, SO 60K, ROT 58K, 540 gpm, 1120 psi, 40 rpm, tq on 1 K, tq off 1 K. ', 06:00 - 22:00 16.00 DRILL P SURF Slide/rotate drill directionally f/725' to 2148'. 600 gpm, 2350 psi, 60 rpm, tq. 5K, WOB 25K. PUK 83K, SO 70K, ROT 75K. Base of Permafrost at 2022' on logs and noted increase of drilling rate. 22:00 - 22:30 0.50 DRILL ~ P SURF Circulate and condition mud. 60 rpm, 2290 psi. 22:30 - 00:00 1.50 DRILL P SURF Wiper trip. POH f/2148' to 1585'. Pulled tight (/1585' to 1450'. PU 80K, pull over 20K to 30K. 19/1/2007 100:00 - 02:30 ! 2.50 02:30 - 03:30 1.00 03:30 - 04:00 0.50 04:30 - 08:00 3.50 08:00 - 21:45 13.75 21:45 - 22:30 DRILL I N I STUC I SURF DRILL P SURF DRILL P SURF DRILL P SURF DRILL I P I I SURF 0.75; DRILL ' P SURF ADT f/24 hrs = 7.3 hrs, AST = 4.85 hrs, ART = 2.45 hrs. Stuck pipe at 1473'. Work pipe free with downward motion and rotation and full circulation. Backream with slow progress to 1370'. High torque. 176 gpm, 60 rpm, 400 psi. POH f/1370' to BHA #1 at 219'. Stand back BHA #1. Bit check. OK. RIH w/BHA #1. Tag up on obstruction at 1870'. Ream down at reduced rate and rpms to 2148'. Slide/drill f/2148' to 3229'. 604 gpm, 2865 psi on, 2663 psi off, 80 rpm, 5K tq on, 4K tq off, PU 110K, SO 85K, ROT 95K. ADT f/24 hrs = 8.68, ART = 2.62, AST = 6.06 Circulate, reciprocate, 3229' to 3219'. 604 gpm, 2663 psi, pump Printed: 10/3/2007 2:26:56 PM r ~ BP EXPLORATION Page 3 of 10 Operations Summary Report Legal Well Name: N-27 Common Well Name: N-27 Spud Date: 8/30/2007 Event Name: DRILL+COMPLETE Start: 8/25/2007 End: 9/24/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 9/13/2007 Rig Name: NABORS 7ES Rig Number: Date ,From - To ~~ Hours Task Code NPT Phase Description of Operations 9/1/2007 21:45 - 22:30 0.75 DRILL P 22:30 - 23:00 0.50 DRILL P 23:00 - 00:00 1.00 DRILL P 9/2/2007 00:00 - 01:30 1.50 DRILL ~ P 01:30 - 02:30 1.00 DRILL P 02:30 - 03:00 i 0.50 DRILL P 03:00 - 04:00 1.00 DRILL P 04:00 - 04:30 0.50 DRILL P 04:30 - 06:00 1.50 DRILL P 06:00 - 07:00 1.00 DRILL P 07:00 - 07:30 0.50 DRILL P 07:30 - 09:00 1.50 DRILL P SURF SURF SURF SURF SURF SURF 614 bbls until clean. POH on short trip to 2171'. Cont. to POH on short trip to 2450'. Pull 35K over at 2450', 2180'. Backream 2180' to 2171'. 490 psi, 247 gpm, 7K tq. POH on short trip f/2171' to 279' w/no overpulls. RIH on short trip. Hit obstruction at 2150'. Ream down pushing obstruction w/reduced pump rate and rotation to 2244, 120 gpm, 30 rpm. Back ream 2244' to 2148' 575 gpm, 1940 psi, 30 rpm. RIH (/2148' to 3229'. CBU x 2 @ 650 gpm, 60 rpm, reciprocate 15' until clean. POH to 2827'. Tight spot. POH backreaming/pumping out through tight spots as required f/2827'. Back ream 2178' to 2148'. Upward movement restricted. Pump out of hole f/2148' at base of permafrost to 1863'. POH f/1863' to 184' w/no further restrictions. RIH to 2800' and hit obstruction. Ream f/2800 tp 3009'. 350 gpm, 2000 psi. 40 rpm, 5K tq and RIH to 3229' w/pumps encountering no obstruction. CBU 650 gpm, 3125 psi, 100 rpm, 5K tq. POH. Backreaming f/3229' to 2100' at base of permafrost. 500 gpm 2330 psi, 60 rpm, 5K tq. POH. Pump out of hole at 400 gpm f/2100' to 1863'. POH to BHA and LD BHA #1. RU to run 9-5/8" L-80 BTC-M casing. Make dummy run w/casing hanger. 27.80' and mark split jt at RKB level. PU Franks fill up tool. Run 78 jts 9 5/8" L-80 BTC-M casing to 3188'. Run last jt, bump rocks, and pump at 42 gpm. Work casing and wash to bottom. Land 9-5/8" casing with shoe at 3222'. Establish circulation at 137 gpm, 557 psi with Franks fill up tool. RU cementing head. Plugs installed verified by WSL. Circulate 9.5 ppg old spud mud staging pumps up from 1 bpm to 7.5 bpm at 548 psi. Full returns throughout. CBU x 2 and bring vis down to <70 for cement job. Unable to reciprocate casing. PJSM w/Schlumberger, crew, all hands, mud engineer, WSL. Cement 9 5/8" casing as follows: Pump 5 bbls H2O ahead to floor w/Schlumberger and test lines to 4000. Mix and pump 100 bbl Mudpush to floor and overboard all H2O via tee, drop bottom plug, mix and pump 459 bbls 10.7 ppg DeepCRETE lead w/red dye in first 10 bbls, saw bottom plug bump and blow through at 825 psi. Mix and pump 48 bbls 15.8 ppg G tail, drop top plug, follow w/10 bbls H2O from Schlumberger, switch to rig and pump 220 bbls old spud mud and bump plugs. Displacement average rate 7.5 bpm, drop to 3 bpm last 10 bbls, FCP = 735 psi. CIP 02:54. Mudpush and 82 bbls good green cement w/some red dye back to surface. Bring pressure to 3500 psi and hold for 30 mins. w/chart. Full returns throughout job. Bleed off and check floats for flowback. None. Clean cement out of diverter. LD cement head. LD landing joint. ND diverter system. Remove diverter flow line. I SURF ,SURF SURF SURF iSURF ;SURF 09:00 - 10:00 1.00 DRILL P I SURF 10:00 - 12:30 2.50 DRILL P ~, SURF 12:30 - 15:00 2.50 CASE P I SURF 15:00 - 21:15 6.25 CASE P I I SURF 21:15 - 22:00 0.75 CASE P I SURF 22:00 - 00:00 ~ 2.00 CASE P I SURF 9/3/2007 00:00 - 03:00. 3.00 CEMT P ~ SURF I i i 03:00 - 03:30 I 0.501 CEMT I P I 'SURF 03:30 - 05:00 1 1.501 DIVRTR I P I I SURF 05:00 - 07:00 2.001 DIVRTR P .SURF Printed: 10/3/2007 2:26:56 PM i i~ BP EXPLORATION Page 4 of 10 Operations Summary Report Legal Well Name: N-27 Common Well Name: N-27 Spud Date: 8!30/2007 Event Name: DRILL+COMPLETE Start: 8/25/2007 End: 9/24/2007 Contractor Name: NABOBS ALASKA DRI LLING I Rig Release: 9/13/2007 Rig Name: NABOBS 7ES Rig Number: Date From - To Hours Task Code NPT Phase ~ Description of Operations 9/3/2007 ~ 07:00 - 09:30 2.50 WHSUR P SURF ' NU FMC Unihead casing head and tubing spool and test to 1000 psi f/10 mins. 09:30 - 15:00 5.50 BOPSU P SURF ! NU DSA and BOP stack, MU Koomey lines, torque up all !flange bolts. 15:00 - 16:00 1.00 BOPSU P SURF ', RU f/BOP test. 16:00 - 19:00 3.00 BOPSU N RREP SURF ;Trouble shoot and repair BOP, replace hydraulic fitting on BOP ~ !stack. Change Koomey hoses. 19:00 - 19:30 0.50 BOPSU P ' SURF 'Continue RU to test BOP. i 19:30 - 00:00 I 4.50 BOPSU P SURF I BOP test. 4000 psi high pressure test, 250 low pressure test 'Iw/chart. Witnessed by BP WSL Lowell Anderson and Lenward I Toussant NAD tourpusher. AOGCC presence at test waived ~ by Jeff Jones w/AOGCC. 9/4/2007 00:00 - 01:00 1.00 BOPSU P SURF RO, BD. Install wear bushing. 01:00 - 03:30 2.50 DRILL P INTi PU 99 jts of 4" HT-40 drill pipe and RIH. 03:30 - 04:30 1.00 DRILL P ~ INT1 ! POH and stand back 25 stands of 4" drill pipe. j 04:30 - 06:30 ~ 2.00 DRILL N RREP INT1 ;Replace solenoid for top drive link tilt. 1 06:30 - 07:00 i, 0.50 DRILL P ~ ~ INT1 Cont. POH and stand back total 33 stands of 4" drill pipe. 07:00 - 08:00 1.00 DRILL P , INT1 ', PU 39 jts. 4" drill pipe. 08:00 - 08:30 0.50 DRILL P INT1 POH and stand back 13 stands of 4" drill pipe. 08:30 - 10:30 2.00 DRILL P INT1 !, PU BHA # 2 w/Hughes HCM506Z S/N 7005767/1.15 deg XP motor and RIH. 10:30 - 12:00 1.50 DRILL P INT1 ~, Shallow test MW D and PU 43 jts. 4" drill pipe. 12:00 - 13:15 1.25 DRILL P INT1 'RIH w/stands f/2265' to 3044'. ~ 13:15 - 14:15 1.00 DRILL P INT1 ,Fill pipe, circulate 61 gpm, 240 psi, 36 bbl pumped. Tag ',cement stringer at 3116'. Test casing to 3500 psi f/5 mins. 14:15 - 15:15 1.00 DRILL P INT1 Cut and slip drilling line. 15:15 - 15:45 0.50 DRILL P INT1 ,Service topdrive and crown. 15:45 - 16:30 0.751 DRILL P INT1 I Wash down and tag plugs at 3134' and drill float collar/cement 'to 3214'. (See large chunks black then red plug rubber at ~! surface.) 16:30 - 18:00 1.50 DRILL P INT1 li Displace well to 8.8 ppg LSND mud. 443 gpm, 859 psi, 40 I rpm, 4K tq. Reciprocate. 18:00 - 18:30 0.50 DRILL P INT1 i Drill cement f/3214', tag and drill shoe to 3220'. Drill 8.5" hole ~ Ito 3245'. 445 gpm, 918 psi, 4K tq, 40 rpm, 5K WOB, 110K PU, ' ' 80K SO, 90K ROT. 18:30 - 20:00 1.50 DRILL P INT1 !Pull back into shoe. CBU. Perform FIT to 11.2 ppq EMW, 385 ;psi, 8.8 ppg mud, 3067 TVD. Establish baseline f/ECD. 20:00 - 20:15 0.25 DRILL P INT1 Drill f/3245' to 3345'. 545 gpm, 1545 psi. Corrupted lower GR I readout f/MW D. 20:15 - 21:15 1.00 DRILL N HMAN INT1 !~ POH to 3221' and reprogram MWD surface computer. RIH to i ' 3345'. 21:15 - 00:00 2.75 DRILL P INTi ~ Drill directionally f/3345' to 3810'. 10K WOB, 543 gpm, 1554 ' psi on, 1458 psi off, 5K tq on, 5K tq off, 115 PU, 85K SO, 96K I ROT. 9.37 ppg calculated ECD, 9.92 ppg actual ECD. ~ I I ADT = 1.95 hrs. f/24 hrs, AST = .18 hrs, ART = 1.77 hrs. I Progress = 581'. i 'I 9/5/2007 00:00 - 06:00 6.00 DRILL P INT1 ~ Drill directionally f/3810' to 4850'. 15K WOB, 545 gpm, 2210 ~~, psi on, 2020 psi off, 100 rpm, 7K tq on, 6K tq off, 145 PU, 80K i '~ SO, 97K ROT. 9.56 ppg calculated ECD, 10.25 ppg actual ECD. 06:00 - 00:00 18.00 ~ DRILL P INTi ;Drill directionally (/4850' to 7090'. 18K WOB, 504 gpm, 2812 Printed: 10/3/2007 2:26:56 PM BP EXPLORATION Page 5 of 10 Operations Summary Report Legal Well Name: N-27 Common Well Name: N-27 Spud Date: 8/30/2007 Event Name: DRILL+COMPLETE Start: 8/25/2007 End: 9/24/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/13/2007 Rig Name: NABOBS 7ES Rig Number: Date 'From - To II Hours .Task Code NPT Phase Description of Operations 9/5/2007 ', 06:00 - 00:00 18.001 DRILL ~ P ~ ~ INT1 I psi on, 2589 psi off, 100 rpm, 8K tq on, 7K tq off, 180 PU, 123K I' 9/6/2007 ~ 00:00 - 06:00 i 6.001 DRILL ~ P ~ INT1 06:00 - 21:15 I 15.251 DRILL I P I I INT1 21:15 - 23:00 i, 1.751 DRILL P INT1 23:00 - 00:00 I 1.00 1 DRILL P INT1 9/7/2007 00:00 - 00:30 0.50 DRILL P INT1 00:30 - 01:00 , 0.50 i 1 DRILL P INT1 01:00 - 03:00 i 2.00 DRILL P INT1 03:00 - 03:30 ! 0.50 DRILL P INT1 03:30 - 05:30 ~ 2.00 DRILL P INT1 05:30 - 06:30. 1.00 DRILL P INT1 06:30 - 07:00 0.50 DRILL P INT1 07:00 - 09:00 2.00 DRILL P INTi 09:00 - 13:00 j 4.001 DRILL ~ P INT1 13:00 - 14:30 ~ 1.50 ~ DRILL P ~ (INT1 14:30 - 16:30 I 2.00. DRILL P i INTi I 16:30 - 20:30 i 4.00'1 DRILL N RREP INT1 SO, 145K ROT. 10.74 ppg calculated ECD, 10.79 ppg actual I ECD. ' Pump 40 bbl (250 vis) HiVis sweep at 4890' w/slight increase in cuttings. Increase mud wt. to 10.1 ppg w/spike fluid at 6800' pror to HRZ penetration at 7100'. ADT f/24 hrs = 16.57, AST = 4.67, ART = 11.9 Drill directionally f/7090' to 7650'. 20K WOB, 503 gpm, 2990 psi on, 2735 psi off, 100 rpm, 8K tq on, 7K tq off, 180 PU, 125K SO, 145K ROT. 10.74 ppg calculated ECD, 11.05 ppg actual ECD. Drill directionally f/7650 to 8968'. 12-20K WOB, 484 gpm, 3146 psi on, 2902 psi off, 100 rpm, 10K tq on, 8K tq off, 200K PU, I 125K SO, 145K ROT. 10.74 ppg calculated ECD, 10.78 ppg actual ECD. I ADT f/24 hrs = 15.2, AST = 3.1, ART = 12.1 Progress = 1878' CBU x 2 at 502 gpm 3010 psi, 100 rpm, 8K tq. Set stand back after 1 hr. Calc ECD = 10.74, Act ECD = 10.65. Mud clean across shakers. Monitor well. POH on short trip to 8016'. POH f/8016' to 7515'. Tight spot. Pull over gradually increasing to 18K over string wt. Pump out of hole f/7515' to 7230' (top of Kingak up through HRZ). Pull over decreased to string weight. POH f/7230' to 9-5.8" shoe at 3222'. CBU. 548 gpm, 1966 psi. RIH f/3220' to 7950' Took 25K down wt. PU and attempt to break circulation. Packed off. Work pipe and pumps to regain circulation. Stage pumps up to 450 gpm, 2500 psi, 80 rpm, 10K tq. Ream down f/7950' to 8016' at reduced rate and rpm. Back ream f/8016' to 7920'. CBU, 450 gpm, 2500 psi, 80 rpm, 10K tq. RIH (/8016' to 8780. Wash down (/8780' to TD at 8968'. No fill on bottom. Circulate surface to surface w/45 bbl HI-Vis sweep, 500 gpm, 3060 psi. ' 100 rpm, 12K tq. 50% increase in cuttings. Weight up mud f/10.1 ppg to 10.4 ppg. 480 gpm, 2760 psi, 100 rpm, 12K tq, reciprocate 30'. Circulate 3427 bbls around. See large quantities of well defined splintered shale 1" to 2" in length. Reduce pump rate f/500 gpm to 440 gpm, 2520 psi, rotate 60 rpm, 9K tq. Circulate 830 bbls around w/continuous heavy returns of splintered shale across shakers. SD and monitor well. Static. Pump out of hole f/8968' to 7729'. 106 gpm, 310 psi, PU 210K, SO 135K. Topdrive went down w/electrical problem. Trace to "J" box wire separated at connection point. Repair. Printed: 10/3/2007 2:26:56 PM ~ ~ BP EXPLORATION Page 6 of 10 .Operations Summary Report Legal Well Name: N-27 Common W ell Name: N-27 Spud Date: 8/30/2007 Event Nam e: DRILL+COMPLE TE Start : 8/25/2007 End: 9/24/2007 Contractor Name: NABOBS ALASK A DRI LLING I Rig Release: 9/13/2007 Rig Name: NABOBS 7ES Rig Number: Date ~ From - To Hours ~ Task ~~ Code', NPT ~~ Phase Description of Operations ~ ! --- - ' ' 9/7/2007 20:30 - 21:00 DRILL 0.50 P INT1 to 7060 (above top of HRZ), 100 Pump out of hole (/7729 ~ gpm, 300 psi. No overpulls. 21:00 - 23:30 2.50 ~, DRILL P INT1 RIH f/ 7060' to 8968' Wash last stand down w/slow pumps and !, slow rotation. 95 gpm, 300 psi, 15 rpm. No obstructions, no fill ~i on bottom. 23:30 - 00:00 0.50 ~ DRILL P INT1 CBU staging pumps up to 420 gpm, rotate 60 rpm and j reciprocate 30' strokes. 200 gpm, 745 psi, 10K tq. 270 gpm at 1150 psi, 10K tq. 420 gpm, 2230 psi, 10K tq. 9/8/2007 00:00 - 01:00 1.OOI DRILL P INT1 Cont. w/CBU. At bottoms up large amounts of 1" to 2" I splintered shale across shakers. Consult w/town team and decision made to raise MW f/10.4 ppq to 10.7 ppp. 01:00 - 03:30 2.50 DRILL P INTi Circulate, condition mud, build mud wt f/10.4 to 10.7 ppg. After 10.7 mud around shale diminishing across shakers. 03:30 - 06:30 3.00 DRILL P INTi Pump out of hole f/8968' above top of HRZ to 6391'. 06:30 - 08:00 1.50 ~, DRILL P INT1 Pull over and swabbing. Back ream 6391' to 5818'. 420 gpm, 1960 psi, 80 rpm, 7K tq. Pumped BU while backreaming. 08:00 - 10:30 2.50! DRILL P INT1 POH to 241'. 10:30 - 12:00 1.501 DRILL ~ P INT1 LD BHA and clear floor. Pull wear bushing. 12:00 - 14:30 2.50; CASE P INT1 Change and test top rams. Function test rams. 250 low ' ' pressure, 4000 high pressure. BD/RD test equipment. 14:30 - 15:30 1.00; CASE P INT1 PJSM before task. Rig up casing running equipment. ~ 15:30 - 20:30 5.00 ~ CASE ~ P INT1 PJSM w/casing hand and crew. MU and RIH w/7" 26# L-80 mixed BTC-M/TCII casing string. MU shoe track, test floats. MU tq. avg = 7200 ft/Ibs, RIH to 3200'. above 9-5/8" shoe. PU 1 97K, SO 88K. 20:30 - 21:00 0.50 CASE P INTi Circulate 185 bbls, stage pumps up to 5 bpm: 1 bpm = 270 psi, i 2 bpm = 370 psi, 3 bpm = 305 psi, 4 bpm = 333 psi, 5 bpm = ~ ~ 390 si. YP at 14 be innin of tri rn hole. MW = 10.7 p 9~ 9 P PPg• PU = 105K, SO = 90 K. 21:00 - 00:00 3.00 ~ CASE P INT1 RIH in OH f/3222' to 4253', RU XO jt to TCII and tq. turn equipment. TCII tq at 10100 ft/Ibs. RIH to 4720' and break II circulation. Circulate while RIH every 8th, 9th, and 10th jt. Stage pumps U3.5 bpm and stop increase in rate when losses noted. Pump 40 bbls f/3 jts. 9/9/2007 00:00 - 04:30 4.501 CASE P INT1 RIH 40 ft./min w/7" L-80 26# casing f/4253' to 6902'. Stage pumps up to 3 bbls/min every 10 jts and pump 3 jts down. Record up and down wts: 5233' 170K PU, 120K SO. 5672' 182K PU, 128K SO. 6069' 190K PU, 130K SO. 6466' 205K PU, 138K SO. 6941' 210K PU, 130K SO. 04:30 - 05:00 ~ 0.50 CASE P INTi 6902' to 6981' CBU 160 bbls, 5 bpm/670 psi w/small amount of sand and no shale around at bottoms up. 6970' PU 230 SO 180K. 05:00 - 07:30 2.50 CASE P INTi RIH f/6981' to 8924'. 40 ft./min. 07:30 - 09:30 2.00 ~ CASE P INT1 Wash down last stand f/8924' to 8968'. Stage pumps up to 5 bpm, 835 psi. PU 295K, SO 160K. CBU x2 w/no losses. 09:30 - 10:30 1.00 CEMT P INT1 RD Franks tool. RU cementing head and lines. Cement head loaded and checked by WSL. 10:30 - 12:30 2.00, CEMT P INT1 Break circulation and lose circulation. Circulate 2.5 bpm, 320 ! ~ psi w/10% returns. 225 bbl losses f/10:30 to 12:30. 2 bpm, 370 psi. PJSM f/cement job w/all hands, Schlumberger, and ~ WSL. Mobilize CemNet flcement. ', ~ 12:30 - 16:00 3.50!; CEMT P j INT1 Use Schlumberger to pump 5 bbls H2O to rig floor. Test lines Printed: 10/3/2007 2:26:56 PM BP EXPLORATION Page 7 of 10 Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Date From - To 9/9/2007 (12:30 - 16:00 N-27 N-27 DRILL+COMPLETE NABOBS ALASKA DRILLING I NABOBS 7ES ~~ Hours ~ Tank ~ Code NPT Start: Rig Release Rig Number: Phase 3.50 i CEMT I P I I INT1 16:00 - 21:00 5.001 CASE i I ~ P I I 1 INT1 21:00 - 21:30 0.50 CASE P I i INTi 21:30 - 23:00 1.50 WHSUR P i INT1 23:00 - 00:00 1.00 WHSUR P INT1 9/10/2007 00:00 - 01:30 01:30 - 02:30 02:30 - 04:30 1.50 WHSUR P INT1 1.00 BOPSU P INT1 2.00 BOPSU P INT1 04:30 - 06:30 ~ 2.00! DRILL ~ P ~ ~ PROD1 06:30 - 09:30 3.00 DRILL P I PROD1 09:30 - 10:30 1.00 DRILL P PROD1 10:30 - 13:00 2.50 DRILL P PROD1 13:00 - 13:30 ~ 0.50 DRILL I P PROD1 13:30 - 14:30 1.00 DRILL P I PROD1 Spud Date: 8/30/2007 8/25/2007 End: 9/24/2007 9/13/2007 Description of Operations to 4500 psi. Mix and pump 70 bbls of 11.00 ppg Mudpush w/2 ppb CemNet. Bring Mudpush to rig floor via bleed off Tee to avoid pumping water downhole. Drop bottom plug. Continue pumping Mudpush spacer. Poor returns increasing as spacer is pumped. Batch mix and pump 132 bbls of 12 ppg Lite Crete lead slurry w/2 ppb CemNet plus additives, 5 bbls/min. Batch mix and pump 38 bbls of 15.8 ppg "G" tail slurry w/2 ppb CemNet + additives, 5 bbls/min. Still experiencing some lost circulation but returns improving throughout job. Drop top plug. Follow plug w/5bbls H2O displacement to clear cement f/lines. Switch to mud displacement w/rig pumps. Circulation improved to 90% full returns. Displace 335 bbls 10.7 ppg old mud w/rig pumps. Pump 300 bbls at 5 bpm. Slow pumps to 3 bbls/min, then 2 bbls/min f/35 bbls and bump plug. FCP = 934 psi. Bring pressure w/rig pumps to 1400 psi over cementing FCP. Bleed pressure to 0 and check floats for backflow. None. Use Schlumberger pumps to increase pressure to 4000 psi and hold for 30 min casing testa Close annular preventer. Pump 10 bbls 10.7 ppg drlg mud down 7" x 9-5/8" annulus. Initial breakdown pressure 460 psi. Inject at 515 psi, 1 bpm. Continue injecting 1 bbl every 30 min. Increase rate to 2 bpm. Break down at 630 psi. Total bbls. injected = 25. Monitor well for 30 minutes prior to splitting stack. Per Schlumberger UCA, lead cement compressive strength at 50 psi at 21:00. PJSM w/FMC. Flush stack, remove fluid f/top jt to be cut. ND BOP and split stack. Install 9-5/8" x 7" casing slips and packoff. SO 100K set in slips. RU Wachs casing cutter and cut 7" casing off. LD cut jt. Cont. install 9-5/8" x 7" packoff and pressure test to 4300 psi f/10 mins. Torque lock downs to 450 ft/Ibs. NU BOP. Install 3.5" x 6" variable rams. Pump 5 bbls 10.7 ppg mud down 7" x 9-5/8" annulus at 490 psi. to ensure infectivity. Test upper rams and ram doors to 4000 psi high, 250 psi low w/4" test jt. Test annular to lower rams w/4.5" test jt. 4000 psi high, 250 psi low. PU 6.125"/1.15 deg motor BHA #3 w/Hughes MX-18HDX S/N5129122. PJSM on handling of nukes w/Schlumberger. Load source and continue PU BHA # 3. Off the critical path inject 67 bbls 10.7 ppg mud followed by 24 bbls 12.4 ppg mud w/rig pumps down 7" x 9-5/8" annulus 2 bbls min 460 psi. RU Hot Oil Services to same annulus and pump 59 bbls diesel for freeze protection. RIH to 876' and shallow test MWD. Continue to RIH to 7000'. Cut and slip 110' of drilling line and service top drive. Stripping drill. BD lines. RIH fl7000' to 8807'. Wash to bottom f/8807' to 8885'. 100 gpm, 800 psi. Tag plugs/float collar at 8885'. Drill plugs, float collar, cement to Printed: 10/3/2007 2:26:56 PM ~ ~ BP EXPLORATION Page 8 of 10 Operations. Summary Report Legal Well Name: N -27 Common W ell Name: N-27 Spud Date: 8/30/2007 Event Nam e: DRILL+C OMPLE TE Start: 8/25/2007 End: 9/24/2007 Contractor Name: NABOBS ALASK A DRI LLING I Rig Release: 9/13/2007 Rig Name: NABOB S 7ES Rig Number: Date I From - To ' Hours Task '', Code NPT ~ Phase Description of Operations 9/10/2007 _ 13:30 - 14:30 - _ _ 1.00 DRILL P __ PROD1 8963'. 250 gpm, 2080 psi, 60 rpm, 11 K tq, PU 210K, SO ~ 115K, ROT 150K. 14:30 - 16:30 2.00 DRILL P i PROD1 ;Circulate 250 bbls, displace well f/ 10.7 ppg LSND to 8.4 ppg i FloPro SF mud. 280 gpm, 2320 psi, circulated 80 bbls H2O, 40 bbl spacer, 294 bbls FloPro SF. 16:30 - 17:00 0.50 DRILL P PROD1 ;Drill cement in shoe track to shoe at 8968' and new hole to i 18988'. 275 gpm, 1670 psi, 60 rpm, 9K tq, WOB 15K. 17:00 - 17:30 0.50 DRILL P i PROD1 ~, CBU 204 bbls. Monitor well. Static. 17:30 - 18:00 0.50 DRILL P PROD1 FIT test to 982 psi/10.6 EMW w/8.4 ppg mud at 8554' TVD. 18:00 - 00:00 6.00 DRILL P ~ PROD1 Drill directionally f/8988' to 9477. 280 gpm, 1870 psi on, 1610 ~ i psi off, 80 rpm, 6K tq. on, 5K tq off, WOB 20K, PU 195K, SO 155K, ROT 165K. ~ ADT = 4.76 hrs. ART = 4.76 hrs. Progress = 509'. 9/11/2007 00:00 - 01:30 1.50 DRILL P PROD1 ',Drill directionally f/947T to 9505' MD, TD well per geo. ~ 269 gpm @ 1863 psi on -1630 psi off i 80 rpm @ 6K tq on - 5K tq off 23K WOB, PU 198K, SO 155K, ROT 168K 01:30 - 04:00 2.50 DRILL P ~ PROD1 '; MADPass f/9505' to 9055 at 300'/hr, 280 gpm, 1604 psi, 4K tq. per geo. ~ MADPass 9055' to 8965' at 700'/hr. 04:00 - 05:00 1.00 DRILL P PRODi ~ Drop ball and open CCV valve. CBU x 1.5 at 500 gpm @ 1645 '~ psi, reciprocate pipe. Shakers clean, MW in 8.5 ppg, MW out 8.5 ppg it Monitor well, well static Pump dry job l ' 05:00 - 07:30 2.50 DRILL P i POH w/drilling BHA #3 to 876 PROD1 07:30 - 08:00 0.50 DRILL P PROD1 IUD 21 jts HWDP 08:00 - 09:30 1.50 DRILL P PROD1 I Drop 1.76" Ball. Close CCV with 2020 psi. ~ PJSM before unloading Nuke Source. I L/D BHA 09:30 - 10:00 0.50 CASE P . PROD1 ~ R/U to run 4.5" 12.6# L-80 IBT-M liner. PJSM w/WSL, Tool Pusher, crew. 10:00 - 12:00 2.00 CASE P PROD1 P/U 16 jts 4.5" 12.6# L-80 IBT-M liner M/U liner hanger. 12:00 - 17:00 5.00 CASE P PROD1 ' M/U one stand DP to liner hanger. Circ one liner volume, 4 bpm at 110 psi. I li P/U WT- 35K, SOW - 35K Continue RIH to 8936'. Filled pipe every 10 stands 17:00 - 17:30 0.50 CASE P PROD1 Circulate 140 bbls Stage pumps up to 6 bpm ', ~ 2 bpm=385 psi 3 bpm=470 psi I ~ 4 bpm=550 psi 6 bpm=848 psi P/U WT - 170K SOW - 140K 17:30 - 18:00 0.50 CASE P PROD1 ~ Continue RIH, wash last stand to bottom at 1.5 bpm, 450 psi ~ Tag bottom at 9,505' 18:00 - 19:30 1.50 CASE P i ~ PROD1 I M/U cement head, stage pumps to 6 bpm, Circ 375 bbls 1 bpm=394 psi i j 2 bpm=487 psi Printed: 10/3/2007 2:26:56 PM ~ ~ BP EXPLORATION Page 9 of 10 Operations Summary Report Legal Well Name: N-27 Common Well Name: N-27 Spud Date: 8/30/2007 Event Name: DRILL+COMPLETE Start: 8/25/2007 End: 9/24/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/13/2007 Rig Name: NABOBS 7ES Rig Number: i Date From - To ' Hours j Task ,Code', NPT ', Phase ~ Description of Operations 9/11/2007 ; 18:00 - 19:30 1.50 CASE P PROD1 3 bpm=620 psi 4 bpm=700 psi 5 bpm=874 psi 6 bpm=1050 psi 19:30 - 21:00 1.50 CEMT P PROD1 PJSM with SLB, WSL, ToolPusher, crew Pump 5 bbls water, Pressure Test lines to 4500 psi Pump 22 bbls of 12.0 ppg mud push, 5 bpm @ 720 psi ' Pump 24 bbls Class G 15.8 ppg cement, 5 bpm @ 350 psi Kick out plug with 12 bbl pert pill, positive indication plug left head Displace @ 6 bpm, reciprocate pipe, park at 1,350 'strokes ~ 1,501 strokes to pick up liner wiper plug, 2300 psi spike, indication hanger set 1,648 strokes to bump the plug, bumped plug with 1,300 psi Continued pressuring up to 3,500 psi Slacked off 50K to verify hanger set Bleed off pressure to 0 psi, check floats ~ Rotate 15 turns to right to release from C2 running tool ~, Pressure up to 1,000 psi, P/U until pressure bleeds off, circulate 30 bbls, 10 bpm@2,300 psi Set packer with 35K Ibs (positive indication packer set and dog sub sheared), P/U and repeat with rotation 21:00 - 21:30 0.50 CASE P PROD1 CBU 200 bbls, 434 gpm, 1,786 psi 14-16 bbls 12.2 ppg cement back to surface ~ 21:30 - 23:00 1.50 CASE P PROD1 Displace well from Flo-Pro to 8.5 ppg seawater 440 gpm, 1,595 psi, 481 bbls ~ L/D cement head and blow down lines 23:00 - 00:00 1.00 CASE P PROD1 ( Monitor well -Well static i I POH from 8,795' UD DP to 7,644' 9/12/2007 00:00 - 04:30 4.50 CASE P PROD1 POH from 8,795' to surface, LD DP 04:30 - 05:00 0.50 CASE P PROD1 Make service breaks to Baker running tool LD running tool i 05:00 - 06:00 1.00 EVAL P OTHCMP Pressure Test casing and liner to 4000 psi Chart and record for 30 minutes ~ 06:00 - 07:00 1.00 EVAL P OTHCMP Spot wireline unit RU wireline equipment for Slim Cement Mapping Tool (SCMT) 07:00 - 07:30 0.50 EVAL N DFAL OTHCMP P/U logging tools Test of tools failed 07:30 - 08:30 1.00 EVAL P OTHCMP Check SCMT tools, tested fine 08:30 - 10:00 1.50 EVAL P OTHCMP RIH with SCMT to 9,416' 10:00 - 16:00 6.00 EVAL P OTHCMP Run cement logs from 9,416' to surface 16:00 - 16:30 0.50 EVAL P OTHCMP RD wireline tools (16:30 - 17:00 0.50 BUNCO RUNCMP Pull wear ring Dummy Run with tubing hanger 17:00 - 17:30 0.50 BUNCO P RUNCMP PJSM with Slb, Baker, WSL, Tool Pusher, and crew on running i completion string RU torque turn equipment and compensator 17:30 - 00:00 6.50 BUNCO P RUNCMP RIH with 4 1/2", 12.6#, 13CR Vam Top completion string from surface to 6,509' 9/13/2007 00:00 - 02:30 2.50 ~ BUNCO P ~ RUNCMP RIH with 4 1/2", 12.6#, 13CR Vam Top completion string from i 6,509' to 8,806' 02:30 - 03:30 1.00 RUNCOIV IP RUNCMP Space out tubing hanger Printed: 10/3/2007 2:26:56 PM ~ ~ BP EXPLORATION Page 10 of 10 j Operations Summary Report Legal Well Name: N-27 Common Well Name: N-27 Spud Date: 8/30/2007 Event Name: DRILL+COMPLETE Start: 8/25/2007 End: 9/24/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/13/2007 Rig Name: NABOBS 7ES Rig Number: Date '~, From - To Hours Task i Code NPT li Phase Description of Operations _ _-- IrI~-_-- -- - - - -_ 9/13/2007 ~ 02:30 - 03:30 i 1.00 RUNCOt~1P RUNCMP Calculated 20' of pups required; used 19.52' 03:30 - 04:00 ; 0.50 04:00 - 05:30 ! 1.50 05:30 - 07:30 Pressure up, set a~ cker Test tubina to 4000 osi. chart and record for 30 minutes Test annulus to 4000 psi, chart and record for 30 mi 07:30-08:00 ~ 0.50~WHSUR P 08:00 - 09:30 ' 1.50 j BOPSU P 09:30 - 12:00 ~i 2.50 i W HSUR P 12:00 - 13:00 1.001 W HSUR P 13:00 - 16:00 3.001 WHSUR P 16:00 - 16:30 ~ 0.50 WHSUR P 16:30 - 17:00 j 0.50 WHSUR P 17:00 - 00:00 7.001 DEMOB P Bleed off annular pressure, bleed off tubing pressure, pressure up annular to 2700 psi to shear DCK valve, pump 3 bbls both ways RUNCMP Install TWC, test from below to 1000 psi for 10 minutes RUNCMP Nipple down BOPS RUNCMP Nipple up tree and adapter flange, test pack-off to 5000 psi, Test tree to 5000 psi with diesel, 30min test RUNCMP PJSM with DSM, RU Lubricator, test lubricator to 1000 psi for 5 min, Pull TWC, Install VR plugs in 9 5/8" x 7" Annulus RUNCMP PJSM with Little Red, Pressure test lines to 3500 pis, Reverse 177 bbls diesel, 2 BPM @ 1100 psi, allow well to U-tube. Freeze protected IA x OA to 2200' TVD RUNCMP FMC Dry Rod BPV, Little Red test BPV to 1000 psi from below RUNCMP Secure well, blow down and break service lines from rig to pits Release rig at 17:00 hrs POST Rig move to G-19B WLEG mule shoe at 8,804' iUNCO P RUNCMP Land tubing hanger; run in LDS iUNCO P RUNCMP Reverse circulate 137 bbls untreated seawater 94 bbls seawater treated with corrossion inhibitor 71 bbls untreated seawater 3 bpm, 230 psi 2.001 BUNCO P RUNCMP Drop ball and rod Printed: 10/3/2007 2:26:56 PM Digital Well File ~ ~ Page 1 of 1 Well: N-27 Well History Well Date Summary N-27 10/26/2007 T/1/O = 0/0/70. Temp = SI. TBG & IA FLs (pre-EL). Tt~g FL @ near surface. IA FL @ surface. N-27 11/25/2007 .Pull 4" CIW H BPV. Post-Rig. N-27 11/25/2007 "'WELL Sll ON ARRIVAL"' RIG UP SLICKLINE ***CONT JOB ON 11-16-07*** N-27 11/26/2007 "'CONY JOB FROM 11-25-07"' PULLED BALL & ROD FROM 8786' SLM. PULLED STA 3 @ 6086' SLM(1" BK-DGLV) &STA# 4 @ 3800' SLM(1" BEK-DCK SHEAR GLV). SET STA# 4 (1" BK-LGLV-16/64" ports, 1500# tro) @ 3800' SLM &STA# 3 (1" BK-S/O, 20/64" ports) @ 6086' SLM. PULLED 4 1/2" RHC PLUG BODY FROM 8785' SLM (8791' MD) = 6' CORRECTION. USED RHC DEPTH TO CORRECT FOR TAG. DRIFT TBG W/ 2.7/8" DUMMY PERF GUN. SD @ 9412' SLM + 6' CORRECTION= 9418' MD (BOTTOM SHOT IS TO BE@9218'MD) SAMPLE BAILER FULL OF SAND & MUD *** WELL S/I ON DEPARTURE, NOTIFY PAD OP*** N-27 11/27/2007 MOVE ONTO WELL, MEET WITH PAD OP, BEGIN RIG UP TO RUN CEMENT BOND LOG AND PERFORATE. ***** CONTINUE AWGRS ON 28-NOV-07 ***** N-27 11/28/2007 *" CONTINUED FROM 27-NOV-07 **' RUN SCMT BOND LOG GOOD CEMENT FROM 9,300' - 8,804'. PERFORATED 9.172' - 9.192' and 9.214' - 9.2 JET. 6 SPF GUNS. ALL SHOTS FIRED. ***JOB COMPLETE*** Print Da te: 12/20/2007 Page 1 of 1 http://digitalwellfile.bpweb.bp.com/WIInfo/Reports/ReportViewer.aspx 12/20/2007 by N-27 Su Report Date: i t-Sep-07 Client: BP Expkxation (Alaska; Field: Prudhoe Bay Unit - WOA Structure I Slot: N-PAD I N-27 Well: N-27 Borehole: N-27 uwuAPfu: 50029233650( Survey Name 1 Date: N-27 / September t 1, 200-r Tort 1 AHD 1 DDf 1 ERD ratio: 110.091 ° / 2570.73 ft / 5.470 10.28: Gtid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Fee Location Latllong: N 701915.721, W 148 54 36.86! location Grid NIE YIX: N 5968189.450 ftUS, E 634412.890 ftU: Grid Convergence Angle: +1.02612454° ort Schlumberger Vertical Section Azimuth: 180.770° Vertical Section Origin: N 0.000 ft, E 0.000 ft TVD Reference Datum: Rotary Table TVD Reference Elevation: 71.60 ft relative to MSl Sea Bed 1 Ground Level Elevation: 43.00 ft relative t0 MSL Magnetic Declination: 23.517° Total Field Strength: 57647.925 nT Magnetic Dip: 80.903° Declination Date: September 07, 2007 Magnetic Declination Model: BGGM 2007 North Reference: True North Total Corr Mag North -> True North: +23.517° Local Coordinates Referenced To: Well Head Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft d de h ft h ft ft ft ft d 1100 ft ftUS ftUS Klt U.W V.W U.UV -r7.DA U.UU V.VU U.UU V.VV u.uu u.uu v.w aavo~oa.ya vrw~c.oa ~~ rv ~a w.rct rr iyv~av.ova GYD GC SS 100.00 0.18 230.09 28.35 100.00 0.10 0.16 0.16 -0.10 -0.12 0.18 5968189.35 634412.77 N 70 1915.720 W 148 54 36.872 165.00 0.36 245.61 93.35 165.00 0.26 0.46 0.46 -0.25 -0.38 0.30 5968189.19 634412.51 N 70 1915.718 W 148 54 36.880 200.00 0.38 239.75 128.35 200.Q0 0.36 0.69 0.68 -0.35 -0.58 0.12 5968189.09 634412.31 N 701915.717 W 148 54 36.886 270.00 0.55 232.53 198.35 270.00 0.69 1.25 1.25 -0.68 -1.05 0.26 5968188.76 634411.85 N 70 1915.714 W 148 54 36.900 MWD+IFR+MS 301.18 0.30 208.23 229.53 301.18 0.85 1.48 1.47 -0.84 -1.21 0.97 5968188.59 634411.70 N 70 1915.712 W 148 54 36.904 392.14 1.22 177.88 320.48 392.13 2.03 2.67 2.39 -2.02 -1.29 1.07 5968187.41 634411.64 N 70 1915.701 W 148 54 36.906 481.27 0.52 264.89 409.60 481.25 3.02 3.82 3.43 -3.00 -1.65 1.46 5968186.42 634411.29 N 701915.691 W 148 54 36.917 570.82 2.95 273.71 499.10 570.75 2.95 6.53 5.23 -2.89 -4.36 2.72 5968186.49 634408.58 N 70 1915.692 W 148 54 36.996 660.99 4.76 262.61 589.06 660.71 3.36 12.57 10.87 -3.22 -10.39 2.16 5968186.05 634402.57 N 70 1915.689 W 148 54 37.172 750.21 7.46 258.16 677.77 749.42 5.15 22.06 20.32 -4.88 -19.73 3.07 5968184.21 634393.26 N 70 1915.673 W 148 54 37.444 838.73 9.29 258.28 785.34 836.99 7.95 34.95 33.21 -7.51 -32.35 2.07 5968181.36 634380.68 N 70 1915.647 W 148 54 37.8 935.55 12.18 253.14 860.46 932.11 12.73 52.97 51.22 -12.07 -49.78 3.14 5968176.50 634363.34 N 70 1915.602 W 148 54 38.3 1030.55 14.04 252.91 952.98 1024.63 19.30 74.52 72.74 -18.36 -70.39 1.96 5968169.84 634342.85 N 701915.540 W 148 54 38.92 1126.22 14.85 250.86 1045.62 1117.27 27.04 98.38 96.57 -25.79 -93.06 1.00 5968162.00 634320.31 N 70 1915.467 W 148 54 39.585 1222.97 15.21 251.33 1139.06 1210.71 35.48 123.47 121.62 -33.92 -116.80 0.39 5968153.45 634296.73 N 70 1915.387 W 148 54 40.277 1318.14 16.40 247.35 1230.64 1302.29 44.98 149.38 147.46 -43.09 -141.03 1.69 5968143.85 634272.67 N 701915.297 W 148 54 40.984 1413.46 18.75 246.23 1321.50 1393.15 56.69 178.16 176.10 -54.45 -167.47 2.49 5968132.02 634246.44 N 701915.185 W 148 54 41.756 1508.77 19.52 246.75 1411.55 1483.20 69.54 209.40 207.22 -66.91 -196.12 0.83 5968119.05 634218.02 N 701915.063 W 148 54 42.592 1604.33 21.21 246.75 1501.13 1572.78 83.07 242.66 240.38 -80.03 -226.67 1.77 5968105.38 634187.71 N 701914.933 W 148 54 43.484 1699.55 24.20 248.41 1588.96 1660.61 97.51 279.41 277.09 -94.02 -260.65 3.21 5968090.79 634153.99 N 701914.796 W 148 54 44.475 1796.34 22,74 248.53 1677.74 1749.39 112.14 317.95 315.62 -108.16 -296.51 1.51 5968076.00 634118.39 N 701914.657 W 148 54 45.522 1891.36 24.39 250.52 1764.84 1836.49. 125.88 355.94 353.60 -121.43 -332.10 1.93 5968062.10 634083.05 N 701914.526 W 148 54 46.560 1987.21 24.88 250.71 1851.96 1923.61 139.65 395.89 393.55 -134.69 -369.79 0.52 5968048.17 634045.60 N 70 1914.396 W 148 54 47.660 SurveyEditor Ver SP 2.1 Bld( doc40x_100) N-27\N-27\N-27\N-27 Generated 12/20/2007 3:46 PM Page 1 of 4 Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure k d d k k k ft k k k d 1100 k kUS ftUS [vai.yr [~.tKt cra.aa roJr.oi cw~.ac ~oJ.o~ 2179.50 26.03 240.00 2025.91 2097.56 171.91 2273.75 25.53 234.14 2110.80 2182.45 194.61 2369.30 24.14 230.29 2197.52 2269.17 219.58 2464.01 22.51 223.55 2284.50 2356.15 245.47 2559.47 21.48 216.69 2373.02 2444.67 273.04 2655.12 20.97 208.75 2462.20 2533.85 302.34 2750.43 20.99 197.92 2551.23 2622.88 333.72 2846.48 21.15 184.63 2640.91 2712.56 367.47 2942.02 19.45 173.05 2730.55 2802.20 400.45 3036.83 19.12 171.45 2820.04 2891.69 431.41 3132.70 18.41 164.98 2910.82 2982.47 461.48 3162.93 18.80 162.83 2939.47 3011.12 470.70 3269.41 17.91 160.81 3040.54 3112.19 502.42 3365.96 18.11 159.71 3132.35 3204.00 530.37 3462.95 17.53 157.52 3224.69 3296.34 557.86 3554.40 16.43 158.17 3312.15 3383.80 582.46 3648.40 15.45 160.19 3402.54 3474.19 606.45 3744.97 15.84 160.34 3495.53 3567.18 630.85 3841.05 15.21 161.08 3588.11 3659.76 655.00 3936.20 15.38 161.41 3679.89 3751.54 678.66 4032.02 16.24 164.88 3772.08 3843.73 703.53 4127.97 16.14 164.49 3864.23 3935.88 729.24 4223.41 16.27 164.10 3955.87 4027.52 754.78 4319.75 17.37 160.96 4048.09 4119.74 781.24 4415.03 16.48 161.98 4139.25 4210.90 807.41 4510.83 16.62 159.09 4231.08 4302.73 833.01 4606.31 16.55 159.52 4322.59 4394.24 858.37 4701.34 16.12 159.31 4413.78 4485.43 883.27 4798.44 15.82 158.72 4507.13 4578.78 908.08 4893.48 16.09 158.95 4598.51 4670.16 932.31 4988.86 15.27 163.59 4690.35 4762.00 956.58 5084.12 15.59 164.17 4782.17 4853.82 980.83 5179.89 16.41 165.30 4874.23 4945.88 1006.21 5275.45 17.44 165.11 4965.65 5037.30 1033.00 5371.03 17.47 164.87 5056.83 5128.48 1060.59 5465.97 16.78 162.89 5147.56 5219.21 1087.34 5562.66 16.52 161.87 5240.20 5311.85 1113.63 5657.82 16.45 161.87 5331.45 5403.10 1139.18 5754.08 17.01 161.13 5423.63 5495.28 1165.33 5849.28 16.72 161.56 5514.74 5586.39 1191.38 9J~7.00 YJJ..7Y -IYO.IJ -YV/.YY V.JV JO{lVVJY.VY v~rfwv.cv ~~ •v acs ~Y.~v.s ~• ~-~v yr-fv.~ 477.83 475.29 -165.94 -445.38 4.51 5968015.58 633970.59 N 70 1914.089 W 148 54 49.866 518.79 515.34 -188.18 -479.76 2.75 5967992.73 633936.62 N 70 1913.870 W 148 54 50.869 558.91 553.95 -212.73 -511.48 2.23 5967967.62 633905.34 N 70 1913.628 W 148 54 51.795 596.37 589.19 -238.24 -538.87 3.30 5967941.61 633878.41 N 70 1913.377 W 148 54 52.594 632.09 621.48 -265.51 -561.91 2.90 5967913.94 633855.87 N 70 1913.109 W 148 54 53.266 666.67 651.06 -294.56 -580.61 3.05 5967884.56 633837.69 N 70 1912.823 W 148 54 53.812 700.71 677.53 -325.77 -594.07 4.06 5967853.12 633824.79 N 701912.516 W 148 54 54.205 735.10 700.08 -359.43 -600.77 4.97 5967819.35 633818.70 N 701912.185 W 148 54 54.400 768.15 717.13 -392.41 X00.23 4.56 5967786.38 633819.83 N 701911.861 W 148 54 54.384 799.46 731.12 -423.44 -596.02 0.66 5967755.44 633824.60 N 701911.556 W 148 54 54.261 830.27 744.01 -453.59 -589.76 2.29 5967725.41 633831.40 N 701911.259 W 148 54 54.0 839.91 747.60 -462.86 -587.08 2.61 5967716.19 633834.24 N 70 1911.168 W 148 54 54.000 873.44 759.77 -494.71 -576.64 1.03 5967684.53 633845.25 N 70 1910.855 W 148 54 53.696 903.29 770.91 -522.81 -566.55 0.41 5967656.62 633855.84 N 70 1910.579 W 148 54 53.401 932.97 782.20 -550.44 -555.74 0.91 5967629.19 633867.14 N 70 1910.307 W 148 54 53.086 959.68 792.83 -575.18 -545.66 1.22 5967604.64 633877.66 N 70 1910.064 W 148 54 52.792 985.49 804.34 -599.30 -536.48 1.20 5967580.69 633887.27 N 7019 9.826 W 148 54 52.523 1011.53 817.06 X23.81 -527.68 0.41 5967556.34 633896.50 N 70 19 9.585 W 148 54 52.267 1037.25 830.40 -648.08 -519.18 0.69 5967532.23 633905.44 N 70 19 9.347 W 148 54 52.019 1062.35 844.17 -671.85 -511.12 0.20 5967508.61 633913.93 N 70 19 9.113 W 148 54 51.783 1088.44 859.74 -696.83 -503.57 1.33 5967483.77 633921.92 N 70 19 8.867 W 148 54 51.563 1115.20 876.76 -722.63 -496.50 0.15 5967458.10 633929.45 N 70 19 8.613 W 148 54 51.357 1141.83 894.05 -748.27 -489.29 0.18 5967432.60 633937.11 N 70 19 8.361 W 148 54 51.146 1169.70 911.95 -774.85 -480.90 1.48 5967406.18 633945.98 N 7019 8.100 W 148 54 50.901 1197.44 929.89 -801.14 -472.08 0.98 5967380.05 633955.27 N 70 19 7.841 W 148 54 50.644 1224.72 947.66 -826.86 -462.98 0.87 5967354.50 633964.82 N 70 19 7.588 W 148 54 50.379 1251.98 965.43 -852.36 -453.36 0.15 5967329.18 633974.90 N 70 19 7.338 W 148 54 50.098 1278.70 983.31 -877.38 -443.96 0.46 5967304.33 633984.75 N 70 19 7.092 W 148 54 49.823 1305.42 1001.44 -902.32 -434.40 0.35 5967279.57 633994.76 N 7019 6.846 W 148 54 49. 1331.54 1019.48 -926.68 -424.96 0.29 5967255.38 634004.62 N 7019 6.607 W 148 54 49.2 1357.31 1038.34 -951.07 -416.67 1.57 5967231.15 634013.35 N 7019 6.367 W 148 54 49.027 1382.65 1057.94 -975.42 -409.63 0.37 5967206.93 634020.82 N 7019 6.127 W 148 54 48.821 1409.05 1078.86 -1000.88 -402.69 0.92 5967181.60 634028.22 N 7019 5.877 W 148 54 48.619 1436.87 1101.28 -1027.78 -395.58 1.08 5967154.83 634035.81 N 7019 5.612 W 148 54 48.411 1465.54 1124.58 -1055.47 -388.16 0.08 5967127.28 634043.73 N 7019 5.340 W 148 54 48.195 1493.49 1147.23 -1082.33 -380.41 0.95 5967100.57 634051.96 N 70 19 5.076 W 148 54 47.969 1521.20 1169.48 -1108.73 -372.02 0.40 5967074.32 634060.81 N 7019 4.816 W 148 54 47.724 1548.20 1191.25 -1134.39 -363.62 0.07 5967048.82 6349.67 N 7019 4.564 W 148 54 47.479 1575.91 1213.70 -1160.67 -354.83 0.62 5967022.71 634078.93 N 7019 4.305 W 148 54 47.222 1603.53 1236.24 -1186.84 -345.99 0.33 5966996.70 634088.24 N 7019 4.048 W 148 54 46.964 SurveyEditor Ver SP 2.1 Bld( doc40x_100) N-27\N-27\N-27\N-27 Generated 12/20/2007 3:46 PM Page 2 of 4 CommeMS Measured Inclination Azimuth Sub-Sea ND TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de d ft ft k ft ft k ft de 1100 k ftUS kUS 5944.54 16.20 161.34 5606.09 5677.74 1216.85 1630.52 1258.50 -1212.43 -337.40 0.55 5966971.27 634097.28 N 7019 3.796 W 148 54 46.714 6040.03 15.86 161.51 5697.87 5769.52 1241.73 1656.89 1280.41 -1237.42 -329.00 0.36 5966946.44 634106.12 N 70 19 3.551 W 148 54 46.468 6135.22 15.77 160.77 5789.46 5861.11 1266.17 1682.83 1302.06 -1261.97 -320.62 0.23 5966922.04 634114.95 N 70 19 3.309 W 148 54 46.224 6230.36 16.91 159.57 5880.75 5952.40 1291.22 1709.59 1324.31 -1287.15 -311.53 1.25 5966897.04 634124.48 N 70 19 3.062 W 148 54 45.959 6325.26 16.38 160.28 5971.67 6043.32 1316.62 1736.78 1347.01 -1312.68 -302.20 0.60 5966871.68 634134.27 N 70 19 2.811 W 148 54 45.686 6421.56 16.40 161.18 6064.06 6135.71 1342.15 1763.95 1370.07 -1338.33 -293.23 0.26 5966846.20 634143.70 N 7019 2.558 W 148 54 45.425 6517.29 16,05 161.02 6155.98 6227.63 1367.33 1790.70 1393.01 -1363.63 -284.57 0.37 5966821.05 634152.81 N 7019 2.309 W 148 54 45.172 6612.36 16.74 164.31 6247.18 6318.83 1392.83 1817.52 1416.51 -1389.24 -276.59 1.22 5966795.59 634161.25. N 70 19 2.057 W 148 54 44.939 6708.89 16.01 165.12 6339.80 6411.45 1418.98 1844.74 1440.90 -1415.49 -269.41 0.79 5966769.48 634168.89 N 70191.799 W 148 54 44.729 6804.09 16.39 162.12 6431.22 6502.87 1444.35 1871.29 1464.57 -1440.96 -261.92 0.97 5966744.15 634176.84 N 70191.549 W 148 54 44.511 6899.36 17.01 157.16 6522.48 6594.13 1469.86 1898.65 1488.16 -1466.60 -252.38 1.63 5966718.69 634186.83 N 70 191.297 W 148 54 44.2 6994.97 15.81 155.91 6614.19 6685.84 1494.49 1925.66 1510.83 -1491.38 -241.63 1.31 5966694.11 634198.02 N 7019 1.053 W 148 54 43.9 7091.80 16.21 159.33 6707.27 6778.92 1519.04 1952.36 1533.64 -1516.07 -231.48 1.06 5966669.61 634208.61 N 70 19 0.810 W 148 54 43.62 7186.52 15.57 162.22 6798.37 6870.02 1543.40 1978.29 1556.59 -1540.54 -222.93 1.07 5966645.29 634217.60 N 7019 0.569 W 148 54 43.373 7282.31 16.22 161.93 6890.49 6962.14 1568.25 2004.52 1580.18 -1565.50 -214.85 0.68 5966620.48 634226.12 N 7019 0.324 W 148 54 43.138 7377.80 16.94 160.54 6982.01 7053.66 1593.92 2031.77 1604.59 -1591.30 -206.08 0.86 5966594.85 634235.35 N 70 19 0.070 W 148 54 42.882 7473.81 17.54 158.02 7073.71 7145.36 1620.39 2060.22 1629.73 -1617.90 -196.01 1.00 5966568.43 634245.90 N 70 18 59.809 W 148 54 42.588 7569.25 17.44 157.21 7164.74 7236.39 1646.76 2088.90 1654.81 -1644.42 -185.09 0.28 5966542.11 634257.30 N 70 18 59.548 W 148 54 42.269 7664.90 17.32 157.28 7256.02 7327.67 1672.96 2117.48 1679.81 -1670.77 -174.03 0.13 5966515.97 634268.82 N 70 18 59.289 W 148 54 41.946 7760.13 17.05 157.03 7347.00 7418.65 1698.74 2145.61 1704.52 -1696.70 -163.11 0.29 5966490.24 634280.20 N 7018 59.034 W 148 54 41.628 7855.78 16.62 156.65 7438.55 7510.20 1724.06 2173.31 1728.88 -1722.17 -152.22 0.46 5966464.97 634291.55 N 7018 58.783 W 148 54 41.310 7951.96 16.14 156.80 7530.83 7602.48 1748.83 2200.44 1752.81 -1747.08 -141.50 0.50 5966440.25 634302.71 N 7018 58.538 W 148 54 40.997 8045.98 17.03 159.82 7621.89 7693.54 1773.89 2227,55 1777.16 -1772.29 -131.50 1.30 5966415.24 634313.16 N 7018 58.290 W 148 54 40.705 8141.69 16.19 160.74 7712.65 7784.30 1799.25 2254.63 1801.93 -1797.77 -122.36 0.93 5966389.92 634322.76 N 70 1858.040 W 148 54 40.439 8237.67 16.82 162.76 7804.68 7876.33 1825.03 2281.89 1827.21 -1823.67 -113.83 0.89 5966364.19 634331.75 N 70 18 57.785 W 148 54 40.190 8334.09 15.70 163.48 7897.24 7968.89 1850.75 2308.89 1852.53 -1849.50 -105.98 1.18 5966338.50 634340.05 N 7018 57.531 W 148 54 39.961 8428.00 15.01 163.50 7987.80 8059.45 1874.50 2333.75 1875.95 -1873.34 -98.92 0.73 5966314.79 634347.54 N 70 18 57.296 W 148 54 39.755 8523.53 14.38 164.61 8080.20 8151.85 1897.71 2357.99 1898.88 -1896.64 -92.25 0.72 5966291.62 634354.62 N 70 18 57.067 W 148 54 39.560 8619.52 13.88 164.19 8173.29 8244.94 1920.19 2381.42 1921.13 -1919.21 -85.95 0.53 5966269.17 634361.32 N 70 1856.845 W 148 54 39.377 8714.48 13.33 163.65 8265.58 8337.23 1941.57 2403.76 1942.31 -1940.67 -79.77 0.59 5966247.82 634367.89 N 701856.634 W 148 54 39.1• 8810.13 12.68 162.35 8358.78 8430.43 1962.07 2425.28 1962.63 -1961.26 -73.48 0.75 5966227.35 634374.55 N 701856.432 W 148 54 39.013 8842.06 12.70 161.63 8389.93 8461.58 1968.71 2432.30 1969.22 -1967.93 -71.31 0.50 5966220.72 634376.83 N 70 1856.386 W 148 54 38.949 8904.03 12.42 161.77 8450.42 8522.07 1981.44 2445.77 1981.86 -1980.72 -67.08 0.45 5966208.01 634381.29 N 701856.240 W 148 54 38.826 8978.19 12.86 161.32 8522.78 8594.43 1996.77 2462.00 1997.07 -1996.11 -61.94 0.61 5966192.71 634386.71 N 701856.089 W 148 54 38.676 9043.37 12.54 160.92 8586.36 8658.01 2010.26 2476.33 2010.49 -2009.67 -57.31 0.51 5966179.24 634391.58 N 7018 55.956 W 148 54 38.541 9138.85 12.32 160.08 8679.61 8751.26 2029.54 2496.88 2029.67 -2029.04 -50.45 0.30 5966159.99 634398.79 N 70 18 55,765 W 148 54 38.341 9234.50 12.02 160.56 8773.11 8844.76 2048.43 2517.04 2048.50 -2048.03 -43.66 0.33 5966141.13 634405.92 N 7018 55.578 W 148 54 38.142 9329.72 11.78 159.29 8866.28 8937.93 2066.78 2536.68 2066.80 -2066.47 -36.92 0.37 5966122.82 634412.98 N 7018 55.397 W 148 54 37.946 9425.76 11.06 160.36 8960.42 9032.07 2084.54 2555.69 2084.54 -2084.32 -30.36 0.78 5966105.09 634419.86 N 7018 55.222 W 148 54 37.754 Last Survey 9455.11 10.91 160.85 8989.23 9060.88 2089.79 2561.29 2089.79 -2089.59 -28.50 0.60 5966099.85 634421.82 N 7018 55.170 W 148 54 37.701? SurveyEditor Ver SP 2.1 Bid( doc40x_100) N-27\N-27\N-27\N-27 Generated 12/20/2007 3:46 PM Page 3 of 4 Comments Measured Inclination Azimuth Sub-Sea TVD ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft k ft ft ft ft ft de 100 ft ftUS ftUS IUtYtO~CIHn) `JOUD.W IU.`Jl IW.8.7 `JU38.LG `JlUY.0r LU~O.O/ L.7/U./3 LUYO.0/ -GU~O.~1 -G.7.'iV V.VV a~wav.aa VJ~-.GJ.V/ Y~~vIVJJ.VVL r• -+o.r~ar.vw Survey Type: Definitive Survey NOTES: GYD GC SS - (Gyrodata -gyro single shots - Gyrodata gyro orientation surveys. Not to be run above 70 degrees inGination. ) MWD + IFR + MS - (In-field referenced MWD with mull-station analysis and correction applied In post-processing.) Leoal Descrilation: Northing (Yi IftUSI Eastins~ (Xl IftUSI Surface : 2285 FSL 4709 FEL S8 T11 N R13E UM 5968189.45 634412.89 BHL : 186 FSL 4742 FEL S8 T11N R13E UM 5966090.99 634425.07 C~ i SurveyEditor Ver SP 2,1 Bld( doc40x_100) N-27\N-27\N-27\N-27 Generated 12/20/2007 3:46 PM Page 4 of 4 KB. ELEV = 71.7' BF. ELEV = 45.8' KOP = 500 Max Angle = 24 DEG @ 3213 Datum MD = Datum N D = TREE = CNV 4-1 /16 5M WELLHEAD = FMC Gen 5 CSG HEAD = 11" 5M W/ 7" MANDREL HANGER & PACKOFF TBG SPOOL = 11" X 11" SM TBG HANGER = 11" X 4-1/2" ADP FLANGE= 11"X4-1/16" 108' 20", 91.5 Ib/ft, H-40 Non-Insulated Conductor 2201' HES 4-1/2 'X' Landing Nipple; ID = 3.813" 3222' 9-5/8", 47 #/ft, L-80, BTC, ID = 8.681 ST MD ND DEV TYPE VLV LATCH PORT DATE 4 3811 3631 15 KBG2 DOME BK 16 11/26/07 3 6100 5827 16 KBG2 SO BK 20 11/26/07 2 7637 7301 17 KBG2 DMY BK 0 09/15/07 1 8629 8254 14 KBG2 SO BK 0 09/15/07 8707' HES 4-1/2" X NIPPLE; I.D. 3.813" 8727' BAKER PKR 7" X 4-1/2" S-3, ID = 3.88", 12' TBS 8760' HES 4-1/2" X NIPPLE; ID = 3.813" 8791' HES 4-1/2" XN NIPPLE; ID = 3.725" 9032' 4-1/2", 12.6#, L-80, IBT-M, MARKER JT @ TSAD 9,417' 4-1/2" PBTD 9503' 4-1/2", 12.6#, L-80, IBT-M, ID = 3.958", 0.01522 BPF DATE REV BY COMMENTS DATE REV BY COMMENTS 09/13/07 N7ES ORIGINAL COMPLETION 09115/07 /TLH GLV CORRECTIONS 11 /26/07 JLJ/PJC GLV C/O 11/28/07 RRD/PJC DRLG DRAFT CORRECTIONS 12/15/07 TEUPJC PERFORATIONS (11/28107) 12/15/07 PJC LOCATION CORRECTION PRUDHOE BAY UNfT WELL: N-27 PERMTf No: 2071040 API No: 50-029-23365-00 SEC 8, T11 N, R13E. 2285' FSL & 571' FWL BP Exploration (Alaska) N-271 DRLG DRAFT 11 /21 /07 NO. 4509 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite a0o Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken A77N: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Milne Pt., Endicott~~~'~~ Well .Inh # 1 nn rlncrri ntinn n~~~ ci r+..~... nn Z-10 11676974 GLS '~-~::~, -- ,?/ 11/11/07 1 06-16 11686797 PPROF & RS ; °- ~" _ f•" *"? 11/15/07 1 MPL-33 11661179 _... MEM INJECTION PROFILE ~,,7 t {* z~h :k -¢;~ - 11/13/07 1 MPF-25 11846827 USIT ~ i' `~~ "- ~' c`, 11/10107 1 GNI-04 11846828 USIT ,_~~~')~`=)-._. d °'`y- 11111/07 1 OWDW-SW 11626128 RST ~ ~ ~•,'•~ . - , '.`s"-. '' ~ _? ':~t- 10/10/07 1 1 3-35IL-36 11630502 RST ; i~~"°.;)~Y.: Zq~•i +.e--- ~-a~.~, 09/09/07 1 1 15-266 11661165 MCNL ,z ,a :r,'.~ a ~:--`~ i.t „~°•-•~t =F'~' 08/24/07 1 1 05-36A 10928638 MCNL fp ~:, - ~'f~~~~9./') `~ t °~ a. ~" ~ 06/11/05 1 1 07-16A 11216211 MCNL ~ _; r -- '-°" ~ '"`~ d ~~ • (~'~ 08/27/06 1 1 2-28B/0-19 11638650 RST ~) t,~ - ~, ~ 1;,, t • ~ - ;~- "'3 07105/07 1 1 07-02A 11649983 MCNL ~~r"~--~`~i'}~ i' - ~ a°''~ 08/07/07 1 1 N-27 40015763 OH MWD/LWD EDIT ":..y/~j`; • P;--°°_ / 09/11/07 2 1 ~a.rw~ rwrvw rra_G/vG f~CliUr ~ o~ JIV1911YV NIYU RC1 URIYIIVV VIVC l'}Jr'T •6,Hl.r'I I V: BP Exploration (Alaska) Inc. ~ ~sl ~~ ` t~ , Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ,., Date Delivered: z`s}i11136 r•~4+ue Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-283'; A7TN: Beth ,~ ~' ~ .~~ _ _ Received by i ~ ~ ~' ~, • Date I1-09-2007 Transmittal Number:92919 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA FIELD LOG DATA) If you have anv questions, please contact Douglas Dortch at the PDC at 564-4973 Delivery Contents 1 CD-ROM Containing Field Log Data & Electronic Log Prints for the following wells: 17-.07~ . ~,b~~.l._l2.__.~-~.~_._ ___ -~ ^~ -091 ~~'.}_ ,1~ ~. _.'~ r5~(~_ G-27_A ~0~. ~~.1~._ "~ ~ 5~ Y~ Please~ign and Return one copy of this transmittal. Thank You, Douglas Dortch Petrotechnical Data Center Attn: State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 `~~,~ 5 ~ t is~ Sj=~ Petrotechnical Data Center LR2- I 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 995 1 9-66 1 2 // 09/27/07 U • ~7~i~~~b~~~~ir~ N0.4437 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Wnll .Inh !t Inn Dacrrintinn Date RI Cnlnr CD 15-29A 11686783 SCMT ab 09/05/07 1 OS-256 11630496 SCMT _ < 08/30/07 1 02-33A 11813082 SCMT 08131/07 1 15-28A 11686782 SCMT 09/04/07 1 N-27 11824345 SCMT - ~ 09112107 1 05-22A 11813086 SCMT 09/18/07 1 S-400A 11855508 USIT - 09/18/07 1 E-27A 11676963 USIT (CEMENT) 09/18/07 1 E-27A 11676963 USIT (CORROSION) - 09/18/07 1 MPG-07 11594520 USIT = - 08/29!07 1 MPS-37 NIA SCMT 09/08/07 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACIi TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. - .. p~ ~\ j~ ~ ~j -~ Anchorage, Alaska 99508 ,; t Date Delivered: -:--- ,,, y_ ~~ ._. Alaska Data & Consulting Seni es 2525 Gambell Street, Suite 4 0 Anchorage, AK 99503-283 ATTN: Beth -~ ~ _ _,__ Received b ib ',~.~m~6, P -.; .. SCHLUMBERGER Survey report Client ...................: BP Exploration (Alaska) Inc. Field ....................: Prudhoe Bay Well .....................: N-27 API number ...............: 50-29-23365-00 Engineer .................: E. Galotta RIG :.....................: 7E5 STATE :...................: AK ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ---- Permanent datum..........: Depth reference..........: GL above permanent.......: KB above permanent.......: DF above permanent.......: MEAN SEA LEVEL Driller's Pipe Tally 43.00 ft N/A 71.68 ft ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: -999.25 ft Departure (+E/W-)........: -999.25 ft Azimuth from Vsect Origin to target: 180.77 degrees G I,~ a [(0)2007 IDEAL ID12_OC_09] 11-Sep-2007 13:20:06 Page 1 of 5 Spud date ................: 30-Aug-07 Last survey date.........: 11-Sep-07 Total accepted surveys...: 106 MD of first survey.......: 0.00 ft MD of last survey........: 9505.00 ft ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2006 Magnetic date ............: 29-Aug-2007 Magnetic field strength..: 57656.65 GAMA Magnetic dec (+E/W-)...... 23.73 degrees Magnetic dip .............: 80.94 degrees ----- MWD survey Reference Reference G ............... Reference H ............... Reference Dip ............: Tolerance of G...........: Tolerance of H............ Tolerance of Dip.........: Criteria --------- 1002.68 meal 57656.50 GAMA 80.94 degrees (+/-) 2.50 meal (+/-)300.00 GAMA (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 23.73 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 23.73 degrees (Total az corr = magnetic dec - grid cony) Survey Correction Type .... I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction • • r SCHLUMBERGER Survey Report 11 -Sep-2007 13:20:06 Page 2 of 5 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP None 2 100.00 0.18 230.09 100.00 100.00 0.10 -0.10 -0.12 0.16 230.09 0.18 BP _CB GYRO MS 3 165.00 0.36 245.61 65.00 165.00 0.26 -0.25 -0.38 0.46 236.92 0.30 BP _CB GYRO MS 4 200.00 0.38 239.75 35.00 200.00 0.36 -0.35 -0.59 0.68 238.79 0.12 BP _CB GYRO MS 5 270.00 0.55 232.53 70.00 270.00 0.69 -0.68 -1.05 1.25 237.29 0.26 BP _CB GYRO MS • 6 301.18 0.30 208.23 31.18 301.17 0.85 -0.84 -1.21 1.47 235.26 0.97 BP _MWD+IFR+MS 7 392.14 1.22 177.88 90.96 392.13 2.03 -2.02 -1.29 2.39 212.54 1.07 BP _MWD+IFR+MS 8 481.27 0.52 264.89 89.13 481.25 3.02 -3.00 -1.65 3.43 208.87 1.46 BP _MWD+IFR+MS 9 570.82 2.95 273.71 89.55 570.75 2.95 -2.89 -4.36 5.23 236.48 2.72 BP _MWD+IFR+MS 10 660.99 4.76 262.61 90.17 660.71 3.36 -3.22 -10.39 10.87 252.78 2.16 BP MWD+IFR+MS 11 750.21 7.46 258.16 89.22 749.42 5.15 -4.88 -19.73 20.32 256.10 3.07 BP _MWD+IFR+MS 12 838.73 9.29 258.28 88.52 836.99 7.95 -7.51 -32.35 33.21 256.92 2.07 BP _MWD+IFR+MS 13 935.55 12.18 253.14 96.82 932.11 12.73 -12.07 -49.78 51.22 256.38 3.14 BP _MWD+IFR+MS 14 1030.55 14.04 252.91 95.00 1024.63 19.30 -18.36 -70.39 72.74 255.38 1.96 BP _MWD+IFR+MS 15 1126.22 14.85 250.86 95.67 1117.27 27.04 -25.79 -93.06 96.57 254.51 1.00 BP MWD+IFR+MS 16 1222.97 15.21 251.33 96.75 1210.71 35.48 -33.92 -116.80 121.62 253.81 0.39 BP _MWD+IFR+MS 17 1318.14 16.40 247.35 95.17 1302.29 44.98 -43.09 -141.03 147.46 253.01 1.69 BP _MWD+IFR+MS 18 1413.46 18.75 246.23 95.32 1393.15 56.69 -54.45 -167.47 176.10 251.99 2.49 BP _MWD+IFR+MS 19 1508.77 19.52 246.75 95.31 1483.20 69.54 -66.91 -196.12 207.22 251.16 0.83 BP _MWD+IFR+MS 20 1604.33 21.21 246.75 95.56 1572.78 83.07 -80.03 -226.67 240.38 250.55 1.77 BP _MWD+IFR+MS • 21 1699.55 24.20 248.41 95.22 1660.61 97.51 -94.02 -260.65 277.09 250.17 3.21 BP _MWD+IFR+MS 22 1796.34 22.74 248.53 96.79 1749.39 112.14 -108.16 -296.51 315.62 249.96 1.51 BP _MWD+IFR+MS 23 1891.36 24.39 250.52 95.02 1836.49 125.88 -121.43 -332.10 353.60 249.92 1.93 BP _MWD+IFR+M5 24 1987.21 24.88 250.71 95.85 1923.61 139.65 -134.69 -369.79 393.55 249.99 0.52 BP _MWD+IFR+MS 25 2081.97 25.04 249.95 94.76 2009.52 153.61 -148.15 -407.44 433.54 250.02 0.38 BP MWD+IFR+MS 26 2179.50 26.03 240.00 97.53 2097.56 171.91 -165.94 -445.38 475.29 249.57 4.51 BP _MWD+IFR+MS 27 2273.75 25.53 234.14 94.25 2182.45 194.61 -188.18 -479.76 515.34 248.58 2.75 BP _MWD+IFR+MS 28 2369.30 24.14 230.29 95.55 2269.17 219.58 -212.73 -511.48 553.95 247.42 2.23 BP _MWD+IFR+MS 29 2464.01 22.51 223.55 94.71 2356.15 245.46 -238.24 -538.87 589.19 246.15 3.30 BP _MWD+IFR+MS 30 2559.47 21.48 216.69 95.46 2444.67 273.04 -265.51 -561.91 621.48 244.71 2.90 BP MWD+IFR+MS [(c)2007 IDEAL ID12_OC_09] a SCHLUMBERGER Survey Report 11 -Sep-2007 13:20:06 Page 3 of 5 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DL5 Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 31 2655.12 20.97 208.75 95.65 2533.85 302.34 -294.56 -580.61 651.06 243.10 3.05 BP _MWD+IFR+MS 32 2750.43 20.99 197.92 95.31 2622.88 333.72 -325.77 -594.07 677.53 241.26 4.06 BP _MWD+IFR+MS 33 2846.48 21.15 184.63 96.05 2712.56 367.47 -359.43 -600.77 700.08 239.11 4.97 BP _MWD+IFR+MS 34 2942.02 19.45 173.05 95.54 2802.20 400.45 -392.41 -600.23 717.13 236.82 4.56 BP _MWD+IFR+MS 35 3036.83 19.12 171.45 94.81 2891.69 431.41 -423.44 -596.02 731.12 234.61 0.66 BP _MWD+IFR+MS • 36 3132.70 18.41 164.98 95.87 2982.47 461.47 -453.59 -589.76 744.01 232.44 2.29 BP_MWD+IFR+MS 37 3162.93 18.80 162.83 30.23 3011.12 470.70 -462.86 -587.08 747.60 231.75 2.61 BP _MWD+IFR+MS 38 3269.41 17.91 160.81 106.48 3112.18 502.42 -494.71 -576.64 759.77 229.37 1.03 BP _MWD+IFR+MS 39 3365.96 18.11 159.71 96.55 3204.00 530.37 -522.81 -566.55 770.91 227.30 0.41 BP _MWD+IFR+MS 40 3462.95 17.53 157.52 96.99 3296.34 557.86 -550.44 -555.74 782.20 225.27 0.91 BP MWD+IFR+MS 41 3554.40 16.43 158.17 91.45 3383.80 582.46 -575.18 -545.66 792.83 223.49 1.22 BP _MWD+IFR+MS 42 3648.40 15.45 160.19 94.00 3474.19 606.45 -599.30 -536.48 804.34 221.83 1.20 BP _MWD+IFR+MS 43 3744.97 15.84 160.34 96.57 3567.18 630.84 -623.81 -527.68 817.06 220.23 0.41 BP _MWD+IFR+MS 44 3841.05 15.21 161.08 96.08 3659.76 655.00 -648.08 -519.18 830.40 218.70 0.69 BP _MWD+IFR+MS 45 3936.20 15.38 161.41 95.15 3751.54 678.66 -671.85 -511.12 844.17 217.26 0.20 BP MWD+IFR+MS 46 4032.02 16.24 164.88 95.82 3843.73 703.53 -696.83 -503.57 859.74 215.85 1.33 BP _MWD+IFR+MS 47 4127.97 16.14 164.49 95.95 3935.88 729.24 -722.63 -496.50 876.76 214.49 0.15 BP _MWD+IFR+MS 48 4223.41 16.27 164.10 95.44 4027.52 754.78 -748.27 -489.29 894.05 213.18 0.18 BP _MWD+IFR+MS 49 4319.75 17.37 160.96 96.34 4119.74 781.24 -774.85 -480.90 911.95 211.83 1.48 BP _MWD+IFR+MS 50 4415.03 16.48 161.98 95.28 4210.90 807.41 -801.14 -472.08 929.89 210.51 0.98 BP _MWD+IFR+MS • 51 4510.83 16.62 159.09 95.80 4302.73 833.01 -826.86 -462.99 947.66 209.25 0.87 BP _MWD+IFR+MS 52 4606.31 16.55 159.52 95.48 4394.24 858.37 -852.36 -453.36 965.43 208.01 0.15 BP _MWD+IFR+MS 53 4701.34 16.12 159.31 95.03 4485.43 883.27 -877.38 -443.96 983.31 206.84 0.46 BP _MWD+IFR+MS 54 4798.44 15.82 158.72 97.10 4578.78 908.08 -902.32 -434.40 1001.44 205.71 0.35 BP _MWD+IFR+MS 55 4893.48 16.09 158.95 95.04 4670.16 932.31 -926.68 -424.96 1019.48 204.64 0.29 BP MWD+IFR+MS 56 4988.86 15.27 163.59 95.38 4762.00 956.58 -951.07 -416.67 1038.34 203.66 1.57 BP _MWD+IFR+M5 57 5084.12 15.59 164.17 95.26 4853.82 980.83 -975.42 -409.63 1057.94 202.78 0.37 BP _MWD+IFR+MS 58 5179.89 16.41 165.30 95.77 4945.88 1006.21 -1000.89 -402.69 1078.86 201.92 0.92 BP _MWD+IFR+MS 59 5275.45 17.44 165.11 95.56 5037.30 1033.00 -1027.78 -395.58 1101.28 201.05 1.08 BP _MGJD+IFR+MS 60 5371.03 17.47 164.87 95.58 5128.48 1060.59 -1055.47 -388.16 1124.58 200.19 0.08 BP MWD+IFR+MS [(c)2007 IDEAL ID12_OC_09] SCHLUMBERGER Survey Report 11 -Sep-2007 13:20:06 Page 4 of 5 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 61 5465.97 16.78 162.89 94.94 5219.21 1087.34 -1082.33 -380.41 1147.23 199.37 0.95 BP _MWD+IFR+MS 62 5562.66 16.52 161.87 96.69 5311.85 1113.63 -1108.73 -372.02 1169.48 198.55 0.40 BP _MWD+IFR+MS 63 5657.82 16.45 161.87 95.16 5403.10 1139.18 -1134.39 -363.62 1191.25 197.77 0.07 BP _MWD+IFR+MS 64 5754.08 17.01 161.13 96.26 5495.28 1165.33 -1160.67 -354.83 1213.70 197.00 0.62 BP _MWD+IFR+MS 65 5849.28 16.72 161.56 95.20 5586.39 1191.38 -1186.84 -345.99 1236.24 196.25 0.33 BP _MWD+IFR+MS • 66 5944.54 16.20 161.34 95.26 5677.74 1216.85 -1212.43 -337.40 1258.50 195.55 0.55 BP _MWD+IFR+MS 67 6040.03 15.86 161.51 95.49 5769.52 1241.73 -1237.42 -329.00 1280.41 194.89 0.36 BP _MWD+IFR+MS 68 6135.22 15.77 160.77 95.19 5861.11 1266.17 -1261.97 -320.62 1302.06 194.26 0.23 BP _MWD+IFR+MS 69 6230.36 16.91 159.57 95.14 5952.40 1291.22 -1287.15 -311.53 1324.31 193.61 1.25 BP _MWD+IFR+MS 70 6325.26 16.38 160.28 94.90 6043.32 1316.62 -1312.68 -302.20 1347.01 192.96 0.60 BP MWD+IFR+MS 71 6421.56 16.40 161.18 96.30 6135.71 1342.15 -1338.33 -293.23 1370.07 192.36 0.26 BP _MWD+IFR+MS 72 6517.29 16.05 161.02 95.73 6227.63 1367.33 -1363.63 -284.57 1393.01 191.79 0.37 BP _MWD+IFR+MS 73 6612.36 16.74 164.31 95.07 6318.83 1392.83 -1389.24 -276.59 1416.51 191.26 1.22 BP _MWD+IFR+MS 74 6708.89 16.01 165.12 96.53 6411.45 1418.98 -1415.49 -269.41 1440.90 190.78 0.79 BP _MWD+IFR+MS 75 6804.09 16.39 162.12 95.20 6502.87 1444.35 -1440.96 -261.92 1464.57 190.30 0.97 BP MWD+IFR+MS 76 6899.36 17.01 157.16 95.27 6594.13 1469.86 -1466.60 -252.38 1488.16 189.76 1.63 BP _MWD+IFR+MS 77 6994.97 15.81 155.91 95.61 6685.84 1494.49 -1491.38 -241.63 1510.83 189.20 1.31 BP _MWD+IFR+MS 78 7091.80 16.21 159.33 96.83 6778.92 1519.04 -1516.07 -231.48 1533.64 188.68 1.06 BP _MWD+IFR+MS 79 7186.52 15.57 162.22 94.72 6870.02 1543.40 -1540.54 -222.93 1556.59 188.23 1.07 BP _MWD+IFR+MS 80 7282.31 16.22 161.93 95.79 6962.14 1568.25 -1565.50 -214.85 1580.18 187.81 0.68 BP _MWD+IFR+MS • 81 7377.80 16.94 160.54 95.49 7053.66 1593.92 -1591.30 -206.08 1604.59 187.38 0.86 BP _MWD+IFR+MS 82 7473.81 17.54 158.02 96.01 7145.36 1620.39 -1617.90 -196.01 1629.73 186.91 1.00 BP _MWD+IFR+MS 83 7569.25 17.44 157.21 95.44 7236.39 1646.76 -1644.42 -185.09 1654.81 186.42 0.28 BP _MWD+IFR+MS 84 7664.90 17.32 157.28 95.65 7327.67 1672.96 -1670.77 -174.03 1679.81 185.95 0.13 BP _MWD+IFR+MS 85 7760.13 17.05 157.03 95.23 7418.65 1698.74 -1696.70 -163.11 1704.52 185.49 0.29 BP MWD+IFR+MS 86 7855.78 16.62 156.65 95.65 7510.20 1724.06 -1722.17 -152.22 1728.88 185.05 0.46 BP _MWD+IFR+MS 87 7951.96 16.14 156.80 96.18 7602.48 1748.83 -1747.09 -141.50 1752.81 184.63 0.50 BP _MWD+IFR+MS 88 8046.98 17.03 159.82 95.02 7693.54 1773.89 -1772.29 -131.50 1777.16 184.24 1.30 BP _MWD+IFR+MS 89 8141.69 16.19 160.74 94.71 7784.30 1799.25 -1797.77 -122.36 1801.93 183.89 0.93 BP _MWD+IFR+MS 90 8237.67 16.82 162.76 95.98 7876.33 1825.03 -1823.66 -113.83 1827.21 183.57 0.89 BP MWD+IFR+MS [(c)2007 IDEAL ID12_OC_09] SCHLUMBERGER Survey Report 11-Sep-2007 13:20:06 Page 5 of 5 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 91 8334.09 15.70 163.48 96.42 7968.89 1850.75 -1849.50 -105.98 1852.53 183.28 1.18 BP _MWD+IFR+MS 92 8428.00 15.01 163.50 93.91 8059.45 1874.50 -1873.34 -98.92 1875.95 183.02 0.73 BP _MWD+IFR+MS 93 8523.53 14.38 164.61 95.53 8151.85 1897.71 -1896.64 -92.25 1898.88 182.78 0.72 BP _MWD+IFR+MS 94 8619.52 13.88 164.19 95.99 8244.94 1920.19 -1919.21 -85.95 1921.13 182.56 0.53 BP _MWD+IFR+MS 95 8714.48 13.33 163.65 94.96 8337.23 1941.57 -1940.67 -79.77 1942.31 182.35 0.59 BP MWD+IFR+MS 96 8810.13 12.68 162.35 95.65 8430.43 1962.07 -1961.26 -73.48 1962.63 182.15 0.75 BP _MWD+IFR+MS 97 8842.06 12.70 161.63 31.93 8461.58 1968.71 -1967.93 -71.31 1969.22 182.08 0.50 BP _MWD+IFR+MS 98 8904.03 12.42 161.77 61.97 8522.06 1981.44 -1980.72 -67.08 1981.86 181.94 0.45 BP _MWD+IFR+MS 99 8978.19 12.86 161.32 74.16 8594.43 1996.77 -1996.11 -61.94 1997.07 181.78 0.61 BP _INC+TREND 100 9043.37 12.54 160.92 65.18 8658.01 2010.26 -2009.67 -57.31 2010.49 181.63 0.51 BP MWD+IFR+MS 101 9138.85 12.32 160.08 95.48 8751.25 2029.54 -2029.04 -50.45 2029.67 181.42 0.30 BP _MWD+IFR+MS 102 9234.50 12.02 160.56 95.65 8844.75 2048.43 -2048.03 -43.66 2048.50 181.22 0.33 BP _MWD+IFR+MS 103 9329.72 11.78 159.29 95.22 8937.93 2066.78 -2066.47 -36.92 2066.80 181.02 0.37 BP _MWD+IFR+MS 104 9425.76 11.06 160.36 96.04 9032.07 2084.54 -2084.32 -30.36 2084.54 180.83 0.78 BP _MWD+IFR+MS 105 9455.11 10.91 160.85 29.35 9060.88 2089.79 -2089.59 -28.50 2089.79 180.78 0.60 BP MWD+IFR+MS 106 9505.00 10.91 160.85 49.89 9109.87 2098.67 -2098.51 -25.40 2098.67 180.69 0.00 Projected to TD [(c)2007 IDEAL ID12_OC_09] LJ • Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Christine Mahnken (AOGCC) Well No N-27 Date Dispatched: 17/9/2007 Installation/Rig Nabors 7ES Dispatched By: Franklin Medina LWD Log Delivery V1.1, 10-02-03 Data No Of Prints No of Floppies Surveys 2 1 ' Please sign and return to:.lames H. Johnson Received By: (` BP Exploration (Alaska) Inc. ~~ Petrotechnical Data Center (LR2-1) 900 E. Benson Blvd. Anchorage, Alaska 99508 Fax:907-564-4005 e-mail address: johnsojhC~3bp.com ~~~~~o~ Permit to Drill No. 20?-104 (N~) ~ Page 1 ofF~ ~~~ Maunder, Thomas E (DOA) From: Rose, John G (FAIRWEATHER) [John.G.Rose@bp.comj Sent: Tuesday, August 28, 2007 12:50 PM To: Maunder, Thomas E (DOA) Subject: RE: N-27i (Permit No. 207-104) Flow-Paddle Variance The Wellsite leader on 7ES will advise your North Slope inspec#or when the flow-paddle has been re-installed on this well (at some point below the base of the gravel on the surface hole where flow-line plugging issues are no longer of major concern) and we will follow the good drilling practices as outlined below to confirm the status of the well at all time in terms of well "flow". Thanks for your help. - JR John G. Rose BP-Alaska Drilling Group Office 907/564-5271 Cell 907/748-5223 Fax 907!564-4040 From: Maunder, Thomas E (DOA) [mailtoaom.maunder@alaska.gov] Sent: Tuesday, August 28, 2007 10:53 AM To: Rose, John G (FAIRWEATHER) Subject: RE: N-27i (Permit No. 207-104) Flow-Paddle Variance John, With the proximity of N pad to the Kuparuk River, it is likely not surprising that gravel could be drilled deeper. Having the paddle removed below 1000' is acceptable but the mitigation (PVT and observations) steps planned need to be performed. Call or message with any questionsJcomments. Tom Maunder, PE AOGCC From: Rose, John G (FAIRWEATHER) {mailto:John.G.Rose@bp.com] Sent: Tuesday, August 28, 2007 10:33 AM To: Maunder, Thomas E (DOA) Subject: N-27i (Permit No. 207-104) Flow-Paddle Variance Tom, The reality of the N-27i spud at Prudhoe (we should spud early tomorrow (8/29/07) on Nabors 7ES), is that we could be drilling significant gravels with high viscosity spud down to near the base of the permafrost at 2058' MD {1982' TVD). Therefore, can we leave it to the Wellsite drilling team to re-install the flow-paddle at a surface hole depth where the potential for flow-line plugging has minimized as opposed to the 1000' depth as referenced below? Thanks for your consideration. - JR John ~. Rose BP-Alaska Drilling Group Office 907/564-5271 CeR 907!748-5223 Fax 907/564-4040 8/28/2007 Permit to Drill No. 207-104 (N~ i} ~ Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, August 14, 2007 9:04 AM To: 'Rose, John G (FAIRWEATHER}' Cc: Hobbs, Greg S (ANC) Subject: RE: Permit to Drill No. 2-1~Oq-(11~27i) John, I have seen this request in grass roots wells drilled on the western pads. What you propose has been determined acceptable on those pads. Our standard approval has been that removing the paddle is acceptable while drilling shallower than 1000'. I will place a copy of this message in the well file. A copy should be available at the rig. Call or message with any questions. Tom Maunder, PE AOGCC From: Rose, John G (FAIRWEATHER) [mailto:John.G.Rose@bp.com~ Sent: Tuesday, August i4, 2007 8:54 AM To: Maunder, Thomas E (DOA) Cc: Hobbs, Greg 5 (ANC) Subject: Permit to Drill No. 207-104 (N-27i) Tom, As the N-27i welt will include drilling through the surface hole gravels with a high viscosity spud mud, t forgot to include a "Variance Request" tv remove the "flow-paddle" from the flow-line during our surface hold drilling operations. This "Variance Request" (as indicated below) has been a standard part of our recent Permit to Drill applications for new wells and I would appreciate it if you could approve this variance request for the N-27i well If you have any questions or concerns, please advise. Thanks - JR Variance Request To avoid the risk of plugging the flow line with large rocks and wood encountered white drilling surface hole, it is requested to drill without a flow paddle for the first portion of the surface hole. After drilling past the Larger rocks and wood sections, the flow paddle will be put back in the flow line. To mitigate any risk involved with no flow paddle, the following steps will be taken while the flow paddle is removed from the flow line. Ensure PVT alarms are used and the pit Levels are accurately monitored for any pit gain. Visually look down the riser during connections to ensure the well is not flowing. John G. Rose BP-Alaska Drilling Group Office 907/564-5271 Ce11 90 7/74 8-5223 Fax 907/564-4040 8/14/2007 i Maunder, Thomas E (DOA) From: Rose, John G (FAIRWEATHER) [John.G.Rose@bp.com] Sent: Monday, August 06, 2007 4:57 PM To: Maunder, Thomas E (DOA) Subject: RE: N-27-again Attachments; N-27 (P6) 1320 ft radius.pdf Tom, Page 1 of ~. In regards proximity of near-by wells, the attached plot details the wells which are within 1/4 mile radius at the top of the reservoir with the TVD "tick" marks on the wells being from the top of the reservoir to TD. N-16 falls within the 1/4 mile radius with N-O1 and N-09being the next closest, but outside the radius. Wells 11, 12 and 22 are well outside the radius. As for the cementing issue as discussed earlier today, please note the following: 9-5/8" cement job: Tail = 48 bbls of 15.8 ppg G (232 sxs) -1.17 cf/sxs Lead = 566 bb{s of 10.7 ppg Arctic Set Lite (713 sxs) - 4.44 cf/sxs 7" cement job: The yield for the 12.0 ppg Lead slurry should read 1.61 cf/sack. 4-1/2" cement job: The TOC on page #5 of the well summary should read 8790' MD which is the top of the liner at 150' into the 7" casing. If you need any additional data, please advise. Thanks - jr John G. Rose BP-Alaska Drilling Group Office 907/564-5271 Gell 907!748-5223 Fax 907/564-4040 From: er, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, Au 2007 3:22 PM To: Rose, )ohn G (FAIRWE / Subject: RE: N-27--again John, Thanks for calling back. Could you al a plot/scan of the 1I4 miler ~ r the N-27 penetration into the reservoir (basically the 7" casin e). I have not seen the data looked at by my ~ tes over here, but there may be other wells that he 1/4 mile radius in the reservoir. See what you can get an can discuss. Call or message ~ ny questions. Tom Maun E 8/7!2007 • ~ Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, August 06, 2007 3:22 PM To: John Rase Subject: RE: N-27-again John, Thanks for calling back. Could you also get aplot/scan of the 1/4 mile radius for the N-27 penetration into the reservoir (basically the 7" casing shoe). I have not seen the data looked at by my associates over here, but there may be other wells that enter the 1/4 mile radius in the reservoir. See what you can get and the we can discuss. Call or message with any questions. Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA} Sent: Monday, August 06, 2007 11:24 AM To: John Rase Subject: N-27 John, As discussed this morning, I am reviewing this permit application. As part of the review, I examine the cement calculations. Would you please recheck your calculations? Using your basis, I calculate a gross XS in surface hole of 265%, in intermediate hole of 95% and in the liner portion of 109%. The depths given in the cementing section on page 5 for the liner section are not the same as on the 401 sheet. Thanks in advance, 1 took forward to your reply. Tom Maunder, PE AOGCC 8!6/2007 ~ ~ //~~/~/~ I+y O a L CQ ..~i aaa _~ ~~3 w~ q C 8 ~' 3 ~~~n ~+>~~-~~ • d ~ d ~ ~ SARAH PALIN, GOVERNOR oJ4~-7S~ OI~ ~D ~ 333 W. 7th AVENUE, SUITE 100 C011TSERQA7'I011T COMI~IISSIOIIT ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Greg Hobbs Senior Drilling Engineer BP Exploration Alaska Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU N-27i BP Exploration Alaska Inc. Permit No: 207-104 Surface Location: 2285' FSL, 4709' FEL, SEC. 08, T11N, R13E, UM Bottomhole Location: 186' FSL, 4744' FEL, SEC. 08, T11N, T13E, UM Dear Mr. Hobbs: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). DATED this ~ day of August, 2007 cc: Department of Fish & Game, Habitat Section w/o encl. Departrnent of Environmental Conservation w/o encl. STATE OF ALASKA ALAS IL AND GAS CONSERVATION COMMI~N PERMIT TO DRILL 20 AAC 25.005 ~E~EI~/I~C~ L1 JJL 2 3 2007 ~~~ tl'1 a n__ 1 a. Type of work ® Drill ^ Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ®Service ' ^ Multiple Zone ^ Stratigraphic Test ^ Development Oil ^ Single Zone 1 c. Specify if well is propose~d r: ' ^Coalbed Methane ^ d~~C~li~ s ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 ~ 11. Well Name and Number: PBU N-27i 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 9412 %TVD 9017 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: • 2285' FSL ~4709' FEL SEC T11 N 08 R13E UM 7. Property Designation: ADL 028282 Pool , , . , , , Top of Productive Horizon: 307' FSL, 4785' FEL, SEC. 08, T11 N, R13E, UM 8. Land Use Permit: 13. Approximate Spud Date: August 20, 2007 Total Depth: 186' FSL, 4744' FEL, SEC. 08, T11 N, R13E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 26,070' ~' 4b. Location of Well (State Base Plane Coordinates): Surface: x-634413 ~' y-5968189 ~ Zone-ASP4 10. KB Elevation Plan (Height above GL): 71.5 feet 15. Distance to Nearest Well Within Pool: 1,000' 16. Deviated Wells: Kickoff Depth: 500 ~` feet Maximum Hole An le: 24 - de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3751 ! Surface: 2902 ° 18. Casin Pro ram: S ecificatio ns To - Se in De th -Bo ttom uanti of Cement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 42" 20" 91.5# H-40 Weld 108' Surface Surface 108' 108' 260 sx Arctic Set A rox. 12-1/4" 9-5/8" 47# L-80 BTC-M 3230' Surface Surface 3230' • 3077' sx AS Lite sx Class 'G' 8-1/2" 7" 26# L-80 TC-II 4118' Surface Surface 4118' 3929' See Below '1~ ~ 3a s 8-1 /2" 7" 26# L-80 BTC-M 4822' 4118' 3929' 8940' 8560' 476 sx LiteCrete 166 sx Class 'G' ~ 6-1/8" 4-1l2" 12.6# L-80 IBT-M 622' 8790' 8417' 9412'- 9017'- 102 sx Class 'G' 1 g, PRESE NT WELL CONDITION SUMMARY(To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): Casing ; Length Size Cement Volume MD ' .TVD Conductor /Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth ND (ft): 20. Attachments ^ Filing Fee, $100 ^ BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ® Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact John Rose, 564-5271 Printed Name Greg bb °" Title Senior Drilling Engineer Prepared By Name/Number: Si nature Phone 564-4191 Date t " ~ ~ ~ Terrie Hubble, 564-4628 -Commission Use Onl Permit To Drill ~,/ Number: ~ ~- ~~ 7 API Number: 4 50- ~Z` ~ ~~~5~ Permit A proval See cover letter for Date: ' ? • other re uirements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce Coalbed me~thfane, gas hydrates, or gas contained shales: [']~ M ~~~ Ctc~C~~~ q v ~y,`~~ ~ `,p ~ Samples Req'd: ^ Yes L7 No Mud Log Req'd: ^ Yes [~]'(Vo ~~~ ~••~ ~0~1- HZS Measures: dyes ^ No Dire tional Survey Req'd: []Yes ^ No Other: ~~~~+~c3:~rc OQ~c'c4~~C:~-S i~ GALL' W B APPROVED BY THE COMMISSION Date " ~ ,COMMISSIONER lion Form 10-401 Revised 12!2005 ~ ~ ~ ~ ~ ~ ` ~ ~ ~mitQl~ upli aL~~~ • • To: Tom Maunder, Petroleum Engineer Alaska Oil & Gas Conservation Commission From: John Rose -ODE Date: July 16, 2007 Re: N-27i Permit to Drill Approval is requested for the drilling of the N-27i grassroots pre-produced Zone 4 Ivishak injector. For the planned drilling of this well, non-insulated 20" conductor casing has been set and cemented at ~80' at the N-27I surface location. From there, the basic drilling plan will include a 12-~/a" surface hole to 3230' MD (SV3) where 9-5/8" surface casing will be run and /cemented to surface. An 8-1/2" intermediate hole will then be drilled from the SV3 to the top of the Sag River formation where a 7", 26.0# intermediate casing string will run and cemented with the proposed cement top to be above the SV 1 to protect the intermediate casing from future leaks due to the injection into the Tertiary formations. A 6-'/s" production interval will then be drilled through Zones 4, 3 and 2 with the conventional well path will be TD once -200'md has been drilled below the POWC. A 4-t/z", 12.6#, L-80 solid liner will be run and fully cemented. The planned completion is 4-t/z", 12.6#, 13Cr-80, VAM TOP tubing, four gas lift mandrels and an S-3 permanent packer. As this well is a planned Ivishak injector, the Area of Review (AOR) reveals a single well (N- 16) within the t/a" mile radius of this well and the details of the isolation/cementing work on that well are indicated below: Casing/Liner 9-5/8" Intermediate Casing T' Production Liner Date Cemented 03/31/83 04/04/83 Setting Depth (MD) 9686' 10,525' Cementing Stages 2 1 Is` Stage Volume 880 sxs 320 sxs Calculate Volume Length (ft) 5362' 3037' Bumped Plug / No Losses yes yes 2"a Stage Volume hRct.~<Pv.4, 140 sxs (DV Collar @2602' MD) na The N-27i well is currently scheduled for Nabors 27E beginning --08/20/07. Please refer to the additional data within this request for specific well details and do not hesitate to call if I additional information is required. John Rose -ODE Office - 564-5271 Cell - 748-5223 N-27i Well Page 1 • Well Name: N-27i • Drill and Complete Plan Summary Type of Well service /producer /injector}: Pre-Produced Zone 4 Injector Target X Y Z TVDss Township Range Section FSL FEL Surface As-built 634413 5968190 ~ 0 11 N ~' 13E 8 2286 ~ 4709 " TSAD 634379 5966210 8475 11N 13E 8 307 4785 BHL 634422 5966090 8950 11N 13E 8 186 4744 AFE Number: PBD 4P2521 API t~urr: Estimated Start Date: 8/20/07 Operating days: 19 Rig: Nabors 7ES TMD 9412' - TVD rkb: 901 T ~ RKB/GL 28.5'/43' r,. RTE 71.5' Well Design: USH Pre-Produced Zone 4 Injector ,~-' 4-Y2" 13-Cr Vam To com letion Current Status: New drill General Well Information: Estimated BHP: 3160 psi at 8603' TVDss '~ Estimated BHT: 225 deg F at 8800' TVDss N-27i Well Page 2 • • Formation Markers: Est. Formation To s Uncertainty Conantercial Hydrocarhon Bearin ~ Est. Pore Press. Est. Pore Press. FOY/ilClhOll (TVDss) (%eet) (Yes/No) (Psi) (ppg EMW) NOTE: All formation tops are required from 1000' above proposed KOP to TD for sidetracks NOTE: All formation to s are re wired from surface to TD for all new wells Base U er GraveUGubic 380 20 Base GubidSV6 1660 20 Base Permafrost 1910* 20 SVS 2251 20 SV4 2462 20 SV3 2885 20 SV2 3019 20 SV1 3383 20 UG4 3725 20 UG3 4019 20 UG1 4563 20 WS2 5045 20 WS1 5235 20 CM3 5442 20 CM2 6310 20 CM1 6443 20 THRZ 6722 20 BHRZ 6949 20 To Kin ak 7253 20 TJF 7607 20 TJE 7756 20 TJD 7966 20 TJC 8208 20 TJB 8341 20 Sa River 8490 20 Yes Shublik 8524 20 Yes TSAD / TZ4B 8603 20 Yes 3160 psi @ 8800 PGOC 8687 20 TZ4A/42N 8697 20 Yes POWC 8730 20 TCGL / TZ3 8756 20 Possible BCGLlTZ2 8850 Possible MHO/HOT 8958 below TD 10 Yes 25N / T2B 8962 below TD 30 Possible TZ1 B 91 12 below TD 30 No * er ad data sheet and N-Ot Casing/Tubing Program: Hole Size Csg/ Tbg O.D. Wt/Ft Grade Connection Length (ft) Top MD/TVD RTE ft) Btm MD/TVD RTE (ft) 42" 20" non- insulatded 91.5 H-40 .438" ID WLD 108 GL 108/108 12-~/a" 9-5/8" 47 L-80 BTC-M 3230 GL 3230/3077 8-1/2" 7" 26 L-80 TC-II 4118 GL 4118/3929 8-1/2" 7" 26 L-80 BTC-M 4822 4118/3929 8940/8560 6-'/8' 4-'h" 12.6 L-80 IBT-M 622 8790/8417 9412/9017 Tubin 4-'/z" 12.6 13-Cr VT 8840 GL 8795/8421 Directional: Directional Plan: Schlumber er Feasibilit Stud P5 Ref Elev: 71.5' MD KOP: 500' MD, be in 1.5/100 build ~' Close A roach Wells: All Wells ass Ma~or Risk Scan, reference P5 anti-collision re ort Surve Pro ram: MWD-Standard 1400' ,MWD + IFR + MS 9411' Maximum Hole An le: 24 de rees at 1494' MD ' Distance to Nearest Pro ert 26,070' , N-27i Well Page 3 • • Line: Distance to Nearest Well in Pool: 1000' f/N-16 at top of reservoir Mud Program: 12-'/0" Surface Hole Mud Properties Spud -Freshwater Mud Interval Density PV YP PH Funn Vis FL 0-2052' BPRF) 8.8-9.2 30-55 50 - 70 9.0 - 9.5 300-400 NC - 8 2052'-3230' SV3 9.2-9.6 30-55 45 - 60 9.0 - 9.5 250-300 < 8.0 8-3/4" Intermediate Hole Mud Pro erties Freshwater Mud (LSND} Interval Density PV YP PH API Filtrate MBT 3230'-7100' THRZ 8.8-9.2 8-14 18-24 9.0-9.5 4 - 7 < 15 7100'-8938' TSAG 10.1 / 12-20 18-24 9.0-9.5 HTHP < 10 < 20 6-'/8" Production Hole Mud Properties FloPro-SF Interval Density PV YP PH API Filtrate MBT 8938'-9412' Final Well TD 8.4-8.6 8-12 22-28 8.5-9.0 < 10 <3 Survey and Loaaina Program: 12-'/a" Hole Section: Surface Gyro until MWD surveys are clean. . MWD /LWD: Dir/GR Open Hole: None Cased hole: None 8-3/4"Hole Section: / MWD/LWD:. DIR/GR/RES/PWD real time Open Hole: None Cased Hole: None required 6-'/e" Hole Section: Sample as required by well site Geologist MWD /LWD: DIR/GR/RES/NUE/DEN ~- Open Hole: None Cased. Hole: USIT (Run log after setting 4-1/2" liner. If <50' good cement above top Ivishak, log 7" drillin liner as well. Cement Calculations: Casin Size Surface Casing - 9 5/8" 40 Ib/ft L-80 BTC -Single Stage Basis Lead: Open hole volume + 250% excess in permafrost and 40% excess below permafrost. TOC at surface. Tail: Open hole volume + 40% excess + 80' shoe track. TOC 500' TVD above shoe to 2700' MD. Fluid Sequence and Tam Port collar located at 1,000' as a contingency for cement to surface Volume: SS~Cc ~th~.y `1 ~, ~~ S~ ~tcrx cJ a33-s~ ~-c~~~ ~~\~~~ Wash None 3 acer 100 bbls of MudPush II wei hted to 10.0 Lead 618 bbls sks) 10.7 Ib/gal Arctic Set Lite cement - 4.44 cuft/sk (NOTE: To minimize surface casing corrosion, considering the use of a 10.7 ppg Dee CRETE slur to re lace the ASL as the lead slurr for this cement 'ob Tail 48 bbls sksl 15.8 Ibfaal Class G - 1.15 cuft/sk Temp I BHST ~ 80° F from SOR, BHCT ~70° F Casing Size Intermediate Casing - 7" 26 Ib/ft L-80 BTC-M x TC-II -Single Stage Basis Lead: Open hole volume + 30% excess. TOC at top SV1 at 3618' MD. Tail: O en hole volume + 30% excess + 80' shoe track. TOC 1000' above 7" shoe. N-27i Well Page 4 • • Fluid Sequence and Volume: None Wash None S acer 70 bbl of MUDPUSH XL S acer wei hted to 10.5-Ib/ al Lead 136 bbl 476 sks 12.0 LiteCRETE + Latex - 2.36 cuft/sk Tail 35 bbl 166 sks 15.8 Class G cement + Latex - 1.16 cuft/sk Temp BHST = 175° F BHCT = 100° F Casing Size Production Liner - 4-'/2" 12.6 Ib/ft L-80 IBT-M -Single Stage Basis Lead: Open hole volume + 30% excess + 150' of liner lap + 80' shoe track + 200' of 7" x 4" DP annulus volume. TOC at liner top (~ MD) t Fluid Sequence and Wash None Volume: 3 acer 20 bbls of Mud ush II Wei hted to 11 Tail 21 bbls (102 sks) 15.8 Ib/gal Class G Cement + Silica + Latex - 1.2 cuft/sk Temp BHST ~ 235° F from SOR, BHCT 160° F estimated by Dowell Surface and Anti-Collision Issues: • With the N-15 & N-26 wells being 200' & 35' respectively, no surface shut-in's will be required to move onto this well. • Close Approach Shut-in Wells: All wells have passed the major risk scan. No wells will require sub-surface shut-in during drilling operations. Reference the Anti-collision report in the directional plan for a full list of offset well paths. N-27i Well Page 5 Well Control Surface hole will be drilled with a diverter. The intermediate and production hole sections will be drilled with well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer. This equipment is capable of handling maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 4,000 psi. Due to anticipated surface pressures exceeding 3,OOOpsi it will be necessary to have two sets of pipe rams installed at all times. Diverter, BOPS and drilling fluid system schematics on file with the AOGCC. Surface Section • BOPE: • Maximum anticipated BHP: • Maximum surface pressure: • Planned BOP test pressure: • 9-5/8" Casing Test: • Kick Tolerance: Hydril GK, 21-1/4", 2000 psi 1340 psi - SV3 (8.5 ppg EMW @ 3010' TVDss) 1039 psi -Based on a full column of gas @ 0.10 psi/ft Function Test 3500 psi surface pressure test NA Intermediate Section Kick Tolerance and Integrity Testing ,~ • BOPE: Hydril, 13-5/8", 5000 psi • Maximum anticipated BHP: 3751 psi -Top Sag River (8.5 ppg EMW @ 8487' TVDss) • Maximum surface pressure: 2902 psi -Based on a full column of gas @ 0.10 psi/ft ~° • Planned BOP test pressure: 4000 psi/250 psi Rams and 2500 psi/250 psi Annular • 7" Casing Test: 4000 psi surface pressure test • Integrity Test - 8-1/2" hole: LOT 20' - 50' from 9 5/8" shoe • Kick Tolerance: 38 bbl KT with a 10.1 ppg mud and a 10.8 ppg FIT/LOT Production Section Kick Tolerance and Integrity Testin • BOPE: Hydril, 13-5/8", 5000 psi • Maximum anticipated BHP: 3160 psi - Ivishak 42P (7.0 ppg @ 8800' TVDss) • Maximum surface pressure: 2280 psi -Based on a full column of gas @ 0.10 psi/ft • Planned BOP test pressure: 4000 psi/250 psi Rams and 2500 psi/250 psi Annular • 4'/2" Casing Test: 4000 psi surface pressure test • Integrity Test - 6-'/e" hole: FIT 20' - 50' from 7" shoe • Kick Tolerance: Calculated an Infinite KT with a 8.5 ppg mud with 8.8 ppg FIT/LOT • Planned completion fluid: Estimated 8.9 ppg Brine / 6.8 ppg Diesel Disposal • No annular disposal in this well. 1 • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject v,: at DS-04. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for disposal. Haul all Class I wastes to Pad 3 for disposal. N-27i Well Page 6 Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE Well Control /Reservoir Pressure Normal pore pressures (8.5 ppg) are expected throughout surface hole drilling operations. Normal pore pressures (8.5 ppg) are also expected throughout the intermediate hole drilling operations, ,; although, Cretaceous injection pressures up to 9.0 ppg may be encountered. The Ivishak is expected to be pressured at 7.0 ppg EMW. ~ -' II. Hydrates and Shallow gas: No gas hydrates or shallow gas is anticipated, however, follow good drilling practices in the regards at all times. III. Lost Circulation /Breathing: Lost circulation on the surface hole cement jobs has been a problem on this pad. Well breathing problems are a possibility in the intermediate hole after weighting-up the mud to 10.1 ppg for the HRZ. Lost circulation in the reservoir section is considered low. Follow the RP guidelines for dealing with it if it occurs. IV. Kick Tolerance /Integrity Testing: Intermediate Section Kick Tolerance and Integrity Testing • Integrity Test - 8-1 /2" hole: LOT 20' - 50' from 9-S/8" shoe • Kick Tolerance: Calculated an Infinite KT with a 8.5 ppg mud with 8.8 ppg FIT/LOT Production Section Kick Tolerance and Integrity Testing • Integrity Test - 6-'/8" hole: FIT 20' - 50' from 7" shoe • Kick Tolerance: Calculated an Infinite KT with a 8.5 ppg mud with 8.8 ppg FIT/LOT V. Stuck Pipe There will be slight differential sticking tendencies across upper sands in the intermediate hole with the planned 10.1 ppg mud weight in the hole. Keep the pipe moving and follow good "practices" while drilling and running the 7" casing in this interval of the well. VI. Hydrogen Sulfide N-Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times as H2S levels greater than 100 ppm have been recorded on N-15 (09/00) and N-26 (01/02). VII. Faults The well plan does not intersect any mapped faults near target level. Seismic reflections in the shallower levels show relatively calm signature with no indication of shallow gas. The nearest significant Lost Circulation incident was --1400 ft N in well N-01 which lost 285 bbls above the Sag. This was probably associated with a large down to the N fault directly beneath N pad. There is a cluster of LC incidents about 3000 ft S ,and another cluster about one mile west, both of which are associated with locally complex fault zones. CONSULT THE N-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION N-27i Well Page 7 ~ i N-27 Drill and Complete Procedure Summary Pre-Rig Operations: 1. Install 20" conductor casing. 2. Weld an FMC landing ring, for the FMC Gen 5/5A wellhead, on the conductor. 3. If necessary, level the pad and prepare location for rig move. Rig Operations: .~--~i 1. MI/RU Nabors 7ES. ` ' ~`~~~~~ ~~~~"~~ 2. Nipple up the diverter spool and riser. P/U sufficient length of 4" drill pipe and stand back in the derrick. 3. M/U a 12-'/4" drilling assembly with Dir/GR. Spud and directionally drill surface hole to the base of the permafrost. Gyro data will be required until clean surveys can be taken. Circulate and condition hole. Trip for a new bit if necessary. 4. RIH and drill the remainder of the surface hole to approximately 120' tvd below the SV3 sand. This will put the surface casing point just below 3,000' TVDSS. Circulate and condition hole. POOH and UD BHA. 5. R/U, run, and cement the 9 5/8", 47# casing back to surface. A TAM port collar may be run as a contingency if hole conditions indicate a problematic primary cement job. (NOTE: Efforts to ensure the final TOC is within 3' of surface will be required.) Co~~t~-'=,~~~~-~~- ~;~~~ ~,~,~ei^~ 6. N/D the riser spool and N/U the FMC casing head and tubing spool ~~S ~~ ~c~C~S,vr~CsC4 7. N/U the BOPE and test to 4,000 psi. 8. MU 6-3/a" MWD/LWD °drilling assembly w/ corrosion rings and RIH. Pick up 4" drill pipe as necessary. This hole section has build/turn DLS of 3°/100 ft and should be drillable with a 1.15° bend motor. 9. Test the 9 5/8' casing to 3500 psi for 30 minutes. Record the test. 10. Drill out cement, float equipment, and the shoe. Displace the well to 8.8 ppg LSND drilling fluid. 11. Drill approximately 20' new formation and perform the planed FIT. A minimum of 11.1 ppg FIT is needed to satisfy kick tolerance requirements while an FIT of 11.2 ppg is needed to satisfy ECD management needs. 12. Drill ahead, according to directional proposal, to 100' above the HRZ. 13. Increase mud weight, via spike fluid, to 10.1 ppg. 14. Drill according to directional plan to intermediate TD, approximately 5' and below the top of the Sag. Circulate bottoms up as necessary for sample collection to properly identify shale/siltstone cap. 15. Condition hole as necessary and POOH. 16. R/U, run, and cement the 7", 26# intermediate casing. 17. Install casing pack-off and test per FMC representative. 18. Freeze-protect the 9 5/8" x 7" annulus, once the cement has reached 500 psi compressive strength. Confirm that the OA is open. Ensure that the mud/diesel/brine in the OA is overbalanced to formation at the 9 5/8" shoe (~9.0 ppg). 19. M/U a 6-'/8" MWD/LWD drilling assembly. RIH, P/U additional 4" drill pipe as required. 20. Pressure test the 7" casing to 4,000 psi for 30 minutes. Record the test. 21. Displace the well to 8.5-8.6 ppg Flo-Pro SF fluid. 22. Drill out shoe and 20' of new formation and perform the planned FIT. A minimum FIT of 8.8 ppg is required to satisfy kick tolerance requirements while an FIT to 10.6 ppg is required to satisfy the ECD management needs. 23. Drill ahead, per directional proposal and rig site geologist, to well TD at approximately 9,412' MD. 24. Condition the hole as required in preparation of running and cementing the 4-~h" production liner. Spot liner running pill on bottom. POOH, UD excess 4" drill pipe, and UD BHA. 25. R/U and run the 4 Yz", 12.6#, L-80, IBT liner. CBU at 7" shoe and TD as necessary. Cement the liner per Dowell program. Release from the liner and set the packer. Circulate excess cement to surface. 26. Displace the well to seawater above the liner top. POOH and UD liner running tools. ~ 27. Run USIT in the 4-1/2" production liner and 7" intermediate casing as required to confirm cement bond/isolation. USIT should be run in corrosion mode as well as cement evaluation mode. 28. R/U and pressure test the casing x liner string to 4,000 psi for 30 minutes. Record. the test. 29. R/U and run a 4-Yz", 12.6#, 13Cr-80, Vam Top completion w/ GLM's. Space and land the tubing with the tubing tail inserted into the liner tie back sleeve. RILDS. 30. Reverse circulate filtered seawater and corrosion inhibitor into the tubing x casing annulus. N-27i Well Page 8 • • 31. Drop ball/rod and set packer. 32. Individually test the tubing and annulus to 4,000 psi for 30 minutes. Record each test. 33. Shear DCR valve. 34. Install TW C and test. 35. N/D the BOPE. 36. N/U the adapter flange and tree. Test tree and adapter to 5,000 psi. 37. RU DSM. Pull TWC. 38. R/U circulating lines and test. Freeze-protect the tubing and annulus to 2,000'. Allow the diesel to U-tube to equilibrium. 39. Install a BPV and VR plugs in the annulus valves. 40. Secure, rig down and move off. Post-Rig Operations: 1. MI / RU slick line. Pull the ball and rod / RHC plug from landing nipple below the production packer. 2. E-Line perf well. 3. Install the well house, instrumentation, and flow line. N-27i Well Page 9 KB. ELEV = 82.5' BF. Et:EV = 54' KOP = 500 Max Angle = Datum MD = 24 DEG @ 3213 Datum TVD = Propa~ed Completion Proposed TOC 3,618' • TREE= CM/ 4-1/16 SM WELLHEAD = FMC Gen 5 CSG HEAD = 11" 5M W/ 7" NIANDREL HANGER & PACKOFF TBG SPOOL = 11" X 11" 5M TBG HANGER = 11" X 4-1/2" ADPFLANGE= 11"X4-1/16" ® 20', 91.51b~ft, H401~haJ2ted (x- 2,207' HES 4-1/2 'X' Landing Nipple; ID = 3.813" 3,230' 9-5/8", 47 #/ft, L-80, BTC, ID = 8.681 GAS LIFT MANDRELS Minimum ID = 3.813" @ 2207' 4-1 /2" HES X NIPPLE 4-1/2", 12.6#/ft, 13 Chrome, 8,78 VamTop, ID = 3.958" PERFORATION SUMMARY REF LOG: CAMCO GR/SSL ON 07/12/£ ANGLEATTOPPERF: 45 @ 11250' Note: Refer to ProduStion DB for historiSal pf INTERVAL ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 DMY DMY RK 3 DMY DMY RK 2 DMY DMY RK 1 DCK S/O RK ,720' HES 4-1/2" X NIPPLE; LD. 3.813" ,731' BAKER PKR 7" X 4-1/2" S-3, ID = 3.88", 12' TBS ,756' HES 4-1/2" X NIPPLE; ID = 3.813" ,,777' HES 4-1/2" XN NIPPLE; ID = 3.725" 1788, 7" x 4-1/2" Baker Flex-Loc Liner Hanger (ID =2.992") w/ ZXP Liner Top Pkr w/ 10' TBS (ID = 5.25") 1,938' 7 , 26 #/ft, L-80, BTC-M (f/8938' to 4118' MD) & TC-II (f/4118' to Surf), ID = 6.276" 1,050' 4-1/2", 12.6#, L-80, IBT-M, MARKER JT @ TSAD 1,326' 4-1 /2" PBTD 1,412' 4-1/2", 12.6#, L-80, IBT-M, ID = 3.958", 0.01522 BPF DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/07/06 STG INffIAL WELL: N-27i PERMff No: API No: BP F~cploration (Alaska) N-271 by Schlumberger N-27 (P5) Proposal Client: BP Exploration (Alaska) Field: Prudhoe Bay Unit - WOA Structure 1 Slot: N-PAD / N-27 ~' ~;'; Well: Plan N-27 Borehole: Plan N-27 ~a UWUAPI#: 50029 Survey Name 1 Date: N-27 (P5) /November 29, 2006 Tort f AHD! DDI! ERD r~io: 59.760° / 2551.73 ft 15.20210.283 Gdd Coordinate Syetem: NAD27 Alaska State Planes, Zone 04, US Feel Loc~ion LaflLong: N 70.32103365, W 148.91024368 Location Grid NIE YIX: N 5968189.500 ftUS, E 634412.600 ftUS ~'` Gdd Convergence Angle: +1.02612233° Vertical Section Azimuth: 180.770° V Vertical Section Origin: N 0.000 ft, E 0.000 ft TVD Reference Datum: Rotary Table TVD Reference Elevation: 67.00 ft relative to MSL Sea Bed 1 Ground Level Elevation: 38.50 ft relative to MSL ~ Magnetic Declination: 23.903° Total Field Strength: 57649.982 nT Magnetic Dip: 80.929° Declination Date: March 28, 2007 Magnetic Declination Model: BGGM 2006 North Reference: True North Total Corc Mag North •> True North: +23.903° • Measured Yertlcel Grevdy Comments Inclination Azimuth Sub•Sea TVD TVD NS EW DLS Build Rate Walk Rate Northing Easting Latitude Longitude Depth Section Tool Face it d ft ft ft ft (t de d 100 ft 100 k de 100 ft kUS ftUS rtit u.uu u.uu zou.uu -nr.uu u.uu u.uu u.uu u.uu -- u.w u.uu u.uu oaouirsa.au os~i~.ou rv rusrwssoa w ivu.aiuzvsoa KOP Crv 1.5/100 / 500.00 0.00 250.00 433.00 500.00 0.00 0.00 0.00 HS 0.00 0.00 0.00 5968189.50 634412.60 N 70.32103365 W 148.91024368 Crv 2.5/100 600.00 1.50 250.00 532.99 599.99 0.46 -0.45 -1.23 HS 1.50 1.50 0.00 5968189.03 634411.38 N 70.32103243 W 148.91025365 700.00 4.00 250.00 632.87 699.87 2.17 -2.09 -5.74 HS 2.50 2.50 0.00 5968187.31 634406.90 N 70.32102795 W 148.91029019 800.00 6.50 250.00 732.44 799.44 5.41 -5.22 -14.34 HS 2.50 2.50 0.00 5968184.03 634398.36 N 70.32101940 W 148.91035989 900.00 9.00 250.00 831.52 898.52 10.19 -9.83 -27.01 HS 2.50 2.50 0.00 5968179.19 634385.78 N 70.32100680 W 148.91046260 1000.00 11.50 250.00 929.91 996.91 16.50 -15.92 -43.73 HS 2.50 2.50 0.00 5968172.81 634369.17 N 70.32099017 W 148.91059814 1100.00 14.00 250.00 1027.44 1094.44 24.33 -23.46 -64.46 HS 2.50 2.50 0.00 5968164.89 634348.57 N 70.32096955 W 148.91076624 1200.00 16.50 250.00 1123.91 1190.91 33.65 -32.46 -89.18 HS 2.50 2.50 0.00 5968155.45 634324.02 N 70.32094498 W 148.91096658 1300.00 19.00 250.00 1219.14 1286.14 44.46 -42.88 -117.82 HS 2.50 2.50 0.00 5968144.52 634295.57 N 70.32091649 W 148.91119879 1400.00 21.50 250.00 1312.95 1379.95 56.74 -54.72 -150.35 HS 2.50 2.50 0.00 5968132.10 634263.27 N 70.32088415 W 148.91146242 End Crv 1494.35 23.86 250.00 1400.00 1467.00 69.64 -07.16 -184.53 -- 2.50 2.50 0.00 5968119.05 634229.32 N 70.32085016 W 148.91173 Base Perm 2052.00 23.86 250.00 1910.00 1977.00 149.62 -144.31 -396.49 -- 0.00 0.00 0.00 5968038.13 634018.79 N 70.32063938 W 148.91345 Crv 3/100 2073.87 23.86 250.00 1930.00 1997.00 152.76 -147.33 -404.80 119.78E 0.00 0.00 0.00 5968034.95 634010.54 N 70.32063112 W 148.913525 2100.00 23.48 248.29 1953.93 2020.93 156.63 -151.07 -414.60 118.22E 3.00 -1.45 -6.54 5968031.05 634000.81 N 70.32062092 W 148.91360449 2200.00 22.21 241.28 2046.10 2113.10 173.55 -167.52 -449.69 111.76E 3.00 -1.27 -7.01 5968013.97 633966.02 N 70.32057597 W 148.91388894 2300.00 21.27 233.58 2139.01 2206.01 193.82 -187.37 -480.87 104.60E 3.00 -0.94 -7.70 5967993.56 633935.20 N 70.32052173 W 148.91414167 2400.00 20.71 225.35 2232.39 2299.39 217.38 -210.57 -508.05 96.92E 3.00 -0.56 -8.23 5967969.88 633908.44 N 70.32045834 W 148.91436200 SV5 2419.89 20.65 223.67 2251.00 2318.00 222.45 -215.58 -512.97 95.34E 3.00 -0.32 -8.45 5967964.79 633903.61 N 70.32044466 W 148.91440190 2500.00 20.56 216.84 2326.00 2393.00 244.17 -237.05 -531.16 88.95E 3.00 -0.11 -8.52 5967942.99 633885.81 N 70.32038599 W 148.91454932 2600.00 20.82 208.37 2419.58 2486.58 274.11 -266.75 -550.14 81.03E 3.00 0.26 -8.47 5967912.97 633867.37 N 70.32030487 W 148.91470312 SV4 2645.42 21.07 204.63 2462.00 2529.00 288.74 -281.27 -557.38 77.53E 3.00 0.56 -8.25 5967898.32 633860.39 N 70.32026519 W 148.91476179 2700.00 21.48 200.26 2512.86 2579.86 307.13 -299.57 -564.93 73.46E 3.00 0.75 -8.01 5967879.89 633853.17 N 70.32021520 W 148.91482298 We1lDesign Ver SP 2.1 Bld( doc40x_100) N-271PIan N-27\Plan N-27\N-27 (P5) Generated 11/29/2006 11:23 AM Page 1 of 2 Conte Measured Inclination Azimuth Subsea TVD TVD Vertical NS EW lirevfty DLS Build Rate Walk Rate Northing Eaeting LaWude LongiWde Depth Section Tool Face k d d k ft ft ft ft d de 100 ft d 100 ft de 100 ft ftUS ftUS Z23UU.UU ZY.OI 12iZ./3 ZbUO.bU Zb/Z.bU 343.13 -330.43 -0/0.4`3 bb.4/L 3.UU 1.V3 -/.03 OJO/043.60 OJ384J.Lb n /V.JLUI IIL4 YV 140.~14yU8b/ Crv 3/100 2838.77 23.00 190.00 2641.35 2708.35 357.87 -350.13 -578.44 136.94E 3.00 1.26 -7.04 5967829.10 633840.57 N 70.32007708 W 148.91493248 2900.00 21.69 186.61 2697.98 2764.98 380.93 -373.15 -581.82 133.81 L 3.00 -2.14 -5.54 5967806.02 633837.60 N 70.32001418 W 148.91495986 3000.00 19.73 180.18 2791.53 2858.53 416.20 -408.39 -584.00 127.79E 3.00 -1.96 -6.42 5967770.75 633836.06 N 70.31991789 W 148.91497751 SV3 3098.78 18.06 172.61 2885.00 2952.00 448.04 -440.26 -582.08 120.63E 3.00 -1.69 -7.67 5967738.93 633838.54 N 70.31983084 W 148.91496194 3100.00 18.04 172.51 2886.16 2953.16 448.41 -440.63 -582.03 120.53E 3.00 -1.53 -8.34 5967738.55 633838.60 N 70.31982982 W 148.91496155 3200.00 16.71 163.49 2981.61 3048.61 477.47 -469.77 -575.92 111.92E 3.00 -1.33 -9.02 5967709.53 633845.23 N 70.31975021 W 148.91491203 End Crv 3221.08 16.48 161.42 3001.81 3068.81 483.19 -475.52 -574.11 --- 3.00 -1.07 -9.81 5967703.82 633847.14 N 70.31973452 W 148.91489732 9-5/8" Csg Pt 3229.62 16.48 161.42 3010.00 3077.00 485.47 -477.81 -573.34 -- 0.00 0.00 0.00 5967701.54 633847.96 N 70.31972825 W 148.91489105 SV2 3239.01 16.48 161.42 3019.00 3086.00 487.99 -480.34 -572.49 -- 0.00 0.00 0.00 5967699.03 633848.85 N 70.31972135 W 148.91488417 SV1 3618.61 16.48 161.42 3383.00 3450.00 589.62 -582.44 -538.17 - 0.00 0.00 0.00 5967597.56 633884.99 N 70.31944242 W 148.9146 UG4 3975.27 16.48 161.42 3725.00 3792.00 685.11 -678.37 -505.92 -- 0.00 0.00 0.00 5967502.23 633918.95 0 N 70.31918035 W 148.91434 UG3 4281.87 16.48 161.42 4019.00 4086.00 767.20 -760.84 -478.20 -- 0.00 0.00 0.00 5967420.28 633948.14 N 70.31895506 W 148.91411971 UG1 4856.49 16.48 161.42 4570.00 4637.00 921.04 -915.40 -426.24 -- 0.00 0.00 0.00 5967266.69 634002.85 N 70.31853283 W 148.91369851 WS2 5359.16 16.48 161.42 5052.00 5119.00 1055.62 -1050.60 -380.79 -- 0.00 0.00 0.00 5967132.34 634050.71 N 70.31816348 W 148.91333007 WS1 5562.52 16.48 161.42 5247.00 5314.00 1110.07 -1105.30 -362.40 -- 0.00 0.00 0.00 5967077.98 634070.07 N 70.31801405 W 148.91318102 CM3 5783.60 16.48 161.42 5459.00 5526.00 1169.26 -1164.76 -342.41 --- 0.00 0.00 0.00 5967018.89 634091.13 N 70.31785159 W 148.91301898 CM2 6682.55 16.48 161.42 6321.00 6388.00 1409.94 -1406.56 -261.13 --- 0.00 0.00 0.00 5966778.61 634176.72 N 70.31719105 W 148.91236012 CM1 6789.97 16.48 161.42 6424.00 6491.00 1438.70 -1435.45 -251.42 -- 0.00 0.00 0.00 5966749.90 634186.94 N 70.31711212 W 148.91228140 THRZ 7099.70 16.48 161.42 6721.00 6788.00 1521.62 -1518.76 -223.42 -- 0.00 0.00 0.00 5966667.11 634216.43 N 70.31688452 W 148.91205440 BHRZ 7337.48 16.48 161.42 6949.00 7016.00 1585.28 -1582.71 -201.92 -- 0.00 0.00 0.00 5966603.56 634239.07 N 70.31670981 W 148.91188015 Drp 2/100 7637.27 16.48 161.42 7236.47 7303.47 1665.55 -1663.35 -174.81 LS 0.00 0.00 0.00 5966523.43 634267.62 N 70.31648952 W 148.91166045 7700.00 15.23 161.42 7296.81 7363.81 1681.72 -1679.59 -169.35 LS 2.00 -2.00 0.00 5966507.28 634273.37 N 70.31644513 W 148.91161618 End Drp 7711.51 15.00 161.42 7307.93 7374.93 1684.55 -1682.44 -168.39 -- 2.00 -2.00 0.00 5966504.45 634274.37 N 70.31643736 W 148.91160843 TJF 7985.94 15.00 161.42 7573.00 7640.00 1751.57 -1749.76 -145.76 -- 0.00 0.00 0.00 5966437.55 634298.20 N 70.31625344 W 148.91142500 TJE 8147.44 15.00 161.42 7729.00 7796.00 1791.00 -1789.39 -132.44 --- 0.00 0.00 0.00 5966398.18 634312.23 N 70.31614519 W 148.91131706 TJD 8372.09 15.00 161.42 7946.00 8013.00 1845.86 -1844.50 -113.92 -- 0.00 0.00 0.00 5966343.41 634331.74 N 70.31599463 W 148.91116690 TJC 8635.05 15.00 161.42 8200.00 8267.00 1910.08 -1909.01 -92.23 -- 0.00 0.00 0.00 5966279.30 634354.57 N 70.31581839 W 148.91099115 TJB 8777.92 15.00 161.42 8338.00 8405.00 1944.97 -1944.06 -80.45 -- 0.00 0.00 0.00 5966244.47 634366.98 N 70.31572263 W 148.91089566 Target Start 8919.76 15.00 161.42 8475.00 8542.00 1979.60 -1978.86 -68.75 -- 0.00 0.00 0.00 5966209.89 634379.30 N 70.31562758 W 148.91080 TSAG 8932.18 15.00 161.42 8487.00 8554.00 1982.64 -1981.91 -67.73 -- 0.00 0.00 0.00 5966206.86 634380.38 N 70.31561925 W 148.9107 7"Csg Pt 8938.39 15.00 161.42 8493.00 8560.00 1984.15 -1983.43 -67.22 -- 0.00 0.00 0.00 5966205.35 634380.92 N 70.31561509 W 148.910788 TSHU 8967.38 15.00 161.42 8521.00 8588.00 1991.23 -1990.54 -64.83 -- 0.00 0.00 0.00 5966198.28 634383.43 N 70.31559566 W 148.91076904 TSAD / Z48 9050.20 15.00 161.42 8601.00 8668.00 2011.46 -2010.86 -58.00 -- 0.00 0.00 0.00 5966178.09 634390.63 N 70.31554015 W 148.91071368 PGOC 9139.23 15.00 161.42 8687.00 8754.00 2033.20 -2032.70 -50.65 -- 0.00 0.00 0.00 5966156.38 634398.36 N 70.31548048 W 148.91065418 TZ4A/42N 9148.55 15.00 161.42 8696.00 8763.00 2035.47 -2034.99 -49.89 -- 0.00 0.00 0.00 5966154.11 634399.17 N70.31547423 W148.91064795 PO WC 9183.75 15.00 161.42 8730.00 8797.00 2044:07 -2043.62 -46.98 --- 0.00 0.00 0.00 5966145.53 634402.22 N 70.31545064 W 148.91062443 TCGL / TZ3 9209.63 15.00 161.42 8755.00 8822.00 2050.39 -2049.97 -44.85 -- 0.00 0.00 0.00 5966139.22 634404.47 N 70.31543329 W 148.91060713 BCGL / 7Z2 9280.03 15.00 161.42 8823.00 8890.00 2067.58 -2067.24 -39.04 --- 0.00 0.00 0.00 5966122.06 634410.58 N 70.31538611 W 148.91056008 25N / T28 9358.71 15.00 161.42 8899.00 8966.00 2086.80. -2086.55 -32.55 --- 0.00 0.00 0.00 5966102.87 634417.42 N 70.31533338 W 148.91050749 TD / Tgt / 4-1 /2" Lnr .9411.51 15.00 161.42 8950.00 9017.00 2099.69 -2099.50 -28.20 -- 0.00 0.00 0.00 5966090.00 634422.00 N 70.31529799 W 148.91047221 WeIlDesign Ver SP 2.1 Bld( doc40x_100) N-27\Plan N-27\Plan N-27\N-27 (P5) Generated 11/29/2006 11:23 AM Page 2 of 2 by Schiumberger ~" N-27 (P5) F1ELp Prudhoe Bay Unit - WOA 51RUCNRE N-PAD ~, , Nnon Pia~~zx ~~e ~ e ~~ MOJN ~c aBOOM 1006 Cip 60919' v Ma~c618. 100] M01915 ]21 69606990 ~t15ap ~. ~ 026 ilIJJ' 6b~ I~ N~t] ND Rd TaEb i6]OpO a6ova MSLi ay Nec. 2J 90]' 6'IB600 ni W1665, 166]) 99105315 i11P6i vy Oaie N emLm 19. 1006 -1200 0 1200 2400 3600 0 1200 2400 3600 0 O N C II ~ 4800 m U 6000 7200 8400 KOP Crv 1.5/100 Crv 2.5/700 End Crv Crv 3H 00 _ _ _ _ _ _ _ _ ase Pemi _ _ _ _ _ _ _ _ _ _ _ _ ...................................... - - - - - - - - - - - vd - cN inoo ; - - - - - - - - - - - - - - - End Crv ...........< ...................................y.................................j..................................~..................................~.. . _ _ _ _ _ _ _ _ _ _ _ _ G _;_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _.~3_ _ _ _ _ _ _ _ _ _ _ _ _ ...........: ...................................:..................................:.................................:..................................:...... • - - - - - - - - - - - - - - MZ- - - - - - - - - - - - - _ _ _ _ _ _ _ _ _ _ _ _ _ _ HRZ_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ FiRZ Oip fnOb: _ _ _ End Drp _ _ t _ _ _ _ _ _ _ _ _ _ ~F_ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ J€ _ _ _ _ _ _ JC Tafq~-et Start .. _.. _.....-..-..-..-..-..-..-.. -..i..-..-..-..-..-..-..-.. . _.. _.. _.. .. .. ..-..-..-..-..-. - - ~ - _ - - - - - - - - - - - - a rZ4e; - - - - - - - _ - - E - ' - - - - - 4fJ~~ - - - - - - _ _ t _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ CGL7L~rgL2 _ _ _ _ _ TDi Tgt/L1/2"Lnr ~,~) -1200 0 1200 2400 3600 Vertical Section (ft) Azim = 180.77°, Scale = 1(in):1200(ft) Origin = 0 N/-S, 0 E/-V 0 1200 2400 3600 4800 6000 7200 8400 ~~ i ~ ~~ Schlumberger ~~~~ N-27 (P5) ~"~~ Prudhoe Bay Unit - WOA ~~~~~~~~~" ~r N-PAD ra,noi Aoc.u x~.c ao uaa r uo tea.." i.a,~~ Hnozr b.e smm ~~~re~. mM oa. us r~ i. ~ ~, .~a coin ~ ~ . a ~ m.<rws~i ~ Fs. s~ev~ ~ ~~ eA~ ~~ m ow~a «. ~~.a -900 -600 -300 0 300 -300 -600 n n -900 Z `o 0 M C m -1200 (0 U V V V -1500 -1800 -2100 N-27 FIt 1 8780ss TD / Tgt / 41/2" Lnr / N-27 (PS) -900 -600 -300 0 300 «< W Scale = 1(in):300(ft) E »> -300 -600 -900 -1200 -1500 -1800 -2100 • • FieldPrudhoe Bay Site PB N Pad We11:Plan N-27 WellpathElan N-27 313 300 200 100 0 2 100 200 300 313 n 0 Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre t • • --___-- ~P_Alaska ___--- Anticollision Reuort _ Company: BP Amoco _ __ Date: 11/29/2006 ___ Time: 11:34:16 Page: 1 Field: Prudhoe Bay Reference Si te: PB N Pad Co-ordinate(NF.) Reference: Well: Plan N-27, True North Reference W elt: Plan N-27 Vertical ('fVD) Reference: N-27 Pfan 67.0 Reference Wellpath: Plan N-27 Db: Oracle - NO GLOBAL SCAN: Using user defined selection & scan criteria Reference: Principal Plan 8~ PLANNED PROGRAM Interpolation Method: MD Interval: 5.00 ft Error Model: ISCWSA Ellipse j ~ Depth Range: 28.50 to 9411.51 ft Scan Method: Trav Cylinder North Maximum Radius:10000.00 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 9/15/2005 Validated: No Version: 5 Planned From To Survey Toolcode Tool Name ft ft 28.50 1400.00 Planned: Plan #5 V1 MWD MWD -Standard 28.50 3200.00 Planned: Plan #5 V1 MWD+IFR+MS MWD +IFR + Multi Station 3200.00 8900.00 Planned: Plan #5 V1 MWD+IFR+MS MWD +IFR + Multi Station , 8900.00 9411.51 Planned: Plan #5 V1 MWD+IFR+MS MWD +IFR + Multi Station ~ Casing Points _ _ hiD T`VD Diameter Hole Size Name ft _ _ °=_ ft in in ~ - _ 3229.62 3077.00 9.625 12.250 9 5/8" i, 8938.39 8560.00 7.000 8.500 7" 9411.51 9017.00 4.500 6.125 41/2" Summary _ _ < Offset Wellpath _ > Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath VID MD Distance Area Deviation Warning ft ft ft ft ft PB N Pad N-01 N-01 V1 4514.15 4300.00 390.89 59.03 331.87 Pass: Major Risk PB N Pad N-01 N-01 A V3 4512.50 4310.00 390.89 58.91 331.98 Pass: Major Risk ~ PB N Pad N-02 N-02 V1 4225.75 3990.00 465.27 56.53 408.74 Pass: Major Risk !, PB N Pad N-03 N-03 V1 3816.03 3575.00 539.88 54.27 485.60 Pass: Major Risk j ', PB N Pad N-04A N-04A V1 1551.41 1545.00 424.46 31.89 392.57 Pass: Major Risk PB N Pad ~ N-04 N-04 V1 3914.00 3885.00 152.28 92.30 59.97 Pass: Major Risk I PB N Pad N-05 N-05 V1 1389.87 1375.00 350.06 29.03 321.03 Pass: Major Risk PB N Pad N-06 N-O6 V1 1302.04 1290.00 247.09 26.56 220.53 Pass: Major Risk PB N Pad N-07 N-07 V1 936.99 930.00 62.59 18.93 43.66 Pass: Major Risk ~ PB N Pad N-07 N-07A V8 941.06 945.00 62.66 19.03 43.64 Pass: Major Risk ii PB N Pad N-08A N-08A V2 1122.89 1115.00 151.80 24.21 127.59 Pass: Major Risk ' PB N Pad N-08 N-08 V6 1118.04 1110.00 151.72 25.80 125.92 Pass: Major Risk i PB N Pad N-09 N-09 V1 5904.71 5520.00 779.01 81.45 697.55 Pass: Major Risk !: i~ ', PB N Pad N-10 N-10 V7 4448.30 4100.00 852.16 84.44 767.71 Pass: Major Risk ', PB N Pad N-10 N-10A V1 4447.07 4100.00 852.09 84.37 767.71 Pass: Major Risk ~~ PB N Pad N-11A N-11A V1 4924.71 4565.00 619.92 60.77 559.15 Pass: Major Risk PB N Pad N-11 A N-11 B V7 4924.71 4565.00 619.90 60.77 559.13 Pass: Major Risk ! PB N Pad N-11A N-11BPB1 V5 4924.71 4565.00 619.90 60.77 559.13 Pass: Major Risk ~ PB N Pad N-11 A N-11 BP62 VS 4924.71 4565.00 619.90 60.77 559.13 Pass: Major Risk PB N Pad N-11A N-11C V7 4922.85 4560.00 619.86 60.73 559.13 Pass: Major Risk '~ PB N Pad N-11 N-11 V1 4580.63 4365.00 549.09 97.81 451.29 Pass: Major Risk '~ PB N Pad N-12 N-12 V1 3836.49 3475.00 813.90 54.56 759.34 Pass: Major Risk PB N Pad N-13 N-13 V1 4895.21 4755.00 301.05 81.38 219.66 Pass: Major Risk ', PB N Pad N-14A N-14A V3 3951.04 3720.00 583.63 62.97 520.66 Pass: Major Risk PB N Pad N-14 N-14 V1 3951.04 3720.00 583.63 62.97 520.66 Pass: Major Risk !; PB N Pad N-15 N-15 V1 659.46 675.00 202.03 10.79 191.24 Pass: Major Risk PB N Pad N-16 N-16 V1 8724.76 9320.00 779.44 511.64 267.80 Pass: Major Risk !, PB N Pad N-17 N-17 V1 599.12 615.00 1076.35 13.88 1062.47 Pass: Major Risk PB N Pad N-18 N-18 V1 584.80 600.00 1190.49 9.86 1180.62 Pass: Major Risk PB N Pad N-19 N-19 V1 613.06 635.00 1299.51 11.57 1287.94 Pass: Major Risk PB N Pad N-20A N-20A V7 647.73 680.00 1404.02 10.71 1393.31 Pass: Major Risk PB N Pad N-20 N-20 V1 651.61 685.00 1404.09 10.95 1393.13 Pass: Major Risk i PB N Pad N-21A N-21A V2 617.39 650.00 1514.52 11.25 1503.27 Pass: Major Risk ~ PB N Pad N-21 N-21 V2 Plan: Undefine 617.39 650.00 1514.53 11.21 1503.32 Pass: Major Risk ' PB N Pad N-22A N-22A V7 3998.48 3515.00 1179.61 61.18 1118.43 Pass: Major Risk PB N Pad N-22 N-22 V4 3998.49 3515.00 1179.63 61.23 1118.40 ~ Pass: Major Risk , j PB N Pad N-22 N-22A V2 3998.49 3515.00 1179.63 61.07 1118.56 Pass: Major Risk ~ PB N Pad N-22 Plan N-226 V5 Plan: N- 3973.94 3490.00 1179.37 52.22 1127.16 ' Pass: Major Risk PB N Pad N-23A N-23A V2 1030.43 1035.00 129.87 23.82 106.04 Pass: Major Risk PB N Pad N-23 N-23 V1 1030.43 1035.00 129.87 23.82 106.04 Pass: Major Risk • • Anticollision Company: BP Amoco Date: 11/29/2006 Time: 11:34:16 Page: 2 Field: Prudhoe Bay Reference Site: PB N Pad Co-ordinate(NF.) Reference: Weit Plan N-27, True North Keference Well: Plan N-27 Vertical ('PVD) Refere nce: N-27 Plan 67.0 Reference Wellpath: Plan N-27 Db: Oracle __-- Summary < Offset Wellpath -- = Reference Offset Ctr-Ctr No-Go Allowable - - -- Site Wcll Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft PB N Pad __ N-24 N-24 V1 1550.50 1520.00 677.52 _ 31.77 645.75 _ _ Pass: Major Risk PB N Pad N-25 N-25 V1 3346.56 3415.00 185.54 62.70 122.84 Pass: Major Risk ~~ PB N Pad N-26 N-26 V1 883.05 890.00 35.37 13.79 21.57 Pass: Major Risk ' • - -Target: N-27 T~- -- ------ --- ------ Site: PB N Pad We1L• N-02,Plan N-27 Drilling Target Conf.: 95% Based on: Planned Program Description: Vertical Depth: 8950.00 ft below Mean Sea Level. Map Northing: 5966090.00 ft Local +N/-S: -2099.50 ft Map Easting : 634422.00 ft Local +E/-W: -28.20 ft Latitude: 70° 18'S5.073N Longitude: 148°54'37.700W Po~gon ___ X ft Y ft Map E ft _____ Map N ft L ____ -193~1~-_ __.__ -155.57 634231.00 -_ . _____. ____. 5965931.00 -2-.-~. _____.155.01 ____ -168.82 __ 6345XO.OQ- _-_ 5965924.00 3 __-__ 173.71 ---__--_-- 1489,3___..._- ---_-_--113.4593.00 59662.42.O.Q_ 4 _-_ -20Q_62 135-63 ._ 634219.00 5966222..00_ I i -IC '' _Ic D o ~ 0 ~ D ~ 0 0 0 0 -2C -2I -2~ -2~ -2~+ 0 0 0 0 m ~ 0 0 0 0 0 ~ ~ KUPARU~< R-PA RESERVOIRS M-PAD Q n _ 6 ~ ~ ~ ~~ 5 ~/1 ~/; - N - W -.L- ~, _~__~ _ S E RD SURVEY REA , a-~ I I N-~aAn 7" ~ 8 ]~ ,~ a VICINITY MAP N.T.S. q E ~F e~ ~Q~° ooso *~~4 9 T-" ~ ~9~ JILT WELL NG WELLS POLE rEs eoaooooo0000000000oooooaooooo0 °~o Leonard J. O'Hanley ~° ~ ' Aso 11386 ~~~o ooh ~`ESSIONA~ SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF MAY 19, 2007. DATE OF SURVEY: MAY 19, 2007. REFERENCE FIELD BOOK: W007-08 (Pg 28-29). COORDINATES ARE ALASKA STATE PLANE, ZONE-4 NAD27. GEODETIC COORDINATES ARE NAD-27. WOA N-PAD AVERAGE SCALE FACTOR IS 0.9999206. ELEVATIONS ARE BPX MSL BASED ON WELL PAD N OPERATOR MONUMENTS N-1 AND N-2. LOCATED WITHIN PROTRACTED SECTION 8, T. 11 N., R. 13 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION N0. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) BOX ELEV. OFFSETS N-27 Y=5,968,189.45 N= 2,771.67 70'19'15.721" 70.3210336' 43 0 2,285' FSL ' X= 634,412.89 E= 1,000.36 148'54'36.869" 148.9102414' . 4,709 FEL CHECKED: DATE: ~ J~j (7(~©(~O JOB NO: ~LL~JI\U\~\~\J IIIJ_ SCALE: i "= s0e' by GREATER PRUDHOE BAY SHEET: AS-BUILT CONDUCTOR WELL N-27 1 °F 1 6050000 6000000 5950000 5900000 5850000 EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) 400000 500000 600000 700000 800000 • • • TRANSMITTAL LETTER CHECKLIST WELL NAME =~~I' /V '-~ / PTD# Z a ? ~ l0 / Development ~ Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in permit No. , API No. 50- - - API number are Production should continue to be reported as a function of the between 60-69) original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -_) from records, data and logs acquired for well SPACING The permit is approved subject to full. compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (name of well) until after (Com~any Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. SCom~any Name) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 7/ 13/2007 a • ^^ : , rn o a , o ~ s , , ~ =y c ~ Q , , , ~ , , , , ,~y °\ y f0' ~ t ~ ~, "a, ca ao , ~ ~ m. Z ~' a `~ s ~ ~ v,, , c E O ~ m. ~ o Z, ' p, c~ N °' c c ° a. E °~ , N ~ ~ .a~ ~ ~ ~ ~ y ~, ~ ~ ~ ~ , ~ ~ f6 ~ ~ O ~ ~ y, , ,r y, . a_ O ~ G ~ ~ ~ ~ N ~ ~ ~ ~ > t O, ~ ° a o: ~ y, a ~, m , ~ . 3 m O ° s _~ . - ~, ~, v d> j y' Z a ~ c O w j , N t, , 4.. . ~ d ~ N• ~~ , , N. Q ' . 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