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Home My WebLink About202-058MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, October 15, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC L-105 PRUDHOE BAY UN BORE L-105 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/15/2024 L-105 50-029-23075-00-00 202-058-0 G SPT 6398 2020580 4000 1727 1741 1734 1735 1051 1072 1075 1075 REQVAR P Adam Earl 8/14/2024 MIT-IA tested as per AIO 24B.005 to 4K 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN BORE L-105 Inspection Date: Tubing OA Packer Depth 657 4230 4159 4159IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE240814145430 BBL Pumped:3.5 BBL Returned:3.1 Tuesday, October 15, 2024 Page 1 of 1 9 9 9 9 9 9 9 999 9 9 9 99 9 9 AIO 24B.005 James B. Regg Digitally signed by James B. Regg Date: 2024.10.15 15:21:27 -08'00' CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: [EXTERNAL] RE: UPDATE UNDER EVALUATION: WAG Injector L-105 (PTD # 2020580) Anomalous IA re-pressurization Date:Tuesday, September 13, 2022 9:02:37 AM Attachments:image001.png image002.png image003.png image004.png From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Monday, September 12, 2022 4:17 PM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: Re: [EXTERNAL] RE: UPDATE UNDER EVALUATION: WAG Injector L-105 (PTD # 2020580) Anomalous IA re-pressurization Ryan, Yes, let's keep it injecting at least while the admin approval application is processing through AOGCC . Thanks, Chris From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Monday, September 12, 2022 1:57:57 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject: RE: [EXTERNAL] RE: UPDATE UNDER EVALUATION: WAG Injector L-105 (PTD # 2020580) Anomalous IA re-pressurization Mr. Wallace, We are currently on day 14 of the previously approved extension. Would it be possible to get an additional 14 days? Thank you, Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Monday, August 29, 2022 3:34 PM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: [EXTERNAL] RE: UPDATE UNDER EVALUATION: WAG Injector L-105 (PTD # 2020580) Anomalous IA re-pressurization Ryan, Thank you for the call and email. Your request to extend the monitoring/evaluation and injection for an additional 14 days while you complete the admin approval request 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: Friday, August 26, 2022 3:30 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>; Stan Golis <sgolis@hilcorp.com> Subject: UPDATE UNDER EVALUATION: WAG Injector L-105 (PTD # 2020580) Anomalous IA re-pressurization 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. Mr. Wallace, WAG Injector L-105 (PTD# 2020580) a passing AOGCC MIT-IA was conducted on 08/14/22 to 4120 psi. The IA re-pressurization rate has been uneven during the current under evaluation period which ends on 08/28/22. With permission, we would like to extend the current under evaluation period for an additional 14 days to continue monitoring the re-pressurization rate. In that time, we also plan to submit a request for administrative approval for continued injection. Please call with 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 Sent: Monday, August 1, 2022 3:39 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: jim.regg@alaska.gov; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: UNDER EVALUATION: WAG Injector L-105 (PTD # 2020580) Anomalous IA re-pressurization Mr. Wallace, WAG Injector L-105 (PTD# 2020580) was observed to have anomalous IA re-pressurization on 07/26/22 from automated exception reports. IA pressure was bled on 07/27/22 from 1540 psi to 380 psi with all liquid returns. The re-pressurization initially appeared to be thermal / rate induced. The IA was again bled on 07/31/22 from 760 psi to +0 psi with a mixture of liquid / gas returns. At this time, the well is classified as UNDER EVALUATION for possible TxIA communication. The well is on a 28 day clock to be resolved. Plan Forward: 1. Downhole diagnostics: PPPOT-T & IC 2. Fullbore: MIT-IA 3. Well Integrity: 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 Projects Well Integrity <AKDCProjectsWellIntegrityEngineer@bp.com> Sent: Friday, February 10, 2017 1:26 PM To: AK, OPS GC2 OSM <AKOPSGC2OSM@bp.com>; AK, OPS GC2 Field O&M TL <AKOPSGC2FieldOMTL1@bp.com>; AK, OPS GC2 Facility OTL <AKOPSGC2FacilityOTL@bp.com>; AK, OPS GC2 Wellpad Lead <AKOPSGC2WellpadLead@bp.com>; AK, OPS Well Pad LV <AKOPSWellPadLV@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt@BP.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; Zoesch, Eric <zoese0@BP.com>; Rupert, C. Ryan <Ryan.Rupert@BP.com>; Peru, Cale <Cale.Peru@bp.com>; ''Regg, James B (DOA) (jim.regg@alaska.gov)' (jim.regg@alaska.gov)' <jim.regg@alaska.gov> Cc: AK, GWO DHD Well Integrity <AKD&CDHDWellIntegri@bp.com>; AK, GWO Projects Well Integrity <AKDCProjectsWellIntegrityEngineer@bp.com>; AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@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>; Pettus, Whitney <Whitney.Pettus@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Tempel, Troy <Troy.Tempel@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com>; ''chris.wallace@alaska.gov' (chris.wallace@alaska.gov)' <chris.wallace@alaska.gov>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com>; AKIMS App User <akimsuser.service@bp.com>; AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Subject: OPERABLE: WAG Injector L-105 (PTD # 2020580) OA Normal Operating Limit (NOL) Revised to 1,500psi All, Injector L-105 (PTD# 2020580) now has a revised OA Normal Operating Limit (NOL, formerly MOASP) of 1500 psi. The NOL revision is via Management of Change eMoC 10221. An engineering design review of the well and wellhead system was completed and approved. A sign indicating the revised NOL has been installed. With the NOL revision this well now meets BP operability criteria and is reclassified as Operable. Please respond with any questions. Joshua Stephens Well Integrity Engineer Office: 907-659-5766 Cell: 903-816-0183 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 recipientor 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 considersappropriate. 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 recipientor 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 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 considersappropriate. 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: WAG Injector L-105 (PTD # 2020580) Anomalous IA re-pressurization Date:Tuesday, September 6, 2022 3:23:51 PM Attachments:image005.png image006.png image007.png image008.png From: Wallace, Chris D (OGC) Sent: Monday, August 29, 2022 3:34 PM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: RE: UPDATE UNDER EVALUATION: WAG Injector L-105 (PTD # 2020580) Anomalous IA re-pressurization Ryan, Thank you for the call and email. Your request to extend the monitoring/evaluation and injection for an additional 14 days while you complete the admin approval request 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: Friday, August 26, 2022 3:30 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>; Stan Golis <sgolis@hilcorp.com> Subject: UPDATE UNDER EVALUATION: WAG Injector L-105 (PTD # 2020580) Anomalous IA re-pressurization Mr. Wallace, WAG Injector L-105 (PTD# 2020580) a passing AOGCC MIT-IA was conducted on 08/14/22 to 4120 psi. The IA re-pressurization rate has been uneven during the current under evaluation period which ends on 08/28/22. With permission, we would like to extend the current under evaluation period for an additional 14 days to continue monitoring the re-pressurization rate. In that time, we also plan to submit a request for administrative approval for continued injection. Please call with 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 Sent: Monday, August 1, 2022 3:39 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: jim.regg@alaska.gov; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: UNDER EVALUATION: WAG Injector L-105 (PTD # 2020580) Anomalous IA re-pressurization Mr. Wallace, WAG Injector L-105 (PTD# 2020580) was observed to have anomalous IA re-pressurization on 07/26/22 from automated exception reports. IA pressure was bled on 07/27/22 from 1540 psi to 380 psi with all liquid returns. The re-pressurization initially appeared to be thermal / rate induced. The IA was again bled on 07/31/22 from 760 psi to +0 psi with a mixture of liquid / gas returns. At this time, the well is classified as UNDER EVALUATION for possible TxIA communication. The well is on a 28 day clock to be resolved. Plan Forward: 1. Downhole diagnostics: PPPOT-T & IC 2. Fullbore: MIT-IA 3. Well Integrity: 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 Projects Well Integrity <AKDCProjectsWellIntegrityEngineer@bp.com> Sent: Friday, February 10, 2017 1:26 PM To: AK, OPS GC2 OSM <AKOPSGC2OSM@bp.com>; AK, OPS GC2 Field O&M TL <AKOPSGC2FieldOMTL1@bp.com>; AK, OPS GC2 Facility OTL <AKOPSGC2FacilityOTL@bp.com>; AK, OPS GC2 Wellpad Lead <AKOPSGC2WellpadLead@bp.com>; AK, OPS Well Pad LV <AKOPSWellPadLV@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt@BP.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; Zoesch, Eric <zoese0@BP.com>; Rupert, C. Ryan <Ryan.Rupert@BP.com>; Peru, Cale <Cale.Peru@bp.com>; ''Regg, James B (DOA) (jim.regg@alaska.gov)' (jim.regg@alaska.gov)' <jim.regg@alaska.gov> Cc: AK, GWO DHD Well Integrity <AKD&CDHDWellIntegri@bp.com>; AK, GWO Projects Well Integrity <AKDCProjectsWellIntegrityEngineer@bp.com>; AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@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>; Pettus, Whitney <Whitney.Pettus@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Tempel, Troy <Troy.Tempel@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com>; ''chris.wallace@alaska.gov' (chris.wallace@alaska.gov)' <chris.wallace@alaska.gov>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com>; AKIMS App User <akimsuser.service@bp.com>; AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Subject: OPERABLE: WAG Injector L-105 (PTD # 2020580) OA Normal Operating Limit (NOL) Revised to 1,500psi All, Injector L-105 (PTD# 2020580) now has a revised OA Normal Operating Limit (NOL, formerly MOASP) of 1500 psi. The NOL revision is via Management of Change eMoC 10221. An engineering design review of the well and wellhead system was completed and approved. A sign indicating the revised NOL has been installed. With the NOL revision this well now meets BP operability criteria and is reclassified as Operable. Please respond with any questions. Joshua Stephens Well Integrity Engineer Office: 907-659-5766 Cell: 903-816-0183 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 recipientor 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 anyattachments 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 considersappropriate. 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: WAG Injector L-105 (PTD # 2020580) Anomalous IA re-pressurization Date:Tuesday, August 30, 2022 2:10:55 PM Attachments:image005.png image006.png image007.png image008.png From: Wallace, Chris D (OGC) Sent: Monday, August 29, 2022 3:34 PM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: RE: UPDATE UNDER EVALUATION: WAG Injector L-105 (PTD # 2020580) Anomalous IA re-pressurization Ryan, Thank you for the call and email. Your request to extend the monitoring/evaluation and injection for an additional 14 days while you complete the admin approval request 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: Friday, August 26, 2022 3:30 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>; Stan Golis <sgolis@hilcorp.com> Subject: UPDATE UNDER EVALUATION: WAG Injector L-105 (PTD # 2020580) Anomalous IA re-pressurization Mr. Wallace, WAG Injector L-105 (PTD# 2020580) a passing AOGCC MIT-IA was conducted on 08/14/22 to 4120 psi. The IA re-pressurization rate has been uneven during the current under evaluation period which ends on 08/28/22. With permission, we would like to extend the current under evaluation period for an additional 14 days to continue monitoring the re-pressurization rate. In that time, we also plan to submit a request for administrative approval for continued injection. Please call with 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 Sent: Monday, August 1, 2022 3:39 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: jim.regg@alaska.gov; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: UNDER EVALUATION: WAG Injector L-105 (PTD # 2020580) Anomalous IA re-pressurization Mr. Wallace, WAG Injector L-105 (PTD# 2020580) was observed to have anomalous IA re-pressurization on 07/26/22 from automated exception reports. IA pressure was bled on 07/27/22 from 1540 psi to 380 psi with all liquid returns. The re-pressurization initially appeared to be thermal / rate induced. The IA was again bled on 07/31/22 from 760 psi to +0 psi with a mixture of liquid / gas returns. At this time, the well is classified as UNDER EVALUATION for possible TxIA communication. The well is on a 28 day clock to be resolved. Plan Forward: 1. Downhole diagnostics: PPPOT-T & IC 2. Fullbore: MIT-IA 3. Well Integrity: 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 Projects Well Integrity <AKDCProjectsWellIntegrityEngineer@bp.com> Sent: Friday, February 10, 2017 1:26 PM To: AK, OPS GC2 OSM <AKOPSGC2OSM@bp.com>; AK, OPS GC2 Field O&M TL <AKOPSGC2FieldOMTL1@bp.com>; AK, OPS GC2 Facility OTL <AKOPSGC2FacilityOTL@bp.com>; AK, OPS GC2 Wellpad Lead <AKOPSGC2WellpadLead@bp.com>; AK, OPS Well Pad LV <AKOPSWellPadLV@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt@BP.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; Zoesch, Eric <zoese0@BP.com>; Rupert, C. Ryan <Ryan.Rupert@BP.com>; Peru, Cale <Cale.Peru@bp.com>; ''Regg, James B (DOA) (jim.regg@alaska.gov)' (jim.regg@alaska.gov)' <jim.regg@alaska.gov> Cc: AK, GWO DHD Well Integrity <AKD&CDHDWellIntegri@bp.com>; AK, GWO Projects Well Integrity <AKDCProjectsWellIntegrityEngineer@bp.com>; AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@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>; Pettus, Whitney <Whitney.Pettus@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Tempel, Troy <Troy.Tempel@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com>; ''chris.wallace@alaska.gov' (chris.wallace@alaska.gov)' <chris.wallace@alaska.gov>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com>; AKIMS App User <akimsuser.service@bp.com>; AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Subject: OPERABLE: WAG Injector L-105 (PTD # 2020580) OA Normal Operating Limit (NOL) Revised to 1,500psi All, Injector L-105 (PTD# 2020580) now has a revised OA Normal Operating Limit (NOL, formerly MOASP) of 1500 psi. The NOL revision is via Management of Change eMoC 10221. An engineering design review of the well and wellhead system was completed and approved. A sign indicating the revised NOL has been installed. With the NOL revision this well now meets BP operability criteria and is reclassified as Operable. Please respond with any questions. Joshua Stephens Well Integrity Engineer Office: 907-659-5766 Cell: 903-816-0183 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 recipientor 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 anyattachments 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 considersappropriate. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, September 15, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC L-105 PRUDHOE BAY UN BORE L-105 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/15/2022 L-105 50-029-23075-00-00 202-058-0 G SPT 6398 2020580 4000 1926 1930 1925 1924 1180 1176 1198 1211 OTHER P Bob Noble 8/14/2022 Operates under AA AIO 24B.005 for OA re-pressurization. Well is under eval for T x IA comm. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN BORE L-105 Inspection Date: Tubing OA Packer Depth 189 4213 4139 4120IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN220814150631 BBL Pumped:4.1 BBL Returned:4 Thursday, September 15, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 PLQ7XELQJDQGLQLWLDO2$SUHVVXUHVUHYLVHG 9 9 5(9,6(' 1924 1176 PLQ7XELQJDQGLQLWLDO2$SUHVVXUHVUHYLVHG AIO 24B.005 James B. Regg Digitally signed by James B. Regg Date: 2022.09.15 11:37:11 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, August 30, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC L-105 PRUDHOE BAY UN BORE L-105 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/30/2022 L-105 50-029-23075-00-00 202-058-0 G SPT 6398 2020580 4000 1926 1930 1925 1942 1180 1176 1191 1211 OTHER P Bob Noble 8/14/2022 Operates under AA AIO 24B.005 for OA re-pressurization. Well is under eval for T x IA comm. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN BORE L-105 Inspection Date: Tubing OA Packer Depth 189 4213 4139 4120IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN220814150631 BBL Pumped:4.1 BBL Returned:4 Tuesday, August 30, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 AIO 24B.005 for OA re-pressurization.under eval for T x IA comm. James B. Regg Digitally signed by James B. Regg Date: 2022.08.30 15:30:02 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: WAG Injector L-105 (PTD # 2020580) Anomalous IA re-pressurization Date:Wednesday, August 3, 2022 11:02:59 AM Attachments:image001.png image003.png From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Monday, August 1, 2022 3:39 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>; Stan Golis <sgolis@hilcorp.com> Subject: UNDER EVALUATION: WAG Injector L-105 (PTD # 2020580) Anomalous IA re-pressurization Mr. Wallace, WAG Injector L-105 (PTD# 2020580) was observed to have anomalous IA re-pressurization on 07/26/22 from automated exception reports. IA pressure was bled on 07/27/22 from 1540 psi to 380 psi with all liquid returns. The re-pressurization initially appeared to be thermal / rate induced. The IA was again bled on 07/31/22 from 760 psi to +0 psi with a mixture of liquid / gas returns. At this time, the well is classified as UNDER EVALUATION for possible TxIA communication. The well is on a 28 day clock to be resolved. Plan Forward: 1. Downhole diagnostics: PPPOT-T & IC 2. Fullbore: MIT-IA 3. Well Integrity: 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 Projects Well Integrity <AKDCProjectsWellIntegrityEngineer@bp.com> Sent: Friday, February 10, 2017 1:26 PM To: AK, OPS GC2 OSM <AKOPSGC2OSM@bp.com>; AK, OPS GC2 Field O&M TL <AKOPSGC2FieldOMTL1@bp.com>; AK, OPS GC2 Facility OTL <AKOPSGC2FacilityOTL@bp.com>; AK, OPS GC2 Wellpad Lead <AKOPSGC2WellpadLead@bp.com>; AK, OPS Well Pad LV <AKOPSWellPadLV@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt@BP.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; Zoesch, Eric <zoese0@BP.com>; Rupert, C. Ryan <Ryan.Rupert@BP.com>; Peru, Cale <Cale.Peru@bp.com>; ''Regg, James B (DOA) (jim.regg@alaska.gov)' (jim.regg@alaska.gov)' <jim.regg@alaska.gov> Cc: AK, GWO DHD Well Integrity <AKD&CDHDWellIntegri@bp.com>; AK, GWO Projects Well Integrity <AKDCProjectsWellIntegrityEngineer@bp.com>; AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@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>; Pettus, Whitney <Whitney.Pettus@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Tempel, Troy <Troy.Tempel@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com>; ''chris.wallace@alaska.gov' (chris.wallace@alaska.gov)' <chris.wallace@alaska.gov>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com>; AKIMS App User <akimsuser.service@bp.com>; AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Subject: OPERABLE: WAG Injector L-105 (PTD # 2020580) OA Normal Operating Limit (NOL) Revised to 1,500psi All, Injector L-105 (PTD# 2020580) now has a revised OA Normal Operating Limit (NOL, formerly MOASP) of 1500 psi. The NOL revision is via Management of Change eMoC 10221. An engineering design review of the well and wellhead system was completed and approved. A sign indicating the revised NOL has been installed. With the NOL revision this well now meets BP operability criteria and is reclassified as Operable. Please respond with any questions. Joshua Stephens Well Integrity Engineer Office: 907-659-5766 Cell: 903-816-0183 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 recipientor 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 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 anyattachments 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 considersappropriate. MEMORANDUM TO: Jim Regg � ' -I Z( 2?,Z-z P.I. Supervisor Z FROM: Brian Bixby Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, January 21, 2022 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC L-105 PRUDHOE BAY UN BORE L-105 Sre: Inspector Reviewed By: P.I. Supry r'` 7 � Comm Well Name PRUDHOE BAY UN BORE L-105 API Well Number 50-029-23075-00-00 Inspector Name: Brian Bixby Permit Number: 202-058-0 Inspection Date: 1/17/2022 Insp Num: mitBDB220117134105 Rel Insp Num: Packer Depth Well I L -los ;Type Inj I G TVD 6398 Tubing PTD 2020580 Type Test SPT ITest psi 4000 - IA BBL Pum p RE vAR ---urned. 4.5 OA Interval) Q P/F ed: 3.5 BBL Ret Notes: MITIA as per AIO 2413.005 / Pretest Initial 15 Min 30 Min 45 Min 60 Min - -- 2195 -------2-1-9-5--,--2-1-9-6 - 1 2188 - -- - 51 4200 - I 4133 4125 i 1019 980 ' 1036 -� 1058 �- Friday, January 21, 2022 Page 1 of 1 MEMORANDUM State of Alaska Permit Number: 202-058-0 Inspection Date: 1/14/2020 ' Alaska Oil and Gas Conservation Commission TO: Jim Regg/ it DATE: Wednesday, January 15, 2020 P.I. Supervisor I SUBJECT: Mechanical Integrity � n' Tests 15 Min 30 Min 45 Min 60 Min BP Exploration (Alaska) Inc. L-105 L-105 FROM: Bob Noble PRUDHOEBAYUN BORE L-105 Petroleum Inspector Tubing 1685 - Sre: Inspector 1686 Reviewed By: P.I. Supry J3 -- NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UN BORE L-105 API Well Number 50-029-23075-00-00 Inspector Name: Bob Noble Permit Number: 202-058-0 Inspection Date: 1/14/2020 ' Insp Num: mi[RCN200114151451 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min L-105 Type Inj W ' TVD 6398 Tubing 1685 - 1685 1686 1685 zozosso Type Test SPT Test psi 4000 IA 702 4200 4113 4094 ' rRBLPumped:3? BBL Returned: ' 3.4 OA 1277 1221 - 1266 ' 1287 REQvAR P/F I P Notes: AA 24B.005 requires 2 year MIT -]A to 4000 psi. Wednesday, January 15, 2020 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Re /7 DATE: Tuesday,January 23,2018 P.I.Supervisorg �‹ J ' Z31I SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. L-105 FROM: Chuck Scheve PRUDHOE BAY UN BORE L-105 Petroleum Inspector Src: Inspector Reviewed Byy:? P.I.Suprv��L- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN BORE L-105 API Well Number 50-029-23075-00-00 Inspector Name: Chuck Scheve Permit Number: 202-058-0 Inspection Date: 1/21/2018 Insp Num: mitCS180122063330 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well L-105 '1Typelnj W TVD 6398 "ITubingi 1865 1875 - 1872 - 1873 - PTD 2020580 ' Type Test SPT Test psi a00o - IA 69 4201 - 4139 4126 BBL Pumped: 4 • rBBL Returned: 4 - OA 1076 , 1023 - 1081 - 1108 -r Interval REQVAR P/F P Notes: Tested per AIO 24B.005 v %ANNE) t p ; Tuesday,January 23,2018 Page 1 of 1 ' OF ?,y Iy/,�s� THE STATE Alaska Oil and Gas • 4, -t��, of® TA S KA Conservation Commission ffx____ 333 West Seventh Avenue `� /* GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OFALAS-*P' Fax: 907.276.7542 www.aogcc.alaska.gov Jessica Sayers Production EngineerQEF BP Exploration(Alaska), Inc. %M P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Borealis Oil Pool, BRLS L-105 Permit to Drill Number: 202-058 Sundry Number: 316-237 Dear Ms. Sayers: 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, 7a)t(Alt. , Cathy P Foerster Chair DATED this 24 day of May, 2016. RBDMS LL MAY 2 5 2016 STATE OF ALASKA RECEIVED •ALASKA OIL AND GAS CONSERVATION COMMIT N APR 1 8 2016 APPLICATION FOR SUNDRY APPROVALS / i 20 AAC 25.280 PTS jrZ j(�‘ 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Repair Well 0 ' �'1OGICChutdown 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 Micro OA Squeeze RI• 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 202-058 . 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0 99519-6612 Stratigraphic 0 Service 6. API Number: 50-029-23075-00-00 . H 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 RI BRLS L-105 • 9. Property Designation(Lease Number): 10. Field/Pools: ADL 0028238 ` PRUDHOE BAY,BOREALIS 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): 8360 • 6852 • 8267 , 6772 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"91.5#H-40 33-113 33-113 1490 470 Surface 2828 9-5/8"40#L-80 32-2860 32-2639 5750 3090 Intermediate Production 8326 7"26#L-80 29-8354 29-6847 7240 5410 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment 4-1/2"12.6#L-80 L-80 26-7889 Packers and SSSV Type: See Attachment Packers and SSSV MD(ft)and TVD(ft): See Attachment 4-1/2"MCX I-SSV 2194, 2124.80 12.Attachments: Proposal Summary H Wellbore Schematic E 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 Service H • 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG ®- 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 Sayers,Jessica be deviated from without prior written approval. Email Jessica.Sayers@bp.com Printed Name Sayers,Jessica Title Well Integrity Engineer Signature C < Phone +1 907 564 4281 Date I j /i' 1� V COMMISSION USE ONLY 'i Conditions of approv. .tify Commission so that a r rese tative may witness Sundry Number: S\Le- 2x7 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: Post Initial Injection MIT Req'd? Yes 0 No Spacing Exception Required? Yes 0 No G" Subsequent Form Required: J Fj _g APPROVED BYTHE Approved by: ,994...,41-.k. COMMISSIONERCOMMISSION Date:5.Valiti7 rL- � //(o ORIGINAL RBDMS Li— MAY 252016 Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval.A1/4/ Attachments in Duplicate /6 r<- v ci. z,, . 4, • • a ca m c0 N N CO N CO I- O L N . 00 Q. 00 d7 M O I— 00 o O N- O Lo 00 O M O C0 CO (o C0 0 C0 (0 CO F a 0 1- 00 0) N- ti ON O M 00 d O Lr O h- ~ 00 Mocococacoin 10 c0 O cO co O c0 CO O O 0 H w w o' 0 O 0 Z w w p w p F H J a w o' m 0 W U U w w •▪ O L() M N O M d- O J J J Q < UWj W a N O N M r r N- ¢ Q Q Lu a ° z a) = O N- O 0 0 0 0 0 O N- N- 00 00 00 00 CO a) Z Z_U U_ Z_U J w w O 7.3 O J J 11 p co a 2 U UU W w w o Q Q 014 2 2 2 0 cnCU cn U cn cn Q _Ia .I 0 C V) -5 O LO (N M (N O CO J a O O = N M �' .- O O N d O N N- O O O O O I.L N- N- OO OO CO 00 00 CO L MM N ai O 2 o = H O a J a 2 O cn U cn cn a) a y a 0 U °• UUP-. u. awu � al- - aaaoaw a 0 t m a O H is N N N N N CV (N O O O O O O O O N p 0 • 0 0 0 0 0 0 0 0 w W Z O a) a) o cococo coN O p LU N LL = = = = = = p a w U p w IX a i i ao 0o ao 0o ao 00 ¢ p ; J J w D wa O CO p w J J Q ° w Q Q a cn LL cn a IY N co co Z 10 Ln Lf) Lf) 10 10 U) L() 5 0 0 0 O O O O O LL N Q_' LL 0:10_ a 0_ 0 J 00 L110- J J J J J J J < < m m LL LL cn (n a • • Packers and SSV's Attachment BRLS L-105 SW Name Type MD TVD Depscription L-105 SSSV 2194 2125.04 4-1/2" MCX I-SSV L-105 TBG PACKER 7649.63 6251.33 4-1/2" Baker Premier Packer L-105 TBG PACKER 7831.93 6401.59 4-1/2" Baker S-3 Perm Packer • • 4 Date: 04-14-2016 X0.44' From: Jessica Sayers, Well Integrity/Intervention Engineer (office: 564-4281, cell: 602-8715) Subject: L-105 SqueezeCrete MicroOA Squeeze Objective This program is intended to guide the execution of a cemented OA, low injectivity, • surface casing squeeze repair treatment with SqueezeCrete. This well exhibits sustained OA pressure on and off line and needs remediation. Well Detail Current Status: Operable Previous Test: 01-09-16 MIT-OA to 3000 psi, Pass, 0.19 gpm LLR 04-03-15 MIT-OA to 3000 psi, Pass, 0.37 gpm LLR Integrity Issues: Fully cemented OA with sustained pressure Well Operation Detail Fluid Density: 14 ppg Slurry: SqueezeCrete Relevant History: > 04/03/15: AOGCC MIT-IA Passed to 4100 psi LLR OA 0.374 gpm @ 3000 psi > 01/05/16: MIT-IA Passed to 4200 psi > 01/09/16: AOGCC MIT-IA Passed to 4114 psi, AOGCC OA LLR=0.187 gpm 1 of 3 • • Procedure: 1 D Remove blue goo and ice/material in conductor and clean OA. 2 D Place Squeezecrete in OA, until clean, 1:1 SqueezeCrete returns are observed. Take returns to a grounded bucket. 3 D Rig up pneumatic pump, and resume pumping operation by squeezing SqueezeCrete into OA. Pump until bump (3000 psi max). 4 D Let well cure. 6 D POP well under evaluation 2 of 3 • 0 MEE= 4•1/16'C1W SAFETY NOT : HIS REACRIGS AVBtAGE 126 pone AELLI.EAD= FMC ACTIATCR= ,BAKER C L-105 MR34 ON1411'•'WELL REQUIRES A SSW WHEJI ON MI"* 6471iiv--, 714 24 I KOP- — .7.---i 900J-19-5/8'TAM FORT ODLLAR I ... PAul ArKie= 48*0 6446 _.•CONDUCTC43, Man Datum OM= else, I { 2194' H4-srr rem x p ',D.aeno- I DohiraTV13= 6600'SS , 10• • 9-5/1"CSG,401,1.86 tac,0-ow ---i 285e I--i I, GAS LFT MOUS ST1 MD TVD my TY FE VLV LATCH PORT CATE 3 1 3966 3489 41 KF1G-2 MN BK 0 09,15(14 2 Minimum ID.•3.725"ft 78771 II, ,5285 4496 42 KBG-2 )Nr BK 07/20/02 1 13 , 1 1 7569_6186_ 37 A21G-2 MK BR 0 _10/13707 4-1/2"HES 01 NIPPLE 1 i I ' 7836' -14-1tri435 X Z 76116' H 7"X 4-182'E1KR FREDA RtH,D=3,aor j I I I Thir 1-14-D7 I-ES X wo=3.813- j X pri j j_.mar__FIT x 41/2'eER S-3 PKR D-.3,675- I I 7162' 1—I4-1/2"1133 X NIP,D 3812' j 4-V2'T6G.12.68„L-80 TC11. — 7884' D1524.1,0.3,966- I 71-73' 41-112'VES)0111.,13=1725-1 ---- — . Ther H 4-11,2-INLEGy 0 r•3.958-I FERFORATCH SUMMARY WY LOG SQUEEZE FEW REcan A NGLEAT TOP FEFF. 31'0801Z 7904' Hr MARKER JOINT w i FP,TALI Note:Herr b Produoban DB for huslocioal port dab _ STE I SW NRERVAL OpriSqz StUT SOZ I 4-117 i• 6 '7700-7720 S 07117114 07/18/02 4-1/2' 6 1785-7805 S 07/17/14 07/18/02 3-34T 6 8012-8032 0 18/18(02 I 4-1/7 6 8023-8543 0 07/16(22 3-3At" 8 8040-8974 0 08/18/02 I, 8 8104 8110 , sow MA Hr . RC FR rlNT tio i RA Tilt: I 3-3A3 - 0 06/07/02 11 , ... I FILT.13 —1____jazsr 4$4 144414+44 414,104• •1,4,4,4.4,11A4,4041m 1 r csa 268,1410 BTGU.1383 KC I)‘.8276' I 8360' ''''''"•"'''''''''''' DATE ,REV BY OC•AMENTS DATE FEV BY COR./NTS BOREALB LPIT 07/21/02 141111 OF99944.1.COUPLE/FON '01/17/12 11141.110 ACCED KIS SAFETY NOTE VALL L-105 08/05,02 RAI MN urcarE 07/30/14*WCUIC SET mow_rpeu SLO(07/13/14) FERUTT NO:Imosao 081p18m7 i_..ricK Arksars 06/27H4 MP PJC RLL Gausitai AR No; 30-029-2307540 1W13/02 ISIKAK QV 00 OW 2/14 JIM RE SET ORC VALVE,FS SEC 34,TUN R11 E 2418'ESL 8.1707'ROL 04/08)03 CRS/TP TV CNC OD1*ECTION3 09/15114 JIM RIG(JAY GLV II 3 02115/11 1.613143 ACOEDSSEN SAFETY PETE EIP Bcploralfan(Alaska) 3 of 3 • • PTP 20Z-0S Loepp, Victoria T (DOA) From: Sayers,Jessica <Jessica.Sayers@bp.com> Sent: Tuesday, May 17,2016 10:03 AM To: Loepp,Victoria T(DOA) Subject: RE: PBU Z-19A(PTD 206-105,Sundry 316-244); PBU L-105(PTD 202-058,Sundry 316-237) Micro OA Squeeze Follow Up Flag: Follow up Flag Status: Flagged Hi Victoria! sudiNED FEB 1 �a�, See answers to question, below: 1. We have performed 15. So far,the 15 wells have been able to be operated within our operating limits post treatment. 2. Z-19: 1,250 psi; L-105: 1,110 psi 3. Some of the wells we have treated have IAxOA communication. However,the majority of wells treated have OA pressure that exceeds our operating limit when on-line. We think it is thermally activated, rather than a sustained casing source.The source is not known for these wells and there are a few theories including shallow hydrate gas. It's not definitive though. We don't have any other options we these wells. By treating them,we can manage the wells within our operating wells. Otherwise,the wells will remain shut-in until they are P&Ad.This is a huge bummer because the actual reservoir barriers (tubing and PC) are often shiny and new from recent rig workovers, casing cut and pulls, in which the OA is cemented to surface and this problem then becomes evident. Hope that makes sense and answers your questions. Please let me know if you need any more information! Thanks! Jess Sayers From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Tuesday, May 17, 2016 9:38 AM To: Sayers, Jessica Subject: PBU Z-19A(PTD 206-105, Sundry 316-244); PBU L-105(PTD 202-058, Sundry 316-237) Micro OA Squeeze Jessica, A couple questions 1. How many micro annulus squeezes on the OA have been performed on wells in PBU and what have been the results? 2. How high is the OA pressuring up to in each of these two subject wells? 3. Do you know the source of the pressure? Thanx, Victoria Victoria Loepp 1 • 41110 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Sunday, March 13, 2016 6:06 PM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M TL;AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan;AK, D&C Wireline Operations Superintendent;AK, D&C Well Services Operations Superintendent; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr;AK, OPS PCC Ops Lead;AK, OPS Well Pad LV; Shrider,James; '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; Pettus, Whitney; Sayers, Jessica; Dickerman, Eric; Regg,James B (DOA); Munk, Corey; Odom, Kristine Subject: UPDATE March 13, 2016 OPERABLE:Injector L-105 (PTD#2020580) Administrative Approval Amended Attachments: L-105 AA24B.005 OA hydrates replacement_udpated 03-08-16.pdf All, Injector L-105 (PTD#2020580) recently began operating under Administrative Approval Area Injection Order(A10) 246.005 for high OA pressure. The AOGCC has issued a revised copy of the Administrative Approval sent out on March 05, 2016. The update includes an amended MIT anniversary date of January 09, 2016 instead of April 03, 2015. The well will remain classified as Operable and be carried on the monthly AOGCC Injection Report. The requirements of the approval still include flagging bleeds, a two year witnessed AOGCC MIT-IA cycle instead of annual testing, and no further requirements for a liquid leak rate (LLR)of the OA. A copy of the amended Administrative Approval has been attached for reference and shall be posted in the well house during well operation. Thank you, Whitney Pettus (Alternate:Kevin Parks) APR 0 4 2016 BP�Allasska-Well Integrity Coordinator E� fM A 0.gs: O y.: WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinatorPBP.com From: AT�JVeII Integrity Coordinator Sent: Saturday, March 05, 2016 3:26 PM To: AK, OPS GC2 OSM; AK, OPS GC T i&d fl&M TtLj AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; S PCC Ops Lead; AK, OPS Well Pad LV; Shrider, James; '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; Pettus, Whitney; Sayers, Jessica; Dickerman, Eric; '.e g, James B 1 • i MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,February 18,2016 TO: Jim RSUBJECT:Mechanical Integrity Tests P.I.Supervisor Jv 2 1 19C1(F b BP EXPLORATION(ALASKA)INC. L-105 FROM: Jeff Jones PRUDHOE BAY UN BORE L-105 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry i,ate NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN BORE L-105 API Well Number 50-029-23075-00-00 Inspector Name: Jeff Jones Permit Number: 202-058-0 Inspection Date: 1/9/2016 Insp Num: mit3J160110124730 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min ------ -------- -- — Well' L-105 _ Type Inj W'TVD 6398 - Tubing 1602 1602 . 1599 _ 1596 - PTD 2020580 - Type Test SPT Test psi 1600 IA 488 4202 _ 4131 - 4114 - Interval REQVAR P/F P / OA 837 802 - 839 855 Notes: MIT-IA to 4000 PSI per AOGCC AIO 24.004.3.4 BBLS diesel pumped. 1 well inspected,no exceptions noted. SCANNED SEP 2 7 2016 Thursday,February 18,2016 Page 1 of 1 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,February 18,2016 TO: Jim Regg P.I.Supervisor -7-fz"III( SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. L-105 FROM: Jeff Jones PRUDHOE BAY UN BORE L-105 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprwi NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN BORE L-105 API Well Number 50-029-23075-00-00 Inspector Name: Jeff Jones Permit Number: 202-058-0 Inspection Date: 1/9/2016 Insp Num: mitJJ160110125623 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well L-105 !Type Inj ' 'TVD 6398 - Tubing 1599 , 1599 - 1599 - 1603 PTD 2020580 - Type Test SPT Test psi 1600 - IA 693 697 703 — 709 - Interval 11 QvM P/F P ✓ OA 462 3040 - 3003 3000 Notes: Liquid leak rate(LLR)test per AIO 24.004.The outer annulus was pressured up to 3000 PSI and this pressure was maintained for 30 minutes.Calculated LLR for this test:0.187 gallons per minute. SCANNED SEP_ 2 7 2016 Thursday,February 18,2016 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,January 14,2016 TO: Jim Regg � ' 11 iA/ic<< cI SUBJECT: Mechanical Integrity TestsP.I.Supervisor l BP EXPLORATION(ALASKA)INC. L-I05 FROM: Jeff Jones PRUDHOE BAY UN BORE L-105 Petroleum Inspector Src: Inspector Reviewed By: P.I.SuprvJ` '2--" NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN BORE L-105 API Well Number 50-029-23075-00-00 Inspector Name: Jeff Jones Permit Number: 202-058-0 Inspection Date: 1/10/2016 Insp Num: mitJJ160110124730 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min WellLtos Type Inw TVD 6398 - Tubing1 1602 1602 ! 1599 -; 1596 ' � PTD 2020580 LType Test SPT'Test psi r 1600 - IA 488 4202 - 4131- 4114 - Interval REQVAR iP/F P ✓ OA , 837 802 - I 839 855 - Notes: MIT-IA to 4000 PSI per AOGCC AIO 24.004.3.4 BBLS diesel pumped. 1 well inspected,no exceptions noted. SCANNED ;+ '-, Thursday,January 14,2016 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Re DATE: Thursday,January 14,2016 gg — I'14 JI1, P.I.Supervisor ~ ("( SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. L-105 FROM: Jeff Jones PRUDHOE BAY UN BORE L-105 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry JCS NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN BORE L-105 API Well Number 50-029-23075-00-00 Inspector Name: Jeff Jones Permit Number: 202-058-0 Inspection Date: 1/10/2016 Insp Num: mitJJ160110125623 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well L-105 - Type Inj W 1TVD 6398 Tubing 1599 - 1599. 1599 - 1603 PTD 1 2020580 - Type Test SPT Test psi 1600 IA 693 697 703 709 Interval REQvnR P/F P ✓ OA 462 3040 - 3003 , 3000 , Notes: Liquid leak rate(LLR)test per AIO 24.004.The outer annulus was pressured up to 3000 PSI and this pressure was maintained for 30 minutes.Calculated LLR for this test:0.187 gallons per minute. SCANNED : ,; J;r Thursday,January 14,2016 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday,April 10,2015 TO: Jim Regg "Gly 4I 1)115 P.I.Supervisor r ( SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC L-105 FROM: Bob Noble PRUDHOE BAY UN BORE L-I05 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry lee__ NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN BORE L-105 API Well Number 50-029-23075-00-00 Inspector Name: Bob Noble Permit Number: 202-058-0 Inspection Date: 4/3/2015 Insp Num: mitRCN150406150545 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min L-105 T W, 6398 f 1556 1564 f 1563 1570 -T Well Type Inj t _TVD Tubing PTD , 2020580 Type Testi SPT Test psi l 4000 IA 1 661 . 4100 •d 4043 ' 4043 • j IntervalMOTHER 13/F I PVI OA 889 , 641 559 455 . Notes: AAS 04-1 yr MIT-IA to 4000 psi and LLR LLR .. 374 gpm at 3000 psi for 30 mm. 1 SCANNEIC) . , _ t. Friday,April 10,2015 Page 1 of 1 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Friday, April 03, 2015 7:22 PM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M IL;AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan;AK, D&C Wireline Operations Team Lead;AK, D&C Well Services Operations Team Lead;AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad LV;Wallace, Chris D (DOA); Shrider, James; Sternicki, Oliver R 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; Regg, James B (DOA) Subject: OPERABLE:Injector L-105 (PTD #2020580)AOGCC MIT-IA Passed Attachments: image001 jpg; image002.png; image003.png All, Injector L-105 (PTD#2020580) passed an AOGCC witnessed MITIA on 04/03/2015. The passing test confirms two competent barriers in the wellbore. The well is reclassified as Operable. Please call with any questions. Thank you, Kevin Parks (Apel nate Lawrie Clinicr' SCANNED I BP Alaska -Well Integrity Coordinator b� GINGlobal Wells Organization Office: 907.659.5102 WIC Email:AKDCWelllntegrrtyCoordinator@bp corn From: AK, D&C Well Integrity Coordinator Sent: Friday, March 13, 2015 4:13 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad LV; 'chris.wallace@alaska.gov'; Shrider, James; Sternicki, Oliver R 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; 'jim.regg@alaska.gov' Subject: UNDER EVALUATION: Injector L-105 (PTD #2020580) Put on Injection for Regulatory Compliance Testing All, WAG Injector L-105 (PTD#2020580) was due for regulatory compliance testing on January 18, 2015 (AA 24.004).The well was shut in until nearby drilling activities were complete and is now available to be brought online for compliance testing.This well is reclassified as Under Evaluation. Use caution while placing the well on injection due to fluid packed annuli and the likelihood of annular fluid expansion. Plan forward: 1. Operations: Place well on water injection 2. DHD: Perform AOGCC witnessed MIT-IA and MIT-OA Liquid Leak Rate once well is thermally stable Please call with any questions or concerns. Thank you, Whitney Pettus (Alternate: Kcvai Parks) BP Alaska-Well Integrity Coordinator G�f j G 1 Wens Y•7Yr Orgt,naat:on WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@BP.com From: AK, D&C Well Integrity Coordinator Sent: Wednesday, January 07, 2015 11:26 AM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M IL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad LV; 'chris.wallace@alaska.gov'; Oshiro, Joleen; 'Regg, James B (DOA) (jim.regg@alaska.gov)' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R Subject: RE: NOT OPERABLE: Injector L-105 (PTD #2020580) Due for Regulatory Compliance Testing All, WAG Injector L-105 (PTD#2020580)is due for regulatory compliance testing on January 18, 2015 (AA 24.004).The well is currently not available due to being shut in for nearby drilling activities.At this time,the well has been reclassified as Not Operable until available for online testing.The well has been added to the Quarterly Not Operable Injector Report, and will be tagged appropriately. Please call with any questions. Thank you, Laurie Climer (Alternate:Jack Dishron') BP Alaska-Well Integrity Coordinator G1NG'o3�al Wells Y Y Orgarzaron WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@BP.com 2 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Friday, March 13, 2015 4:13 PM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M TL;AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead;AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr;AK, OPS Well Pad LV;Wallace, Chris D (DOA); Shrider, James; Sternicki, Oliver R 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; Regg,James B (DOA) Subject: UNDER EVALUATION:Injector L-105 (PTD#2020580) Put on Injection for Regulatory Compliance Testing Attachments: image001jpg; image002.png All, WAG Injector L-105 (PTD#2020580) was due for regulatory compliance testing on January 18, 2015 (AA 24.004).The well was shut in until nearby drilling activities were complete and is now available to be brought online for compliance testing.This well is reclassified as Under Evaluation. Use caution while placing the well on injection due to fluid packed annuli and the likelihood of annular fluid expansion. Plan forward: 1. Operations: Place well on water injection 2. DHD: Perform AOGCC witnessed MIT-IA and MIT-OA Liquid Leak Rate once well is thermally stable Please call with any questions or concerns. Thank you, Whitney Pettus (.-1Iternate: Kevin Parlcc) SCANNED m n s BP GW -Well Integrity Coordinator GMMGrob Weis U'gx-Dram WIC Office: 907.659.5102 WIC Email: AKDCWelIIntegrityCoordinatorPBP.com From: , =: - A -II Integrity Coordinator Sent: Wednesday, Jan . - 17, 2015 11:26 AM To: AK, OPS GC2 OSM; AK, OP t.- Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad LV; 'chris.wallace@alaska.gov'; Oshiro, Joleen; 'Regg, James B (DOA) (jim.regg@alaska.gov)' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R Subject: RE: NOT OPERABLE: Injector L-105 (PTD #2020580) Due for Regulatory CompliartceTesting All, 1 r ( (, Image Project 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. ~Dd..... - () 5-15 Well History File Identifier Organjzjng (done) 0 Two-sided 1111111111111111111 ~esca n Needed 1111111111111111111 RES CAN ~olor Items: ~reYSCale Items: 0 Poor Quality Originals: D~AL DATA 1Jf Diskettes, No. 0 Other, NofType: OVERSIZED (Scannable) 0 Maps: 0 Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) 0 Other: 0 Logs of various kinds: NOTES: Scanning Preparation 3 x 30 = 16 0 Other:: , Date/Óp: ot IfJ MP . / 1111111111111111111 I P Date to. a-, oq-- Isl V1f' + ¡.S- = TOTAL PAGES) oÇ (Count does ..1.. at ¡delude cover s~?f9t ..(J Date: to" ()- VL( /s/ V vþ' , 1111111111111111111 BY: Helen ~ Project Proofing BY: Helen (Mar~a) BY: Helen ~ Production Scanning Stage 1 Page Count from Scanned File: I t>fo (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES I Helen ~. Date: ID/:?¡tJIf If NO in stage 1, page(s) discrepancies were found: YES NO BY: NO Isl m P Stage 1 BY: Helen Maria Date: /s/ Scanning is complete at this point unless rescanning is required. 111111111111111 ReScanned 11111111"111 ' III BY: Helen Maria Date: /s/ Comments about this file: Quality Checked 1111111111111111111 8/24/2004 Well History File Cover Page.doc OF To, I 7s,, THE STATE Alaska Oil and Gas OfALAsKA Conservation Commission wh GOVERNOR SEAN PARNELL 333 West Seventh Avenue gP Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Joleen Oshiro atit* A, 20 `L`C�1 . Petroleum Engineer BP Exploration (Alaska), Inc. 0 SS P.O. Box 196612 Anchorage, AK 99519-6612 �O Re: Prudhoe Bay Field, Borealis Oil Pool, BRLS L-105 Sundry Number: 313-644 Dear Ms. Oshiro: 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, Vez p Cathy P.y erster Chair DATED this?day of January, 2014. Encl. ,tet RECEIVED • STATE OF ALASKA v1, DEC Q,3 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 'QTS !3 20 AAC 25.280ACK,LM 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑� • Alter Casing❑ Other. ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number BP Exploration(Alaska),Inc. Exploratory ❑ Development ❑ 202-058-0 • 3.Address: Stratigraphic ❑ Service ❑✓ . 6.API Number. P.O.Box 196612,Anchorage,AK 99519-6612 50-029-23075-00-00 - 7.If perforating: 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? BRLS L-105 - Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0028238 • PRUDHOE BAY, BOREALIS 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): 8360 • 6852 - 8267 6772 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"91.5#H-40 29-109 29-109 Surface 2827 9-5/8"40#L-80 29-2856 29-2635.92 5750 3090 Intermediate None None None None None None Production 8326 7"26#L-80 25-8351 25-6844.29 7240 5410 Liner None None None None None None Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment 4-1/2"12.6#L-80 L-80 23-7885 Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD(ft)and TVD(ft): See Attachment for Packer Depths 4-1/2"MCX I-SSV 2194'•2125.04' 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program Q BOP Sketch ❑ Exploratory ❑ Development ❑ Service ❑Q • 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG Q • Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Joleen Oshiro Email Joleen.Oshiro@BP.Com Printed Name Joleen Oshiro Title Borealis PE Signature 0 hone 564-4606 Date Prepared by Garry Caton 564-4424 IVIX113 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. '3`' (..a-s"- Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBDM-z: MAY 0 9 2014 Spacing Exception Required? Yes ❑ No Subsequent Form Required: /0 – 10 4 ' APPROVED/BY Approved by: vs.„____ COMMISSIONER THE COMMISSION Date: /—7 `/V . Form 10-403 Revised 10/2012 QrR4c44ijiaLior 12 months from the date of approval. Submit Form and Attachments in Dupli fe r • Packers and SSV's Attachment ADL0028238 Well Facility Type MD Top Description TVD Top L-105 _ SSSV 2194 4-1/2" MCX I-SSV 2125 L-105 PACKER - 7646 4-1/2" Baker Premier Packer 6248 L-105 PACKER 7828 4-1/2" Baker S-3 Perm Packer 6398 • by 0 To: C. Olsen/T. Norene Date: Dec 12, 2013 J. Bixby/R. Liddelow From: Joleen Oshiro Production Engineer, 650-483-4774 AFE: Subject: L-105i Fluff'n Stuff and Acidizing Est. Cost: Est. IOR: Reviewed By: Michael Hibbert, Interventions Engineer Step Unit Operation 1 S Pull MCX from 2194' MD 2 C Baseline injectivity test down prod tbg. Fluff'n stuff(target clean out depth= 8125' MD). 2nd injectivity test down prod tbg. Jet acid across perfs. Final injectivity test down prod tubing. Current Status: WAG injector, online Recent PW Injectivity: 4/7/13: 2200 bwpd @ 1500 psi WHIP Max Deviation: 46° at 6446' MD Minimum ID: 3.725" @ 7873' MD (HES X Nipple) Last Downhole Op: 12/3/13: SL drift, pull and re-set MCX at 2194' MD..performed good drawdown test SBHT/BHP 3000 psi, 158 degF....estimate from offset producers, 6600' TVD datum Last Tag: 12/3/13: 8024' corr MD (SL, 3.25" centralizer) Latest H2S: 25 ppm (1/2013)...Nearest producer L-106 Job Scope: The primary objective of this program is to increase the injectivity of L-105. Coil Tubing will perform a Fluff 'n Stuff to clear the fill that is covering -90% of the perforations. This will be followed up by jetting the perforation intervals with 90:10 DAD acid. Background Information: L-105 is a WAG injector that was completed in 2002. It injects into the Kuparuk reservoir, and it supports L- 107, L-104, and V-102. It has a straddle packer completion across the squeezed off Schrader Bluff (viscous oil reservoir) perforations. L-105 has never injected into the Schrader Bluff. After pigging returns were dumped down L-105 in 11/2012, the injectivity index of the well decreased considerably. The last tag in 12/2013 indicated that there is fill covering 90% of the perforations. A caliper survey performed on 11/28/11 indicated that the highest wall penetration was 21% at 7578' MD. Tubing pressure derating calculations indicate the potential for tubing to burst at 6400 psi; therefore, it is not required to hold pressure on IA while pumping down tubing. However, it is okay if there is IAP. Tubing movement calculations indicate no problems at the proposed pumping conditions. There is a risk of trapped annular pressure between the straddle packer completion that will be mitigated by monitoring the IA pressure during the job. The most recent MIT-IA passed at 4150 psi on 1/20/13. . There is an MCX at 2194' MD that SL will need to pull. The OA pressure stabilizes out at 1000-1100 psi; the source of the OA pressure is a hydrate zone through its open shoe. Please contact Joleen Oshiro at 564-4606 (w), 650-483-4774 (c) if there are any questions or comments. Design Details: Existing Perforations MD Top MD Bottom Height 8012' 8074' 62' 8104' 8110' 6' Total Perf Footage 68' of perfs Wellbore Volume 125 bbl to top of perfs IA Volume 142 bbl to top packer Maximum WHIP 4000 psi Maximum IA pressure 2000 psi Recent Injectivity 1.6 bpm at 1600 psi (equivalent to 2300 bwpd) Target Injectivity , 4 bpm at 2400 psi (equivalent to 5800 bwpd) Risks & Discussion • A sundry will be required for the stimulation of this injector. • The ideal cleanout depth would be 8125' MD. The total volume of fill to be fluffed and stuffed away is -4 bbls. • SBG is a basic solution, and it can create a hazardous condition when mixed with HCI. Avoid commingling these fluids on surface and use large 1% KCL spacers when changing from one to the other during the course of the job. • There is a risk of trapped annular pressure between the straddle packer completion (7646'-7828' MD) that will be mitigated by monitoring the IA pressure during the job. • Estimated Fluid Summary o 50 bbls 90:10 DAD acid (SIBHT= 160degF, L-80 tbg/csg)..recommended recipe at the end of the program o 200 bbls SBG o - 720 bbls of 1% XS KCL o - 35 bbls neat methanol 2 of 7 • Slickline- Pull MCX 1. MIRU SL. Pull MCX at 2194' MD. There is no need to re-set an MCX, as the well will continue to be on PWI. CT- Fluff n' Stuff, Acidizinq 1. MIRU 1.75" CT. MU standard FCO BHA with JSN. 2. Open well and line up to pump down the production tubing. Spear in with 5 bbl neat methanol. Perform baseline injectivity test with 1% KCI at the rates in the table below. Hold each rate for at least 5 minutes. Record rates and pressures after pressure has somewhat stabilized at each rate. Maximum pump pressure= 4000 psi. Total anticipated fluid required for injectivity test = 65 bbls of 1% KCI Rate 1 bpm 2 bpm 3 bpm 4 bpm 3. Pump 10 bbls neat methanol into the production tubing. This will keep the production tubing freeze protected during the jetting and fluff and stuff operation. 4. Jet SBG down the coil at maximum rate from surface to 7895' MD with SBG to a closed choke. 5. At 7895', shut down pump, continue RIH, and dry tag fill. 6. Perform fluff n' stuff to at least 8125' MD. Use SBG while jetting and 1% XS KCI while chasing up through perfs. Follow recommended practices for Fluff n' Stuff in the "Alaska Wells Recommended Practice-Cleanout Procedures". • Swap to DJN if needed • May need to motor and mill if unable to jet through fill. NOTE: During the fluff n stuff, SBG will be soaking in the tubing to clean any remaining tubing schmoo. The SBG will be displaced into the formation once the fluff n stuff is completed. 7. Fluff n' Stuff target depth is 8125' MD. After target depth is achieved, PUH above perfs while the SBG soaks for-1-3 hrs. Freeze protect the coil as necessary. 8. Bullhead 120 bbls of 1% KCI down the production tubing at maximum rate to flush all the SBG from the tubing prior to the acid step. Slowly PUH while pumping down the production tubing to keep the coil moving. 3 of 7 9. Perform 2nd injectivity test with 1% KCI to understand the benefit of the fluff and stuff step. Perform injectivity test at the rates in the table below. Hold each rate for at least 5 minutes. Record rates and pressures after pressure has somewhat stabilized at each rate. Maximum pump pressure= 4000 psi. Total anticipated fluid required for injectivity test = 65 bbls of 1% KCI Rate 1 bpm 2 bpm 3bpm 4 bpm 10. At WSL discretion, pump 10 bbls neat methanol to freeze protect the production tubing during the acid step. 11. Displace the coil with 1% KCI while preparing for the acid step. 12. Pump 5 bbl neat methanol spear followed by 50 bbl 90:10 DAD acid. Jet acid across the perforation intervals: • 8012'-8074' MD • 8104'-8110' MD After jetting the acid, PUH above the perforations and allow acid to soak for 15-30 minutes, depending on ambient conditions. SIBHT= 160 degF. (DAD acid recipe is at the end of the procedure) 13. After soak period, pump —200 bbls of 1% KCI while RBIH to overdisplace the acid from the near wellbore and sump. Pump KCI down coil and production tubing at WSL discretion. POOH. 14. Once at surface, perform final injectivity test down the production tubing with 1% KCI to understand the benefit of the acid step. Perform injectivity test at the rates in the table below. Hold each rate for at least 5 minutes. Record rates and pressures after pressure has somewhat stabilized at each rate. Maximum pump pressure= 4000 psi. Total anticipated fluid required for injectivity test = 65 bbls of 1% KCI Rate 1 bpm 2 bpm 3 bpm 4 bpm 15. RDMO and hand the well over to the pad operator to POI at target rate of 4000-5000 bwpd. Maximum PW injection pressure= 3500 psi. 4 of 7 • TREE= 4-1/16"ON SAFETY NDTE1: FIt31E401NG8 AVERAGE 125 ppm AELLFEAR• FNS L-1 O5 MESON MI.WELL PEIOINRESASSSVWHEN ON KB LLLV 78 B' • — BF ft FV - 74$4 . �--- 960' 9-518'TAM FORT COLLAR tMx 46 =ie An9 ° 8446' +� Oahrm4lD= 8158' ( 211 ' H41t2 FESXNF?ID=3813' DatumPVD= 6600 SSI G-5/8'CSG,400. L-80 BTG,ID=8.835' 2856' GAS LIFT M4NDRES ST MD "VD DEV *Y PE VLV L.ATC+I PORT DATE 3' 3966 3489 41 KBO-2 COW SK 0 12125111 2 5286 4498 42 K8G-2 OW 81c 0 07120802 't 756E 6186 37 K61G-2 OMY 8K 0 10113802 !Minimum ID =3.725" 7873' 4-1I2" HES XN NIPPLE 7635' F£SXRP, =3.1117 g � 7646' l IT'X4-1i2'BKR PREMI D=3.8W 1 7317" H 4-117 HES XNP,10+3.813 I 7828' --,T'X 4-1/7 ex S-3 PKR.ID=3 875 I 7852' —4-1/7 HES P IOO=3 81.3.-' 412'TBG 12 5M. _430 TGI, — 7884' 0152 oaf.!D=3 SST [ _7873'_4-1.7"HFS XN JP fi=3 775 _ PERFORA TON SUMMARY ` - j 7885' 4-112"WLBG,K?=3.969 I REF LOG SQUEEZE FERc RECORD AN3LE AT TOP PERF. 34"it 7700' — 7904' Hr MARKER JOINT wl RSR TAG Note.Refer to Pfodu tiara OB for hislorioel 7erf dais SIZE SPF INTERVAL O ril&z DOTE 4-12' ' 6 7700-7722 S 07117/02 4-1/2' 6 7785-X805 S 0771112 3-310' 1r 6 0012-6032 O 08118102 4112' F 6 8023.0043 0 07117802 3-10' G 0040-0074 0 081181(17 80+45' V MARKER JON-- Ri.'AG 3-318" ir 6 8104-13110 0 05107/02 PBTD — 6267" *4.4•�e4'!'�'�ei'4'� 4)4404444/444 r CSG,281 L 80 BTG 4 0383 bpr,0.8 278' — 835& 5 of 7 bp 90:10 DAD - recommended additive concentrations lik Temperature Low Medium High (ambient to 175 F) (175 F to 225 F) (225 F and up) Completion metafurgyP LSO 13Cr L8O 13Cr L80 13Cr Loading for 2% HCI 12% 12% 12% 12% 12% Product Code Function Units HCl HCI HCl HCl HCl A264 Acid Corrosion Inhibitor GalIMgal 4 4 6 6 6 8 A201 Inhibitor Aid Gal/MgaI 0 0 15 40 15 60 A153 Intensifier Ib(Mgal 0 0 0 5 10 10 F103 Flowback Aid Gal/Mgal 2 2 2 2 2 2 L058 iron Control IbIMgal 20 20 20 20 20 20 W054 Anti emulsifier GaliMgal 5 5 5 5 5 5 U067 Mutual Solvent Gal!Mgal 0 0 0 0 0 0 A026 Xylene GallMgal 100 100 100 100 100 100 U074 Emulsifier Gal:Mgal 15 15 15 15 15 15 The recipes above are agreed recipes from 2010 BP- SLB acrd forum 6 of 7 Y, 1-105 Injectivity Index 9 8 6 S , Im 1 4 I 3 ilk , I ` � . �Z •miil1Lig►1 . ► l '1 .4 �P3 i !� i II ii 1IF , ' Or -,- -r 1 l''''' T --7 -r_...__ T- _, OO1 00''' e e e h e OOo 000 ds43 e 00 e e a 00 Otio o<,ti o,,t. 0 ~ Yrye� gyp\1 ~\� � 3 3 �~ o � ~ ry \ \ ' \ * O,\ \ \. k. \. \ \'1, %. > \ \-. 030 \-.. %.• 0N.. bOOL OdbOO1 Ob O O� oti\ 0`' O°' otiO' oa0' o° OWo' O' 0 • o° �o I 7 of 7 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, January 23, 2013 TO: Jim Regg P.I. Superv C � % z ' I SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC L -105 FROM: Chuck Scheve PRUDHOE BAY UN BORE L -105 Petroleum Inspector Src: Inspector Reviewed B y: P.I. Supry -.IC( NON - CONFIDENTIAL Comm Well Name PRUDHOE BAY UN BORE L -105 API Well Number 50- 029 - 23075 -00 -00 Inspector Name: Chuck Scheve Permit Number: 202 -058 -0 Inspection Date: 1/20/2013 Insp Num: mitCS130122074257 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min _ Well L -105 1 Ty pe a In J • I TVD 6248 IA 890 4141 4065 ., 4054 PTD T e Test Test psi � OA 950 9 36 970 988 - I ' 4000 1950 1980 -i 1980 1980 i 2020580 Yp SPT � es p I Interval 'PT P Tubing Notes: Annual MITIA per AA AIO 24.004. Attempted LLR -OA, while OA showed consistent leak an acurate rate could not be established with equipment on location. SCANNED _APR 11 2013 Wednesday, January 23, 2013 Page 1 of I . • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, February 01, 2012 TO: Jim Regg . P.I. Supervisor 4 lt Z' SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC L -105 FROM: Chuck Scheve PRUDHOE BAY UN BORE L -105 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry j�� NON - CONFIDENTIAL Comm Well Name: PRUDHOE BAY UN BORE L - 105 API Welt Number: 50- 029 - 23075 -00 -00 Inspector Name: Chuck Scheve Insp Num: mitCS120129174842 Permit Number: 202 - 058 - Inspection Date: 1/28/2012 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well L-105 .iType Inj. W TVD 6248 ' IA 656 3955 , 3895 3877 - P.T.D 2020580 ' TypeTest SPT Test psi 1562 - OA 800 845 796 820 Interval REQVAR P/F P , Tubing 1289 1300 1288 1287 Notes: Annual MIT required by AIO 24.004 FEB WOWED t a 611- Wednesday, February 01, 2012 Page 1 of 1 Pt L -105 • • PN> Z;z. Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] Sent: Friday, January 27, 20 12 5 :40 AM To: Regg, James B (DOA) Cc: AK, D &C Well Integrity Coordinator; Daniel, Ryan; Schwartz, Guy L (DOA); Maunder, Thomas E (DOA) Subject: L -105 (PTD #2020580) and X -24 (PTD #1991250) UIC Compliance testing Jim, a/ Injector L -105 (PTD #2020580) was due for its annual AOGCC state witnessed MIT -IA on 01/18/12 and Injector X -24 (PTD #1991250) was due for its four year AOGCC MIT -IA on 01/22/12. Injector L -105 (PTD #2020580) passed an MIT -IA pre -test to 4000 psi on 01/03/12 and Injector X -24 (PTD #1991250) passed an MIT -IA pre -test to 2750 psi on 01/02/12. The slope state inspector was contacted early last week and notified of the due dates for both injectors. However, we have been unable to perform the AOGCC state witnessed MIT-lAs for these injectors due to the limited availability of the state inspector and weather shut downs on the slope. As soon as weather conditions permit, the AOGCC state witnessed MI -IAs will be schedule and performed. Please let me know if you have any questions. Thank you, Whitney King filling in for Mehreen Vazir (Alternate. Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWeIIIntegrityCoordinator @BP. FEB StAitiNED c 8 2U Z 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Wednesday, March 02, 2011 Jim Regg l P.I. Supervisor 'J 3 ` 3 // SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC L -105 FROM: John Crisp PRUDHOE BAY UN BORE L -105 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry -VP-- NON CONFIDENTIAL Comm Well Name: PRUDHOE BAY UN BORE L - 105 API Well Number: 50 029 - 23075 - 00 - 00 Inspector Name: John Crisp Insp Num: mitJCr110221072324 Permit Number: 202 - 058 - Inspection Date: 2/20/2011 - Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ' L -105 ' Type Inj. W ' TVD 6248 ' IA 984 2500 2471 I 2459 ' P.T.D 2020580 'TypeTest 1 SPT Test psi 1562 ' OA 918 913 945 - 963 — Interval REQVAR p/F P Tubing 2100 2100 2100 2100 Notes: High OA pressure. 1.1 bbls pumped for test. - Wednesday, March 02, 2011 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ZR I DATE: February 03, 2011 P. I. Supervisor � � li p FROM: Lou Grimaldi SUBJECT: Liquid Leak Rate test Petroleum Inspector BP Exploration Z, 05 ' PBU L -105 0 Prudhoe Bay Unit Borealis Thursday, February 3, 2011; I witnessed the Liquid Leak Rate (LLR) on well the Outer , Annulus of well L -105 in the Borealis field. This test is required by Administrative Approval AIO 24.004 which calls for this test as v well as an annual MIT IA which had been reported as witnessed previously by AOGCC John Crisp. I met Jason Brenny on Location and after a brief procedure meeting the LLR test was began. The OA pressure of 960 psi was bled to a bleed trailer which was all gas and bled down to 50 psi quickly indicating fluid fairly close to surface. Twenty two gallons of diesel was i pumped to raise the OA pressure to 3000 psi. For the next thirty minutes another twenty gallons of diesel was pumped to maintain the OA pressure at 3000 psi. A LLR was calculated at .73 gallons per minute. Attachments: None Non - Confidential Al R 4 WI MIT LLR PBU BOR L -105 03 -03 -11 LG.doc 1 of 1 MEMORANDUM To: Jim Regg P.I. Supervisor C ~~ lr-~~O f Q~ FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, November 02, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC L-]OS PRUDHOE BAY UN BORE L-105 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~'~~ Comm Well Name: PRUDHOE BAY iIN BORE L-105 Insp Num: mitCS091030155753 Rel Insp Num: API Well Number: 50-029-23075-00-00 Permit Number: 202-058-0 Inspector Name: Chuck Scheve Inspection Date: IO/30/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. L-1os ~ ~ YP J Well ~T e In_ ~ ~ TVD d t r 440 r 4000 ~ ~ bias i IA ~ 1 ~ -- -- --- 3940 ~ 3940 ~ _ 2020580 "~T eTest SPT ; Te I I> 'I` D; YP S p - --- --- 1562 ,/r OA 1060 1060 ~ ~ ----- ~----- 1060 ~ 1060 j - - - -_- _ _ - ~~_-____--T-~ --__.-___ , REQVAR P / Interval P/F - ----- --- Tubin ~I 2250 2250 g - ~-- --------1- ---- ~- 2250 ~ 2250 ----- ~ -----~ - - Notes' Yearly test required by AA#24.004 i i~ ~ '"' r~~~4j~~ ry [ ~ iii Monday, November 02, 2009 Page 1 of 1 ~ BP Expioration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 t~~.rw`~..~~C::~ ;~' `.' t ~ ~~ii~ August 14, 2009 n 1._J bp ~~ ~~~~~ Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7t" Avenue Anchorage, Alaska 99501 0 C T 0 5 2009 ~iaska ~il ~ Gas Cons. Gam~mis~ion Anchorage Subject: Corrosion Inhibitor Treatments of GPB L-Pad ~~~~,Q~ Dear Mr. Maunder, i•~, C(~~ L~ Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB L- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. 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 require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator ~ ~ BP Exploration (Alaska ) inc. Surtace Casing by Conductor Mnulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operationa (10at04) Date L pad S/13/2009 Well Name PTO # API # Initial to of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitod sealant date ft bbls ft na al 1-01 2010720 50029230110000 NA 6 NA 612 6/25/2009 L-02A 2041490 50029230480100 NA 1.4 NA 14.5 6/27/2009 L-03 2051030 50029232690000 NA 2.8 NA 24.7 6/25/2009 L-04 2061200 50029233190000 NA 1.7 NA 15.3 6/25/2009 L-100 1980550 50029228580100 NA 6.2 NA 57.8 6/29/2009 L-101 1980320 50029228650000 NA 3.3 NA 30.6 6/29/2009 L•102 2020360 50029230710000 37' NA Need To Job? NA L-103 2021390 50029231010000 NA 1.6 NA 10.2 6/26/2009 L-104 2012380 50029230600000 NA 3.5 NA 47.6 5/6/2009 L-105 2020580 50029230750000 NA 1.75 NA 24.65 5/6/2009 L-106 2012230 50029230550000 NA 2.75 NA 28.05 5/6/2009 ~-107 2011510 50029230360000 NA 4.8 NA 57.8 5/6/2009 L-108 2021090 50029230900000 NA 12 NA 13.8 6/25/2009 L-109 2012010 50029230460000 NA 2.9 NA 32.3 6/27/2009 L-110 2011230 50029230280000 NA 27 NA 3162 6/29/2009 L-111 2020300 50029230690000 NA 4.7 NA 54.4 6/29/2009 L-112 2022290 50029231290000 NA 5.5 NA 51 6/27/2009 L-114A 2051120 50029230320100 NA 2.5 NA 25.5 6/29/2009 L-115 2011400 50029230350000 NA 0.5 NA 3.4 6/27/2009 L-116 2011160 50029230250000 NA 5 NA 54.4 6/26/2009 L-117 2011670 50029230390100 NA 2.9 NA 28.9 6/27/2009 1-118 2011870 50029230430000 NA 1.4 NA 15.3 6/27/2009 L-119 2020640 50029230770000 NA 2.25 NA 28.9 5/6/2009 L-120 2020060 50029230640000 NA 0.75 NA 6.8 5/5/2009 1-121A 2030390 50029231380100 NA 22 NA 25.5 6/27/2009 L-122 2030510 50029231470000 NA 2 NA 20.4 6/27/2009 L-123 2051940 50029232900000 NA 2 NA 18.7 6/27/2009 L-124 2050430 50029232550000 NA 1.8 NA 17 6/27/2009 L-200 204~U1~ 50029231910000 NA 1.8 NA 13.5 6/26/2009 L-201 2040460 50029232020000 NA 1.75 NA 15.3 5/6/2009 1-202 2041960 50029232290000 NA 2 NA 17 6/26/2009 L-204 2060920 50029233140000 NA 1.5 NA 5.95 5/6/2009 1.-205 2080530 50029233880000 NA 1 NA 12.75 1/10/2009 L-210 2031990 50029231870000 NA 325 NA 31.4 5/5/2009 1-211 2040290 50029231970000 NA 1.9 NA 17 6/27/2009 L-212 2050300 50029232520000 NA 1.8 NA 17 6/26/2009 1-213 2060530 50029233080000 NA 2 NA 17 6/25/2009 L-214A 2060270 50029232580100 NA 025 NA 10.2 5/6/2009 1-215 2051270 50029232740000 NA 1.5 NA 30.6 5/6/2009 L-216 2040650 50029232060000 NA 1.3 NA 11.9 6/26/2009 L-217 2060750 50029233120000 late bbckin conductor NA NA L-218 2051190 50029232720000 NA 1.7 NA 15.3 6/27/2009 L-219 2071480 50029233760000 surtace NA NA L-220 2080470 50029233870000 NA 2 NA 20.4 6/28l2009 L-221 2080310 50029233850000 NA 1.7 NA 162 6/25/2009 L-250 2051520 50029232810000 NA 3.4 NA 34 6/26/2009 L-50 2051360 50029232770000 NA 1.8 NA 20.4 6/27/2009 L-51 2060590 50029233090000 NA 1.8 NA 17 6/27/2009 MEMORANDUM To: Jim Regg ~ ;,G. l (;~2-Q' ~1~~ P.I. Supervisor "~ (, FROM: John Crisp Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Thursday, October 09, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC L-105 PRliDHOE BAY LJiV BORE L-105 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Supr~~~`- Comm Well Name• PRUDHOE BAY UN BORE L-105 Insp Num: mitJCr081008112626 Rel Insp Num: API Well Number: s0-029-2307s-00-00 Permit Number: 202-058-o Inspector Name: John Crisp Inspection Date: Ioi2/2ooa Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well L-1os ~ IType Inj. i ~' ,, TVD ~ 6z4s ~ IA 1 ao ~ aozo s96o ~ s9so 2020580 SPT ~ ~ p,T, ~ ~TypeTest ~ Test psi ~ 1562 ~~ , OA ,. 920 ~ 890 ~ 930 ~ 950 i Interval REQVAR p~F P ~ Tubing 1600 ~ 1600 1600 1600 NOtes: 5.6 bbl's pumped for test Thursday, October 09, 2008 Page 1 of I Re James B DOA From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~~~(`1 I(1 Z /L, 7 Sent: Wednesday, November 07, 2007 1:58 PM 1 To: Regg, James B (DOA); Maunder, Thomas E (DOA); Fleckenstein, Robert J (DOA) Cc: NSU, ADW Well Integrity Engineer; NSU, ADW WI Tech Subject: MIT Forms for V-114A (PTD #2031850), Attachments: MIT PBU V-114A 11-03-07.x1s; MIT PBU 14-17A 11-04-07.x1s; MIT PBU L-105 11-03-07.x1s; MIT PBU PSI-01 11-04-07.x1s Jim, Tom and Bob, Please see the attached MIT forms for the following wells: V-114A (PTD #2031850) MITIA for upcoming AA request ,~~~~~~~ ~~~ ~ ~ ~QQ~ 14-17A (PTD #2030010) MITIA for 4-year regulatory compliance -105 (PTD #2020580 i~/IITIA and LLR-OA for AA compliance PSI-01 (PTD #2021450) MITIA for 4-year regulatory compliance «MIT PBU V-114A 11-03-07.x1s» «MIT PBU 14-17A 11-04-07.x1s» «MIT PBU L-105 11-03-07.x1s» «MIT PBU PSI-01 11-04-07.x1s» Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 11 /7/2007 STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us; Tom_Maunder@admin.state.ak.us OPERATOR: FIELD /UNIT !PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. Prudhoe Bay / PBU / L pad 11!04/07 Anna Dube ~~.~~C r~~7~~~ ~ ~ os~ ,~dy Y Packer Depth Pretest Initial 15 Min. 30 Min. Well L-105 Type Inj. W TVD 6248 Tubing 1850 1850 1850 1850 Interval O P.T.D. 2020580 Type test P Test psi /4000 Casing 420 /4000 3960 3940 P/F P Notes: MIT-IA for AA compliance. OA 880 850 860 880 A'~ z4, OOq- Well L-105 Type Inj. W TVD 6248 Tubing 1710 1710 1710 1710 Interval O P.T.D. 2020580 Ty a test P Test psi ;3000 Casing 20 30 30 30 P/F Notes: LLR-OA for AA compliance = .38 gpm. OA 880 3000 3000 3000 Weil Type Inj. TVD Tubing interval P.T.D. T pe test Test psi Casing P!F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Weil Type Inj. TVD Tubing interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas 1 =Industrial Wastewater N =Not Injecting W = Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) l y ~ ~ ~9~-,0(3~(- C(.~/L~(si,~ a~~,~N~ ~ /~`u ~5: \ ~,y1 ~cic~Q.~ l~ MIT Report Form BFL 9!1/05 MIT P6U L-105 11-03-07.x1s STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to; Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us; Tom_Maunder@admin.state.ak.us OPERATOR: BP Exploration (Alaska), Inc. FIELD / UNIT I PAD: Prudhoe Bay /PBU / V pad DATE: 11/03/07 ~~~~~ ~~~~~~~ OPERATOR REP: Anna Dube AOGCC REP: Packer Deptki ~ Pretest Initial 1 S Min. 30 Min. Well V-114A Type Inj. W TVD 6563' Tubing 2400 2400 2400 2400 Interval O P.T.D. 2031850 Type test P Test psi 4000 Casing 1080 4000 3940 3940 P/F P Notes: MIT-IA for upcoming AA request. OA 550 550 550 550 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes; OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A - Terperature Rnornaly Suvey D =Differential Temperature Test ~. INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 9(1 /OS M(TPBU V-114A 14.03-07.x1s MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor ---? 1<l1f I z(r51C(, ( DATE: Wednesday, December 13,2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) fNC L-I05 PRUDHOE BAY UN BORE L-105 Src: Inspector 'J.ß:J.: 0 5~ FROM: Chuck Scheve Petroleum Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ,,-~íZ-- Comm Well Name: PRUDHOE BAY UN BORE L-105 API Well Number 50-029-23075-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS06I2I20550I3 Permit Number: 202-058-0 Inspection Date: 12/11/2006 ReI Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ._----. IType Inj. ¡'wT TVD -r~48-----;iAr I I I -- Well , L-(05 640 I 4000 3960 3940 , i -_..._----~.._.."._-~-,--_.--~- I -~~ P.T. 2020580 !TypeTest : SPT : Test psi ! 1562 OA 1000 980 i (000 i 1060 i I ì ~ -- --- REQVAR ./ Tubing I 1490 1490 , 1490 1490 Interval PIF P , i ------ -- ----~-------------'------_._------- .--- Notes Pretest pressures observed and found stable. Well has a variance for OA repressurization. /' p.,J;6 24-, Ce4 regc__u ir-èS ~^wJL .l-D:--r=4\ hf" ~À.\À''t:: rr~1¡ .;',,",~~~'~~;¡50~ 2«} Wednesday, December 13,2006 Page I of I • FRANK H. MURKOWSKI, GOVERNOR ~' 333 W. 7~" AVENUE. SUITE 100 ANCHORAGE, ALASKA 9950-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATNE APPROVAL AIO 24.004 Mr. Steve Rossberg, Wells Manager a y BP Exploration (Alaska) Inc. >`.:'--h~'~ ~~N ~ ?~~~ 900 East Benson Blvd. P.O. Box 196612 Anchorage, AK 99~ 19-6612 RE: PBU L-10~ (PTD 202-0~8) Request for Administrative Approval Dear titr. Rossberg: In accordance with Rule 8 of Area Injection Order 024.000, the Alaska Oil and Gas Con- servation Commission ("AOGCC" or '`Commission") hereby grants BP Exploration (Alaska) Inc. ('`BPXA")'s request for administrative approval to inject gas in the subject well. AOGCC finds that BPXA has elected to perform no corrective action at this time on PBU L-10~. The Commission further finds that, based upon reported results of BPXA's diag- nostic procedures, PBU L-10~ exhibits two competent barriers to release of well pressure. Accordingly, the Commission believes that the well's condition does not compromise overall w-el1 integrity so as to threaten the environment or human safety. AOGCC's administrative approval to inject gas in PBU L-10~ is conditioned upon the following: 1. BPXA shall record wellhead pressures and injection rate daily; 2. BPXA shall submit to the AOGCC a monthly report of well pressures and injec- tion rates; 3. BPXA shall perform an annual NIIT - IA to 4000 psi; 4. BPXA shall perform an annual LLR - OA to 3000 psi; ~. BPXA shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; and ~ • 1~1r. Steve Rossberg January 18, 2006 Page 2 of 2 6. after well shut in due to a change in the well's mechanical condition, AOGCC ap- proval shall be required to restart injection. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is consid- ered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may nat appeal a Commission decision to Superior Court unless rehearing has been requested. DONE at Anchorage, Alaska and dated January 1$, 2006. ~~~ !~ / Cat y P Foerster, Daniel T. Seamount, Jr. Commissioner Commissioner ~4' F 1 t I ~ l ~r ~ r ~ t .-` - ~ ~; ..~ n - R ~~ } i i ~. 1S i \ ~`. ~ R I~ ~ ~.9 ~ '. ~~ i `~' ~ J e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Insens\Microfilm _ Marker.doc RE: PBU L-1 05 e R~ z1lql~ ð-o;}-05ª Subject;RE: PBU L-I05 '. ., From: "NSU"ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.eom> . Date: Fri, 16 Dee 2005 16:14:54-0900 , To: Jaìnes Regg <jimjegg@admin.state\~~ql>;Winton GAuD ~~i~~~s~~~~:;~~i~tt~~~~:gi1}~~'¡krÑ;~I!ADWWeli~e Hi Jim and Winton, L-105 has OA repressurization due to shallow hydrates. An OA downsqueeze is not an option at this time due to the liquid leak rate of 0.75 gpm. The rate is too low to be able to pump a squeeze material into the annulus. A request for administrative approval has been mailed. Please let us know if it does not arrive in the next week. Thank you, Anna Dube -----Original Message----- From: James Regg [mailto:jim reqg@admin.state.ak.us] Sent: Monday, December 12, 2005 10:06 AM To: NSU, ADW Well Integrity Engineer Cc: Winton GAubert Subject: PBU L-105 I ~" MIT on PBU L-105 (PTD 2020580) was witnessed by inspector 11/28/05; passed MITIA but noted the well has an open surface casing shoe and the OA repressures from the formation. Looked back through well history and noted we have exchanged emails on this well and BP determined that OA pressure was result of shallow hydrates. On 11/7/2004, we were advised that BP would be requesting administrative approval to increase the operating pressure limits (above 1000 psi for OA). Is OA downsqueeze an option here? Still planning to submit an AA for this well? Jim Regg AOGCC 1 of 1 c 12/19/2005 10:03 AM MEMORANDUM e e State of Alaska Alaska Oil and Gas Conservation Commission FROM: Chuck Scheve PetJ"oleum Inspector DATE: Wednesday, November 30, 2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC L-I05 PRUDHOE BA Y UN BORE L-J05 Da--09Ì ~ TO: Jim Regg P.I. Supervisor Src: Inspector Reviewed By: P.I. Suprv JJ.?€.- Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UN BORE L-I05 API Well Number 50-029-23075-00-00 Insp Num: mitCS05II29I612I4 Permit Number: 202-058-0 ReI Insp Num Inspector Name: Chuck Scheve Inspection Date: I I/28/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ;;~(j-~2~~o--1~~::~~:~~~s~J-~~~:Si]~-~~~-~=Hfl~~-~: --I ~::-=t=~:~~~--l---~~~:~~~~-~~-- --J~ ---~~= -I~t~"';1 ~,;;;. p¡i - . ,.J..... . T;;bi~r- ""I mo r ,;" -! n ,,,our - j -- -- --- _______ _____________________ _______ __~__~_____I~_____~___ __ J____________ Notes This well has an open surface casing shoe and the OA repressures from the formation. ß'%'S I- MM(~S~CA-+'w: ÄffhN~¡\~ DP e~ Wednesday, November 30, 2005 Page I of I L-I05 (PTD #2020580) Classified as Normal Well ) Subject: L-I 05 (PTD #2020580) Classified as Nonnal Well From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com> Date: Sun, 07 Noy 2004 22:09:44 -0900 ) ~OéA-O 57> ,. All, Well L-I05 (PTD #2020580) has been found to have sustained casing pressure on the OA and was classified as a Problem Well. The well has been reviewed and confirmed with the AOGCC that it is not regulated by CO 492 due to being an injector. It has been determined that the cause of the high OA pressure is due to the OA shoe being open to a shallow hydrate formation. A MITIA passed to 4000 psi on 06/24/04, a CITOA passed to 3000 psi on 06/14/04. The well is classified as a Normal Well being as there is no loss of integrity. Thß operating limits remain at 2000 psi on the IA and 1000 psi on the OA. The plan forward is to request administrative approval from the AOGCC to increase the operating pressure limits. The following is a diagnostic history of the well: 06/17/04: PPPOT-T Passed to 5000 psi, PPPOT-IC Passed to 3200 psi 06/24/04: MITIA to 4000 psi Passed State witnessed by John Crisp 10/14/04: Email to AOGCC, notify of high OAP. Left message on Winton's phone recorder. 10/31/04: Samples taken on IA and OA. OA sample is indicative of hydrates. IA sample considerably different from OA sample. Please call if you have any Thank you, Anna Dube Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 xl154 questions. SCANNEr) NOV 1 8 2004 1 of 1 11/8/2004 10:36 AM RE: Problem Well Notification: L-I05 (PTD #2020580) ") Subject: RE: Problelll Well Notification: L-I05 (PTD #2020580) From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com> Date: Wed, 20 Oct 2004 19:58:54 -0800 To:'. JamesRegg <jim_regg@admin~state~ak.us> . ,': .' .. ,.:... . .' .. :' . .., . . C(;::. "NSU,AD'W Well: Integrity:ErigiIieer" <NSUADWWellIrit~grityEnglneei@BP ;cö1W~"R.ee~es'~ : : Dottald F'.' <ReevesDf@BP.co~>,"GPB~Lap'(APC)" <GPBLab@BP.com>~nGPB;Fld Oþs.tead"'.:' <gPBFldOpsL~~d@BP~com>;ttSmith;Bruce'Wt~'.~SmithBW@BP~còm>~.."Engel;.~arry.:Ru .. '. . <ErigelHR@BP.com>, .'tRòssberg,R. 'Steven"<:RossbeRS@BP .cóm>,:Wiriton' G:Aubert. :." :::, '. <w¥iton~aubert@admin.state;ak~u.s>'" tlG}>B~ QC2 .TLtt.,<G~BGC2TL@BP~com>; nGPB,' Lål;fTL'.'" <qPBLabTL@BP ~com>; .'~GP~, tab FldTèch.(APC)". <GPB~abFldTech@BP ~com~,. tl9PB':'VVell. PadsLVZ"<GPBWellPadsLVZ@BP.c.°m>,"NSU~'ADW Well operations Supervisöt":. ':' '.." <NSUADWWel1OpenitionsSupervisor@BP.com> ". ...' . ....:. ) Hi Jim. L-I05 went off PWI on 5/31/04 and started MI injection on 9/17/04. I requested the lab complete analysis of the gas sample within a week. I'll check with them and see how it's progressing. Attached is the TIO plot. I'll let you know what the gas analysis indicates. Let me know if you have any other questions. Joe -----Original Message----- From: James Regg [ma.i lta: j :i.m regg@admin. sta.te. ak. us] Sent: Wednesday, October 20, 2004 4:30 PM To: NSU, ADW Well Integrity Engineer Cc: Winton GAubert Subject: Re: Problem Well Notification: L-105 (PTD #2020580) RßDM-S ~~WS ~vers~ -to gas ru(l~ (:,/1 (04 ~ ~- 1V\j~ ~iV\< - ~ ~:c ~u. ~ - ~I~S~T ~\ - II ~(.jS ~'I.. Our database shows L-105 as a WAG injector, currently on gas cycle; 138 ~a MM cf gas injected over 14 days during September 2004. This is one of 3 Sèpt - 14c1ays GtI injectors in the Borealis MI pilot project. Unclear when and why well was shut in. ,T~ I òl1-1 Ilfr - What is the timing for OA gas sample analysis? - Please send TIO plot for pressures back through May 2004 (converted to gas in June 2004). Jim Regg AOGCC NSU, ADW Well Integrity Engineer wrote: All, Well L-105 (PTD #2020580) has sustained casing pressure on the OA and the well has been classified as a Problem well. The TIO's on 10/14/04 were SI/500/1120. The plan forward for this well is as follows: 1. Lab: Sample OA gas, determine if from shallow hydrates Attached is a wellbore schematic. Please call if you have any questions. «L-105.pdf» Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: (907) 659-5102 Mobile: (907) 943-1154 Pager: (907) 659-5100, xl154 Email: NSUADWWellIntegrityEngineer@bp.com SCANNEi'\ Nn\f n ~ ?nn/í 10f2 10/21/20048:12 AM RE: Problem Well Notification: L-I05 (PTD #2020580) > ) ) TIO Plot Content-Description: L-105 TIO Plot 10-20-04.ZIP Content-Type: applicationlx -zip-compressed Content-Encoding: base64 fÞ,u L -I oiJ W ~~ 4¡ecto. ; rCAM- ðf fro~'ect- ~ BðÎ~a.lts 0)'-( fOð l pì~ j.AiSct/Je \I'\r'~ ( 4-.J;Q Z4.0(2) 13<V,3M, uF ¿ytS J'\Tecke1 d-w'tJ 14~s /(\ ;;eþher ,?Où4- 20f2 10/21/20048:12 AM 612112004 . t- - ~- . ~ /1(04- CSw~ +0 ~ç L -105:110--'. Plot 4,.000 3~000- . .... ::J " . .... Q. 2,000 1,000,., 0 10121 f;!003 12/21 /2003 212112004' , I. 4121120Q4 -.------' --+ '-- . .-QOOA -.....,../ '-------~~- TREE = 4-1/16" aw WB...LHEA D = Frvx:: ._n_m~ mnmn_non no " A ClUA TOR = Nl\ ,..... ..... n. """ ... m..., KB. ELE.\! = 78.8' ~~~~ - BF. ELE.\! = 24.94' k<)"p = --. ....-- 40õ' un mnmmmm... no -. mnmno mnmonmmmmm........ Max A ng Ie = 46° @ 6446' Dafu nïïiïïb = . ....m.... . ä 15äï õi3tii mTV 0 = 6600' SS 9-5/8" CSG, 40#, L-80, 10 = 8.835" H 2856' Minimum ID = 3.725" @ 7873' 4-1/2" HES XN NIPPLE 4-112" lEG, 12.6#, L-80, .0152 bpf, 10 = 3.958" 1-4 7884' PERFORAllON SUMMARY REF LOG: SQUEEZE PERF RECORD ANGLE ATTOP PERF: 34 @ 7700' Note: Refer to Production DB for his torical perf data SIZE SPF INTERVAL OpnlSqz DAlE 4-1/2" 6 7700 - 7722 S 07/17/02 4-1/2" 6 7785 - 7805 S 07/17/02 3-3/8" 6 8012 - 8032 0 08/18/02 4-1/2" 6 8023 - 8043 0 07/17/02 3-3/8" 6 8040 - 8074 0 08/18/02 3-3/8" 6 8104 - 8110 0 08107/02 1 A3TD H 8267' 1 7" CSG, 26#, L-80, 10 = 6.276" H 8350' DATE 07/20102 08/05/02 08/18/02 10/13/02 04/08/03 REV BY COMIVENTS TWA/KK ORIGINAL COMA..E1lON RLAlh GL V UP[)6. lE JLJIKK ADPERFS JB/KA K GL V C/O æSlTP TVD/MJ CORRæTIONS L-105 I ~ I :g I 8' ~~ ~ DATE REV BY ') I SAFETY NOTES: =--1 980' H 9-5/8" TAM PORT COLLAR 1 1 2194' H 4-1/2" HES X NIP, 10 = 3.813" 1 . ~ l I ~ ~ . ~ J--i j-1 COMv'lENTS GAS LIFT MANDRELS ST MD lVO OEV 1YPE VL V LATCH PORT OA lE 3 3966 3489 41 KBG-2 OMY BK 0 10/13/02 2 5285 4498 42 KBG-2 OMY BK 0 07/20/02 1 7569 6186 37 KBG-2 OMY BK 0 10/13/02 7635' 1-1 4-1/2" HES X NIP, D = 3.813" 1 7646' H 7" X 4-1/2" BKR PREMER PKR, 10 = 3.89" 1 781 T 1-1 4-1/2" HES X NIP, D = 3.813" 1 7828' H 7" X 4-1/2" BKR S-3 A<R, 10 = 3.875" 1 7852' 7873' l-i 4-112" HES X NIP, D = 3.813" 1 H 4-1/2" HES XN NIP, ID= 3.725" 1-1 4-112" WLEG, ID = 4.00" 1 7885' 7904' H 7" 26# X 20' PUP JTW/ RA TAG (ELM) 8045' H 7" 26# X 20' PUP JTW/ RA TAG (ELM) BOREALIS UI\IT WB...L: L-105 ÆRMT No: 2020580 API No: 50-029-23075-00 SEC 34, T12N, R11 E 2415' NSL & 3573' WEL BP Exploration (Alaska) Permit to Drill 2020580 18' W-~~'1 DATA SUBMITTAL COMPLIANCE REPORT 9/7/2004 Well Name/No. PRUDHOE BAY UN BORE L-105 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23075-00-00 Current Statu.(ivAGI~- (ÛÍc Y ) MD 8360 ~ TVD 6852 /' Completion Date 8/18/2002 r-- Completion Status WAGIN REQUIRED INFORMATION DATA INFORMATION --~--_.~-~--~ --~--_._-"--- -~- Mud Log No Samples No Directional Survey Yes ----~~- ------ Types Electric or Other Logs Run: Well Log Information: (data taken from Logs Portion of Master Well Data Maint) Log/ Data Digital Type Med/Frmt ~ ~ ~ ~ ,t:6g jJ)g ~/ ~ ~C W ~. ~/ -röQ' ~ ~ ~ J.td§ ~ ~ Electr Dataset Number Name Sonic -6amma Ray -6't)fíj c ~~ Log Log Run Interval OH/ Scale Media No Start Stop CH Received Comments --_.------~-_. 0- 5 Col 1 4000 8253 Case 8/16/2002 - ~ Blu .....;1.B6 8303 Open 10/1/2002 y- C~ .........6700 8245 Case 8/16/2002 5 ,eó1 ~ 8253 Case 5 Cðr' A'foo 8245 Case 5 Q6 1 "SiÕ0 8245 Case 1 0 8360 Open 7/24/2002 5 00' 1 6700 8245 Case ..- ~ 8363 Open 10/1/2002 5 ~ ,&:f00 8245 Case 8/16/2002 1 Blu ~ 8238 Case 1 0/14/2002 Static Bottom Hole Pressure Survey 5 Col ~ 8245 Case 8/16/2002 5 Col ~ 8253 Case 8/20/2002 0 8360 Open 7/24/2002 5 Col ~ 8253 Case 8/20/2002 5 Col ...9"r00 8245 Case 5 Col ~O 8253 Case 8/16/2002 25 Blu ~ 8303 Open 10/1/2002 5 Col -5700 8245 Case 8/16/2002 ~---~------------'--- Sample Set Sent Received Number Comments ~17 .....eê"ment Evaluation ,..et1sing collar locator ~nic ~Îs'l;rvey' , ...+en1peratu re Gamma Ray <psing collar locator ~re ..esTnma Ray Cement Evaluation Cirooti,)lrã1 Survey Sonic -"'ámma Ray Cement Evaluation ~ Ray 1-VC -"f'efnperature Well Cores/Samples Information: Name Interval Start Stop DATA SUBMITTAL COMPLIANCE REPORT 9/7/2004 Permit to Drill 2020580 Well Name/No. PRUDHOE BAY UN BORE L-105 Operator BP EXPLORATION (ALASKA) INC MD 8360 TVD 6852 Completion Date 8/18/2002 Completion Status WAGIN Well Cored? ADDITIONAL INFORMATION yG:J Daily History Received? Chips Received? Analysis Received? Comments: 'y IN Formation Tops '"¥ 1t4 --- Compliance Reviewed By: .~ Current Status WAGIN GIN '&N Date: API No. 50-029-23075-00-00 UIC Y -----~~----~ -----_._~---~ _._~--~----~--_. w ð ~~q--------- ~ (' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ( 1. Operations Performed: Abandon D Alter Casing D Change Approved Program D Repair Well 0 PluQ PerforationsD Pull Tubing 0 Perforate New Pool D Operation Shutdown 0 Perforate D 78.80 8. Property Designation: ADL-028238 11. Present Well Condition Summary: Stratigraphic D 9. Well Name and Number: L-105 10. Field/Pool(s): Prudhoe Bay Field / Borealis Oil Pool ExploratoryD Service ŒI Stimulate D Other[&) WaiverD Time ExtensionO Re-enter Suspended Well 0 5. Permit to Drill Number: 202-0580 6. API Number 50-029-23075-00-00 Convert to MI 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 4. Current Well Class: Development D Total Depth measured 8360 feet true vertical 6852.0 feet measured 8267 feet true vertical 6772.4 feet Plugs (measured) Junk (measured) None Effective Depth None Casing Conductor Production Surface Length 78 8326 2827 Size 20" 91.5# H-40 7" 26# L-80 9-5/8" 40# L-80 MD TVD 30 108 30.0 108.0 25 - 8351 25.0 - 6844.3 29 - 2856 29.0 - 2635.9 Burst 1490 7240 5750 Collapse 470 5410 3090 Perforation deDth: Measured depth: 8012 - 8023,8023 - 8032,8032 - 8040,8040 - 8043,8043 - 8074,8104 - 8110 Tubing ( size, grade, and measured depth): 4-112" 12.6# L-80 True vertical depth: 6554.27 - 6563.67,6563.67 - 6571.36,6571.36 - 6578.2,6578.2 - 6580.76,6580.76 - 6607.27,6632.93 - 6638.06 EC I ED @ 23 7885 Packers & SSSV (type & measured depth): 4-112" Baker Premier Packer 4-1/2" Baker S-3 Perm Packer @ 7646 @ 7828 ,") ! j ?!l,14 011 &~ Cons. Comll/ise;o Y$ICh~ ' n 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 0 -7551 -1.5 0 13 Prior to well operation: Subsequent to operation: Oil-Bbl 0 0 Tubing Pressure 2340 14. Attachments: Copies of Logs and Surveys run- Daily Report of Well Operations - ! 15. Well Class after proposed work: Exploratory D 16. Well Status after proposed work: OilD GasD Development D Service ŒJ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron )4~~ WAG ŒJ GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or NIA if C.O. Exempt: 304-246 Title Production Technical Assistant Signature Phone 564-4657 Date 9/7/04 ORIGINAL RBDMS BFL SEP 1 3 ì.OO~ Form 1 0-404 Revised 4/2004 ( L-105 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 06/30/04 Start Mllnjection FLUIDS PUMPED BBLS 0 ITOTAL No Fluids Pumped Page 1 , ' TREE = 4-1/16" em WB..U-EAD= FtvC \........ .m... ... A ClUA TOR = NA. . ... .m...... . .n KB. ELBI = 78.8' ... ............... . ...m...... BF. ELBI = 24.94' Rõ-P;-----'------40ü' MaxAnglë-;--¡go @ 6446" oãfìrriMD= - 8158' DatumTV'Ö= 660(F"SS' 9-518" CSG, 40#, L-80, ID = 8.835" H 2856' ¡---JI Minimum ID = 3.725" @ 7873' 4.1/2" HES XN NIPPLE 4-112"lBG, 12.6#,L-80, .0152 bpf,ID=3.958" H 7884' PERFORATION SUMMARY REF LOG: SQLEEZE PERF RECORD ANGLE AT TOP PERF: 34 @ 7700' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 4-1/2" 6 7700 - 7722 S 07/17/02 4-1/2" 6 7785 - 7805 S 07/17/02 3-3/8" 6 8012.. 8032 0 08/18/02 4-1/2" 6 8023 - 8043 0 07/17/02 3-3/8" 6 8040 - 8074 0 08/18/02 3-3/8" 6 8104- 8110 0 08/07/02 I R3TD H 8267' I 7" CSG, 26#, L-80, ID = 6.276" H 8350' DATE 07/20102 08/05/02 08/18/02 10/13/02 04/08/03 REV BY COMrvENTS lWA/KK ORIGINAL COMA-EllON RLltlh GL V UPDA TE JLJA<K ADPERFS JB/KA K GL V C/O DRSlTP TVD/rvD CORRECTIONS L-1 05 = I I :8: I :g ~~ ~ DATE REV BY I SAFETY NOTES: I ::--1 980' H 9-518" TAM PORT COLLAR I I 2194' H 4-1/2" I-£S X NIP, ID = 3.813" I ~ GAS LIFT MANDRELS ST MD lVD DEV 1YPE VL V LATCH PORT DATE 3 3966 3489 41 KBG-2 DMY BK 0 10/13/02 2 5285 4498 42 KBG-2 DMY BK 0 07/20/02 1 7569 6186 37 KBG-2 DMY BK 0 10/13/02 l I 7635' H 4-112" I-£S X NIP, [) = 3.813" I 7646' H 7"X4-1/2"BKRPREMERPKR,ID=3.89" I ~ . 781T H 4-1/2" I-ESX NIP, [) =3.813" I 7828' H 7" X 4-1/2" BKRS-3 A<R, ID = 3.875" I ~ 7852' H 4-1/2" I-£S X NIP, [) = 3.813" I 7873' H 4-1/2" HES XN NIP, ID= 3.725" 7885' 1-1 4-1/2" WLEG, ID = 4.00" I ~ 7904' H T' 26# X 20' PLP JTW/ RA TAG (ELM) ¡--, 8045' H T' 26# X 20' PLP JTW/ RA TAG (ELM) COrvtv1ENTS BOREALIS UNIT WELL: L-105 ÆRMT No: 2020580 API No: 50-029-23075-00 SEC34, T12N, R11E 2415' NSL& 3573' WEL BP Exploration (Alaska) MEMORANDUM State of Alaska ( Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor '"K'11 7/Jb{iJ-f< DATE: Wednesday, June 30, 2004 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC L-105 PRUDHOE BAY UN BORE L-I05 dvO d-- - Osg FROM: John Crisp Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv .:::Jßrz-- Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UN BORE L-105 API Well Number: 50-029-23075-00-00 Insp Num: mitJCr040628 1 00924 Permit Number: 202-058-0 ReI Insp Num: Inspector Name: John Crisp Inspection Date: 6/24/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well L-I05 Type Inj. N TVD 6852 IA 204 4010 3940 3920 P.T. 2020580 TypeTest SPT Test psi 1599.5 OA 710 760 770 770 Interval OTHER P/F P Tubing 550 900 750 700 Notes: Well being WAGed fI PWI to MI injection. Considered four year MIT. 4000 psi test for MI swap. Wednesday, June 30, 2004 Page 1 of I 1. Type of Request: Abandon 0 Alter Casing 0 Change Approved Program D 2. Operator Name: \rJt¡ 1\-- h / SO /2..0 C4 ( STATE OF ALASKA F(f:~E.~/30 I <¡- ALASKA OIL AND GAS CONSERVATION COMMISSION ~.t",>, \.~'#..~: l\lED APPLICATION FOR SUNDRY APPROVAt;J 292004 20 AAC 25.280 BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 78.80 KB 8. Property Designation: ADL-0028238 11. Total Depth MD (ft): 8360 Casing Total Depth TVD (ft): 6852.0 Conductor 78 Production 8326 Surface 2827 Perforation Depth MD (ft): 8012 - 8023 8023 - 8032 8032 - 8040 8040 - 8043 8043 - 8074 8104 - 8110 Packers and SSSV Type: 4-1/2" Baker Premier Packer 4-1/2" Baker S-3 Perm Packer Length Suspend 0 RepairWell D Pull Tubing D AI~sl'a 0:, n ;", 11. :: G~..dL'; Cun:;, PerforateD bml~e Annular Disposal D StimulateD Time ExtensionD OtherŒJ Re-enter Suspended Well 0 Convert to Mllnj./ 5. Permit to Drill Number: 202-0580 / Operation Shutdown D Plug Perforations D Perforate New Pool D 4. Current Well Class: Development D Exploratory D StratigraphicD Service ŒJ / 9. Well Name and Number: L-105 / 10. Field/Pool(s): Prudhoe Bay Field / Borealis Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 8267 6693.6 MD TVD 6. API Number /' 50-029-23075-00-00 Size Plugs (md): Junk (md): None None Burst Collapse top bottom top bottom 30 108 30.0 108.0 1490 470 25 8351 25.0 6844.3 7240 5410 29 2856 29.0 2635.9 5750 3090 Tubing Size: Tubing Grade: Tubing MD (ft): 4.5 " 12.6 # L-80 23 7885 20" 91.5# H-40 7" 26# L-80 9-5/8" 40# L-80 Perforation Depth TVD (ft): 6554.27 6563.7 6563.67 6571.4 6571.36 6578.2 6578.2 6580.8 6580.76 6607.3 6632.93 6638.1 Packers and SSSV MD (ft): 7646 7828 Detailed Operations Program 0 Description Summary of Proposal 0 Service 00 12. Attachments: BOP Sketch 0 13. Well Class after proposed work: ExploratoryD DevelopmentD ~,/ 14. Estimated Date for Commencing Operation: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Signature Bruce Smith ~ June 30, 2004 Date: 15. Well Status after proposed work: Oil D GasD WAG ~ GINJ[t] PluggedD AbandonedD WINJD WDSPLD Prepared by Garry Catron 564-4657. Contact Bruce Smith ~ ~ 6/29/04 Title Phone Petroleum Engineer 564-5093 Commission Use Only Sundry Number: Jo¥- ;;J.ft, Conditions of approval: Notify Commission so that a representative may witness Other: Subsequent Approved by: Form 1 0-403 Revised 06/2004 BOP TestO Mechanciallntegrity Test D Location Clearance 0 ~. ~t VI' €,IVCt t..~t-f) II ~.Ix tee s I ~ {¡.JÄ-Ú r ¡J . BY ORDER OF ~ k", itJd vi THE COMMISSION Date: ~/.;)í - 7 jUl 0'; (1 SUBMIT IN DUPLICATE ORIGINAt~ ( TREE = 4-1/16" OW WELLI-EAD = Frv'C "''-'"'''''''''' . ~..~~.~........~~...... ,..................... ~~.m. AClUATOR = NA .......... ....... n. """'m~'~.. m ...'-~~'~ KB. ELEV = 78.8' . ..~.... ... .. BF. ELEV = 24.94' _.m_on... - . m. no .m...nun ...m n KOP = 400' Max Angle = 46° @-13446' Datum MD =--0--u--8"1--58' 5ãtumTVD= 6600' SS 9-518" CSG, 40#, L-80, 10 = 8.835" H 2856' ~ Minimum ID = 3.725" @ 7873' 4-1/2" HES XN NIPPLE 4-112" 1BG, 12.6#, L-80, .0152 bpf, 10 =3.958" H 7884' PERFORAllON SUMMARY REF LOG: SQUEEZE PERF RECORD ANGLE AT TOP PERF: 34 @ 7700' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnlSqz DATE 4-1/2" 6 7700 - 7722 S 07/17/02 4-1/2" 6 7785 - 7805 S 07/17/02 3-3/8" 6 8012 - 8032 0 08/18/02 4-1/2" 6 8023 - 8043 0 07/17/02 3-3/8" 6 8040 - 8074 0 08/18/02 3-3/8" 6 8104 - 8110 0 08/07/02 I FBTD H 8267' 17" CSG, 26#, L-80, 10 = 6.276" 1-1 8350' DATE 07/20/02 08/05/02 08/18/02 10/13/02 04/08/03 REV BY COMMENTS TWA/KK ORIGINAL COMA..E110N RLltlh GL V UPDA TE JLJIKK ADPERFS JB/KA K GL V C/O DRS/TP TVD/rvD CORRECTIONS L-105 = I I :8: I SAFETY NOTES: I =---f 980' H 9-518" TA M PORT COLLAR I I 2194' H 4-1/2" I-ES X NIP, 10 = 3.813" 1 ~ GAS LIFT MANDRELS ST MD lVD DEV lYPE VLV LATCH PORT DATE 3 3966 3489 41 KBG-2 DMY BK 0 10/13/02 2 5285 4498 42 KBG-2 DMY BK 0 07/20/02 1 7569 6186 37 KBG-2 DMY BK 0 10/13/02 L . 7635' H 4-1/2" I-ES X NIP, D = 3.813" 1 :8" 7646' H 7' X4-1/2" BKRPREMERPKR, ID= 3.89" 1 I . 7817 H 4-1/2" HESX NIP, D =3.813" 1 Z -~ 7828' H 7' X 4-1/2" BKR S-3 A<R, 10 = 3.875" I ~~ ~ DATE REV BY 7852' 1-1 4-112" I-ES X NIP, D = 3.813" 1 7873' H 4-1/2" HES m NIP, 10 = 3.725" 7885' 1-1 4-1/2" WLEG, 10 = 4.00" I r- ~ 7904' H T' 26# X 20' PLP JTW/ RA TAG (ELM) ~ 8045' H T' 26# X 20' PLP JTW/ RA TAG (ELM) COMMENTS BOREALIS UNIT WELL: L-105 ÆRMT No: 2020580 API No: 50-029-23075-00 SEC 34, T12N, R11 E 2415' NSL & 3573' WEL BP Exploration (Alaska) ( MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Mike Bill f"'~ Commissioner DATE: November 1, 2002 SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder A/\o. f\ BPXA Petroleum Engineer ~\ ~ (VI Ç).., L Pad / þð \ \( "'ù L-105 FROM: Jeff Jones ~ Prudhoe Bay Unit Petroleum Inspector Prudhoe Bay Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. T.V.D. 6248 Tubing 1620 1630 1630 1630 1630 Test psi 1562 Casing 10 2260 2225 2240 2275 OA 770 ,780 820 840 860 Notes: _Pre~test pressures monitored 15 min. & stable. Test fluid 43 deg. F diesel; S riser temp:131 deg. F Type INJ. F,uic C':odes Type Test Interval F = FRESH WATER INJ. M= Annulus Monitoring 1= Initial Test G = GAS INJ. P= Standard Pressure Test 4= Four Year Cycle S = SALT WATER INJ. R= Internal Radioactive Tracer Survey V= Required by Variance N = NOT INJECTING A= Temperature Anomaly Survey W= Test during Workover Well L-105 'Type Inj. P.T.D. 2020580 Type test s P Interval P/F I E 0= DifferentialTemperature Test 0= Other (describe in notes) Test's Details November 1, 2002: I traveled to BPXA's Prudhoe Bay Field L Pad to witness an initial MIT on water injection well L-l 05. Roland Johnson was the BPXA representative for the test today which was performed in a safe and proficient manner. The pre- testpressures \vere obserVedför 151ninutesånd found to be stable. The standard annulus pressure test was then performed and well L-I05 passed the MIT. The. pre§§ure. test \\,~<þeI4.anaclclitiOnal 15 minutes to further demoástrate integrity and the increaseiribåsingpressutes\vas attributed to the temperature differential between the 131 deg. F injection fluid and the 43 deg. F test fluid~Thewellhouse wasinspedtëd with no exceptions noted. Summary: I witnessed a successful initial MIT on BPXA's Prudhoe Bay Field water injection well L-I05. well house inspected; no exceptions. One M.I.T.'s performed: 1 Attachments: Number of Failures: Q Total Time during tests: 1.5 hrs. cc: M IT report form 5/12/00 LG. MIT PBU L-105 11-1-'02 JJ.xls 11/4/2002 ( ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Pre-Prod Converted to Inject 2. Name of Operator BP Exploration (Alaska), Ine. 3. Address P. O. Box 196612 Anehorage, AK 99519-6612 4. Location of well at surface Operation shutdown- Pull tubing - Stimulate - Alter casing - 5. Type of Well: Development - Exploratory- Stratigraphie- Serviee_X Plugging - Perforate - Repair well - Other _X 6. Datum elevation (OF or KB feet) RKB 79 feet 7. Unit or Property name " Prudhoe Bay Unit 8. Well number L-105 9. Permit number / approval number (asp's 587455, 5977576)' 202-058 / 302-291 10. API number (asp's 583343,5978138) 2865' FNL, 3573' FEL, See. 34, T12N, R11 E, UM At top of productive interval 3473' FNL, 4749' FEL, Sec. 35, T12N, R11 E, UM At effective depth 3503' FNL, 4607' FEL, Sec. 35, T12N, R11 E, UM At total depth 3512' FNL, 4560' FEL, Sec. 35, T12N, R11 E, UM 12. Present well condition summary Total depth: measured true vertical (asp's 587596, 5977548) ". 50-029-23075-00 11. Field I Pool Prudhoe Bay Field / Borealis Pool (asp's 587643, 5977540) 8360 feet 6852 feet Plugs (measured) Effective depth: measured 8267 feet Junk (measured) true vertical 6772 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 108' 20" 260 sx Aretic Set (Approx 137' 137' Surface 2857' 9-5/8" 464 sx Articset Lite, 303 2856' 2636' sx Class 'G' Production 8325' 7" 314 sx LiteCrete, 151 sx 8350' 6843' Class 'G' Perforation depth: measured Sqzd Perfs 7700'-7722',7785'-7805'. Open Perfs 8012'-8074',8104'-8110'. true vertical Sqzd Perfs 6293'-6311',6363'-6379'. Open Perfs 6554'-6607',6633'-6638'. Tubing (size, grade, and measured depth) 4-1/2" 12.6# L-80 TBG @ 7828'.4-1/2" 12.6# L-80 Tubing Tail @ 7885'. Packers & SSSV (type & measured depth) 7" x 4-1/2" Baker Premier Paeker @ 7646' MD. 7" x 4-1/2" Baker S-3 Packer @ 7828' MD. 4-1/2" HES 'X' Landing Nipple @ 2194'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniection DOCT J 12002 Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubing Pressure AlasfèaDI~& G~eons. CommissIon 7873 AnChorage \ RECEIVED Prior to well operation Shut-In Subsequent to operation 10/26/2002 15. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations - Oil - Gas - 17. I hereby certify that the fo:egOiñ is ~ue and correct to the best of my knowledge. A~~ J~ Title: Technical Assistant DeWayne R. Schnorr 1758 16. Status of well classification as: Suspended - Service WAG INJECTOR Date October 28. 2002 Prepared by DeWayne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88 . L SUBMIT IN DUPLICATE ~ 09/22/2002 10/12/2002 1 0/13/2002 10/17/2002 10/18/2002 10/23/2002 09/22/02 10/12/02 ( ( L-105 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS NEW WELL POST: STATIC BOTTOM HOLE PRESSURE SURVEY NEW WELL POST: DRIFT/TAG; GAS LIFT--TO DUMMY VALVES; MIT-IA NEW WELL POST: GAS LIFT--TO DUMMY VALVES; MIT-IA NEW WELL POST: AC-FLUID LEVEL NEW WELL POST: AC-BLEED; AC-FLUID LEVEL FIRST DAY OF WATER INJECTION INTO WELL L-I0S. EVENT SUMMARY TAGGED TD HIGH AT 8239 FT MD. CHANGED PROGRAM TO REMOVE STOPS AT 8275 FT MD (6700 FT SS) AND ADDED STOPS AT 7830 AND 7940 FT MD . 8158 FT MD/6600 SS = 2252.7 PSI @ 157.6 DEGF 8041 FT MD/6500 SS = 2206.4 PSI @ 155.6 DEGF 8041 FT MD/6500 SS = 2206.5 PSI @ 155.5 DEGF 7940 FT MD/6414 SS = 2168.8 PSI @ 150.8 DEGF 7830 FT MD/6321 SS = 2134.5 PSI @ 149 DEGF D&T 3.50 CENT TO 8232' MD COR (1221 RATHOLE). PULL LGLV FROM STA-3 PULL S/O FROM ST A-1 SET DGLV IN STA-3. LOAD IA W/ 135BBLS OF INHIBITED WATER SET 111 DGLV BK IN STA# 1 --- MIT IA LOST TOTAL OF 55# IN 30MIN (PASS) RIH W/ 4 1/2 GS TO PULL CS 10/13/02 ASSIST WIRELlNE MIT IA TO 2500 PSI. PUMPED A TOTAL OF 50/50 METHANOL DOWN IA. MIT PASSED. PULL 4 1/211 WHIDDON C-SUB ( EMPTY) «< RETURNED WELL TO OPERATOR »> 1 0/17/02 T/I/O= SI/1250/560 ( for State MITs) IA FL @ 990' 10/18/02 T/I/O = 1320/1200/540 IA FL & BLEED IA (Prep for AOGCC MITIA) IA FL @ 1080' (19 BBLS). BLED IA FROM 1200 PSI TO 10 PSI IN 2 HOURS. MONITOR FOR 15 MINUTES. FINAL WHP's = 1320/10/530 10/23/02 FIRST DAY OF WATER INJECTION INTO WELL L-105. . ' BBLS 2 175 175 352 FLUIDS PUMPED PRESSURE TEST LUBRICATOR W/ 1 BBL OF DIESEL, (2 TESTS) 50/50 METHANOL WATER INHIBITED WATER FOR LOAD & TEST. TOTAL Page 1 ( lREE= 4-1/16"CIW WELLHEAD = Frvc AC1UA TOR;;; nuun NA KB~ELBI;~--_nn78.1f 13F.ELËV~;~- n__un -~-2~94' ï(Óþ;,;;""nnuu nn 400' ~Mix An~eu;,;;nn46~-~~4~~ D:ltum fvD = ~~~~~~ D:ltum lV D = 9-5/8" CSG, 40#, L-80, ID = 8.835" H 2856' Minimum ID = 3.725" @ 7873' 4-1/2" HES XN NIPPLE 4-112"lBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 1-1 7884' PERFORATION SUMMA RY REF LOG: SQUEEZE PERF RECORD ANGLE AT TOP PERF: 34 @ 7700' f\bte: Refer to A"oduction DB for historical perf data SIZE SPF INTER\! AL Opn/Sqz DA TE 4-1/2" 6 7700 -7722 S 07/17/02 4-1/2" 6 7785 -7805 S 07/17/02 4-1/2" 6 8023 - 8043 0 07/17/02 3-3/8" 6 8040 - 8074 0 08/18/02 3-3/8" 6 8012 - 8032 0 08/18/02 3-3/8" 6 8104 - 8110 0 08107/02 I FaTD H 8267' 1 7" CSG, 26#, L-80, ID = 6.276" H 8350' DAlE 07/20102 08/05/02 08118/02 10/13102 REV BY COMMENTS TWA/KK ORIGINAL COMPLETON RUth GLV LPDATE JLJ/KK ACPERFS JB/KAK GLVaO =---1 980' H 9-518" TA M PORT COLLAR I 1 2194' H 4-1/2" I-ESX NIP, ID =3.813" I L-105 = I I ~ ~ l I I :8: ~ I I . I z )5; I~ ~ ~ ~ ~ DA TE REV BY COMMENTS (' I SAFE1Y NOlES: ST MD 3 3966 2 5285 1 7569 GAS LIFT MANDRI3..S TVD DEV TYÆ VLV LATCH 3489 41 KBG-2 DMY BK 4498 42 KBG-2 DMY BK 6186 37 KBG-2 DMY BK FQRT DATE 0 10/13/02 0 07/20/02 0 10/13/02 7635' H 4-1/2" I-ES X NIP, ID = 3.813" I 7646' H 7" X 4-1/2" BKR FREMER PKR, D = 3.89" 1 7817' H 4-1/2"HESXNIP,ID=3.813"1 7828' H 7" X 4-1/2" BKR &-3 A<R ID= 3.875" I 7852' 7873' H 4-1/2" HES X NIP, ID = 3.813" I H 4-112" HES XN NIP, ID = 3.725" I H 4-1/2"WLEG, ID= 4.00" I 7885' 7904' ~ 7" 26# X 20' PLP JT W/ RA TAG (ELM) I 8045' ~ 7" 26# X 20' PLP JT W/ RA TAG (ELM) I GPB BOREALIS WELL: L-105 PERMT f\b: 2020580 AR No: 50-029-23075-00 SEC34, T12N, R11E 2415' NSL & 3573'W13.. BP Exploration (Alaska) Schlumberger Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Beth Well Job# Log Description L-105 d.O~-D~'l SBHP SURVEY V-104 ~~d-' ltj ;l SBHP SURVEY D.S. 15-31AC~.1 D;;:). 22231 D.S.15-31A C-25A J q - - 0 II 22234 C-25A PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered: REceIVED OCT 1 4 2002 Alaska or¡ & Gas Conz" ~mmimon Anchomgl 09/22/02 09/23/02 06/15/02 07/10/02 10/07/02 NO. 2472 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis P. Bay Date Color Sepia CD BL Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATIN: Beth R.~WQO~. bp ( ( ...\t'~4. .........~~T"~...- ~~- ~..~ .~ -F~" .'J'4\- BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 September 10, 2002 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Winton: J" Re: Sundry Notice for L-1 05 Conversion from Pre-Produced Injector to WAG Injector BP Exploration Alaska, Inc. proposes to convert well L-105 from a pre-produced injection well to an active injector (~water and)M1~ flood)) as part of the Borealis Pool Flood Development project. ~ L () - j ...JY"" ()à- 1~~ '-1'/ The procedure includes the following major steps: ¡.$~ tL '/Û/6~ S DfT, Dummy off GL Design, Run Static Survey. J)~ MITIA to 4000 psig. Slickline Work: 1. Drift and tag to at least 8150' MD, to verify access to perfs. 2. Run DHSIT wI dual gauges. Recover DHSIT wI gauges after + 72 hours. 3. DGL Vs MITIA to 4000 psig. Last test: 08/28/02 2006 SOPD Max Deviation: 46° @ 6446' MD Top Perf deviation: 34° @ 7700' MD Min. ID: 3.725" XN nipple @ 7873' MD Last TD tag: 8247' MD 08/07/2002 Last Downhole Ops: Peforating 08/18/2002 Latest H2S value: 0 ppm 09/09/2002. Wellbore Fluids:Tubing Oil, IA Gas Lift. BHT & BHP: L-105 - To be acquired in the next couple of weeks. Reference Log: Schlumberger Platform Express Log 07/12/2002 If you have any questions concerning this Sundry Application, please don't hesitate to call me at 564-5093, hm: 345-2948, cell: 440-8008 or e-mail me at SmithBW @BP.com Sincerely, j. (~ ~ /~ Bruce W. Smith GPB Borealis Development Engineer .. ( ( STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 7700'-7722',7785'-7805'. Open Perfs 8012'-8074', 81Q~,:-ß~ 1(,°" .\t 6293'-6311',6363'-6379'. Open Perfs 6554'-6607',6633'-6638'. 4 ~ 4-1/2" 12.6# l-80 TBG @ 7828'. 4-1/2" 12.6# L-80 Tubing Tail ~ 7?~5::. ð:~'d'~}(;" ~,~':1 ~~ a(l~~ COmmiS$IOr: Packers & SSSV (type & measured depth) 7" x 4-1/2" Baker Premier Packer @ 7646' MD. 7" x 4-1/2" Baker S-3 Pac'~~fíW';:7828' MD. 4-1/2" HES 'X' Landing Nipple @ 2194'. 13. Attachments Description summary of proposal_X Detailed operations program- 14. Estimated date for commencing operation 15. Status of well classification as: September 18, 2002 16. If proposal was verbally approved Oil - Gas û.>J~ ~ ,,11JPfo'V Name of approver Date approved Service ~NJECTOR 17. I hereby certify that the foregoing is true nd correct to the best of my knowledge. Questions? Call Bruce W. Smith @ 564-5093. r~ lv 1. Type of request: Abandon- Suspend- Pre-Producer Alter casing - Repair well - Converted to Inject Change approved program - 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 2865' FNL, 3573' FEl, See. 34, T12N, R11 E, UM At top of productive interval 3473' FNl, 4749' FEl, SEC 35, T12N, R11 E, UM At effective depth 3503' FNl, 4607' FEl, Sec. 35, T12N, R11 E, UM At total depth 3512' FNL, 4560' FEl, See 35 T12N, R11 E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size Conductor 108' 20" Surface 2857' 9-5/8" Production 8325' 7" Perforation depth: measured Sqzd Perfs true vertical Sqzd Perfs Tubing (size, grade. and measured depth Signed Bruce W. Smith Title: Borealis Development Petroleum Engineer Date September 10.2002 Prepared by DeWayne R. Schnorr 564-5174 Operational shutdown - Plugging - Pull tubing - 5. Type of Well: Development - Exploratory - Stratigraphic - Service_X (asp's 583343,5978138) (asp's 587455, 5977576) (asp's 587596, 5977548) (asp's 587643, 5977540) 8360 feet 6852 feet 8267 feet 6772 feet Plugs (measured) Junk (measured) Re-enter suspended well - Pre-Producer Converted Time extension - Stimulate - to Injector Variance - Perforate - Other _X 6. Datum elevation (DF or KB feet) RKB 78.8 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number L -1 05 9. Permit number I approval number 202-058 10. API number 50-029-23075-00 11. Field I Pool Prudhoe Bay Field / Borealis Pool Measured Depth 137' 2856' True vertical Depth 137' 2636' Cemented 260 sx ArcticSet (Approx) 464 sx ArcticSet Lite, 303 sx Class 'G' 314 sx LiteCrete, 151 sx Class 'G' 8350' 6843' ~ ';¡; J BOP sketch - Suspended - FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity - ...BPP Test - Location clearance - ¡¡ I ~ ¡ Mechanical Integrity Test p.. Subsequent form required 10- ~ O't ORIGiNAL S¡G~~ED Oy 0 Taylor Seamount ot,J Approved by order of the Commission Form 10-403 Rev 06/15/88 . I Approval nO'3 0 -a... Ã 't I Commissioner I CAT\:. Date 0, ,?ßJo~ SUBMIT IN TRIPLICATE 1REE = 4-1/16" CrN WElLHEAD = FM8 ACTUA TOR = ' NA KB. a.BI = 78.8' SF. 8.EV = 24.94' KOP = 400' ~x Angle = 46° @ 6446' O:itum M) = O:itum NO = ( I 9-5/8" CSG, 40#, L-80. 10 = 8.835" H 2856' ~ Minimum ID = 3.725" @ 7873' 4-1/2" HES XN NIPPLE I 4-112" iBG, 12.6#, L-80, .0152 bpf, 10 = 3.958" H 7884' PERFORATION SUMMA. RY REFLOO: SQLEEZEPERF RECORD ANGLE AT TOP PERF: 34 @ 7700' r-.bte: Refer to A"oduction DB for historical perf data SIZ E SPF INTER\! AL Opn/Sqz [)A. TE 4-1/2" 6 7700 - 7722 S 07/17/02 4-1/2" 6 7785 - 7805 S 07/17/02 4-1/2" 6 8023-8043 0 07/17/02 3-3/8" 6 8040 - 8074 0 08/18/02 3-3/8" 6 8012 - 8032 0 08/18/02 3-3/8" 6 8104-8110 0 08107/02 I AHD H 8267' 17" CSG, 26#. L-80, 10 = 6.276" H 8350' =---1 980' H 9-5/8" TA M PORT CŒ.LAR I I 2194' H 4-1/2" ~SX NP,ID =3.813" I L-105 = I . ~ l I I :8: ~ I I . I ~ '¿š; ''0 ~ ~ f--4 ~ DA TE REV BY COMtvENTS [)A. TE RBI BY COfvfv18'JTS 07/20102 TWA/KK ORlGINA.L COMPLEfON 08l05iÜ2 RUth GLV LPDA TE 08l18iÜ2 JLJ/KK A rFERFS I SAFETY f\OlES: ST MD 3 3966 2 5285 1 7569 GAS LIFT MA.f\OR8.S TVD OBI TYÆ VLV LATCH FDRf DATE 3489 41 KBG-2 DOME BK-5 16 08/05/02 4498 42 KBG-2 OMY BK-5 07/20/02 6186 37 KBG-2 SO BK-5 20 08/05/02 7635' H 4-1/2" ~SX NlP,ID =3.813" I 7646' H 7" X 4-1/2" BKR ffiEMER PKR. D = 3.89" I 781T H 4-1/2" ~SX NIP, 10 =3.813" I 7828' H 7" X4-1/2"BKR S-3 A<R. 10= 3.875" I 7852' H 4-1/2" ~S X NIP, 10 = 3.813" I 7873' H 4-1/2"HESXNNlP,10=3.725" I 7885' H 4-1/2"WLEG,10=4.00" I 7904' H 7" 26# X 20' PLP Jf W/ Rl\ TAG (ELM) I 8045' H 7" 26# X 20' PLP Jf W/ Rl\ TAG (ELM) I GPB BOREALIS WELL: L-105 PERMT r-.b: 2020580 AA No: 50-029-23075-00 SEC 34. T12N, R11E 2415' NSL & 3573' Wa. BP Exploration (Alaska) ( ( L-I05i API 50-029-23075-00 Well history 1. Spud well 7/5/02, 11:30 AM using Nabors 9ES 2. Surface casing tested 7/702, 09:00, Good. 3. Drilled out surface casing shoe, 7/8/02 13: 30 4. Drilled to 7465 md, 7/10/02 18:00, started short trip, well starting to packoff. Lost 67 bbls. 5. Drill ahead to TD 8360 MD, 7/11/02 13:30, mud showing some signs of dehydration but no losses noted. 6. Condition hole 7. Run PEX 7/12/02, 6.5 hours round trip, no problems noted, no losses. 8. Run Casing, start 7/12/02 18:45, brake eirc every 5 jts, eirc/ 10 min every 20 jts 9. At Midnight hole not taking fluid while running 10. Casing slowed, landed casing 7/13/02 13:30, estimated total losses during casing running 439 BBL. 11. Condition mud, full returns 12. MU Haleo cement head break circ and stage up to 7,BPM, good circ, full returns 13.7/13/02 15:50, Pump 5 bbl WTR, 35 bbls spacer, 120 bbls permafrost L lead slurry, switch to Prem tail at 15.8 ppg. Cement starting to set in batch mixer, Abort Job. 14.7/13/02 16:40 Switch to rig pumps eirc out all cement, got cement back at surface after 485 bbls, circ cement and cont mud until ran out of mud. 15. Attempted to start circ 7/13/02 18:00 no Luck., slight eirc. 16. RU Dowell, 7/14/02 05:00, pump cement operation. Returns not listed 17. Plug in place, floats holding 7/14/02 08:30. 18. Run USIT#1 7/15/0209:00,(23 Y2 hrs set time) very poor to no cement visible. WOC 19. Run USIT #2 7/16/02 09:00, (47 Y2 hrs set time) very poor to no cement visible, Switch design to single injector design, SB not to be perf. 20. Deeide to squeeze cement, 21. Shoot 8023-8043, 7785-7805, 8023-8043, all shots fired. 22.7/18/0204:00, Set EZSV at 8008 MD, stung into with tubing 23. Attempt to eirc, no luck, switch plan to balanced plug. 24. 7/18/0209:00, Spot 22.5 bbls slurry, slowly squeeze / hesitate / squeeze/ no returns. 25. RIH tag cement 7598 MD, drillout and casing scrape. (' 26.7/19/02 10:30, (251/2 hours post squeeze) RU SOS for USIT#3, evaluated with very poor to isolated sections of good cement. a. 7456-58 isolated b. 7498-7500 isolated c. 7540-7560 isolated d. 7578-7584 isolated e. 7590-7634 isolated f. 7640- 7720 isolated g. 7750-7830 isolated h. 7850-7906 isolated. 27. Determined to run completion and shoot post rig move. 28. Rig Release 7/21/02 09:00 29. Wireline operation to perf well 8/18/02 a. 8104-8110 b. 8054-8074 c. 8040-8054 d. 8012-8032 30. POP well 8/28/02 2006 BOPD < ~: : : : : : : ¡ 10 ... - IöJ' xl "~J ~ (iJ"'ljlll U.fm'llIJ ""11 ~I 'iõf'.(õ.fI :m.-."'!ii ~ çmn 11.11.1 ["I i8 ~ 1J,.,\'sr... File, '. Edit, Display Annotate View Help I4J; yf*ll~lt~~) ill ~ ~,,~ D A q ~ ~ y ðt y.å..",,=~J ~'....~ Helvetica ;¡-~G7'(1 - -~? ~;'{<; ~~I;~,~R_- , (...-.'. ...-,.... ,}- ,... 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'.'.': .," .",'.", .~.' ~ -~' , ,: '~: :~ ',Q '~i~\,:, " ,.. "" ~~,. ~,I~:':,::, ,";:-~~:':~,5-:-:,'7¡:t:.:, ," .,; ~ g ',:" i.' ,~' ':', ' J .~ ~ . ~ '-C'~,:":' ',~'.' '~, ~~~ ~" .. ~- ~ . ','., ..,: ;;.,..~~,. ~,,:' '~ ~ ,.. '.- . ,) : . ',! L ~;~ .... iii '.. "..... l'~ ~ _I.""" ",:':;:,': '... ': ~ -, ~, .'."-"";'~.:~;';':'';.¡.'''IIIÌII ~ Schlumberger Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Beth Well Job # L-105 L-105 L-105 22349 OH EDIT MWD GR 22349 MD VISION GR 22349 TVD VISION GR Öo ú) () , ~ ~ Log Description PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E Benson Blvd, Anchorage AK 99508-4254 Date Delivered: RECEIVED OCT 0 1 2002 Ala8ka Oil & Gal Cons. Commi8ion AndIcnge 07111/02 07/11/02 07/11/02 NO. 2440 '09/25/02 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Date Color Sepia Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATIN: Beth R.œ;'~ BL CD ,~ ~ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Revised: 09/09/02, Put on Production 23. CASING SIZE 20" 9-5/8" 1. Status of Well a Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. L~~i;~~~~~~1~~~:~:::~~:::~~~M 1;.1.. ~C,.~~.:,::+,' At total depth r~ ¡ 1767' NSL, 719' EWL, SEC. 35, T12N, R11 E, UM 1.£--:-..-..::.:1 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 78.801 ADL 028238 12. Date Spudded 13. Date T.D. Reached 14. Date Camp., Susp., or Aband. 7/5/2002 7/11/2002 7/21/2002 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 8360 6852 FT 8267 6772 FT a Yes 0 No 22. Type Electric or Other Logs Run MWD, GR, RES, DEN, NEU, RES 1 AIT, DT 1 BHC, CNL, LDL, GR, Caliper, SP, MRES, BHC-Sonic, US IT CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE CEMENTING RECORD Surface 1081 42" ,260 sx Arctic Set (Approx.) 29' 28561 12-1/411 464 sx Articset Lite, 303 sx 'G' 25' 8350' 8-3/4" 314 sx LiteCrete, 151 sx Class 'G' Classification of Service Well Pre-Produced Injector 7. Permit Number 202-058 8. API Number 50- 029-23075-00 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number L-105i 11. Field and Pool Prudhoe Bay Field 1 Borealis Pool (Undefined) 15. Water depth, if offshore 16. No. of Completions NI A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 21941 MD 19001 (Approx.) WT. PER FT. 91.5# 40# 26# GRADE H-40 L-80 L-80 AMOUNT PULLED 711 (Initial Cement Job Aborted, 07/13/02) 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 3-3/811 Gun Diameter, 6 spf 4-1/211 Gun Diameter, 6 spf MD TVD MD TVD 80121 - 8032' 6554' - 6571' Deen 8040' - 8074' 6578' - 6607' 8104' - 8110' 6633' - 6638' 25. SIZE 4-1/211, 12.6#, L-80 TUBING RECORD DEPTH SET (MD) 7885' PACKER SET (MD) 7646' & 7828' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7700' - 80111 Perf & Remedial Cement Squeeze of 7" Csg. (07/17/02) Sqzd Additional 105 sx Class 'G' behind pipe (07/18/02) 8023' - 8043' 6564' - 6581' Squeeze Perfs 7700' - 7722' 7785' -7805' 6293' - 6311' 6363' - 6379' Freeze Protect with 140 Bbls Diesel (07/21/02) Freeze Protect with 100 Bbls Diesel, 30 Bbls MeOH (08/19/02) 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Not on Injection NIA Date of Test Hours Tested PRODUCTION FOR OIL-BBL 8/19/2002 8 TEST PERIOD 2,006 Flow Tubing Casing Pressure CALCULATED OIL-BBL Press. 24-HoUR RATE 28. Brief description of lithology, porosity, fractures, apparent dips a~~;~~~:: of oil, gas or water. Submit core ChiP,( E C E , V E D GAs-McF 3,786 GAs-McF WATER-BsL 21 WATER-BBL CHOKE SIZE 176 OIL GRAVITY-API (CORR) GAS-OIL RATIO 1,887 No eore samples were taken. SEP 1 0 2002 i, k:1~ka Oil & (jas l;Ons. t,û¡¡¡¡mSSiOt 4,nfJhOf::JiJ€ G~ Form 10-407 Rev. 07-01-80 Submit In Duplicate '" 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Schrader Bluff N Sands 4980' 4272' Schrader Bluff 0 Sands 5184' 4423' Base Schrader / Top Colville 5522' HRZ 7610' Kalubik 7868' Kuparuk D 7989' Kuparuk C 8008' Kuparuk B 8216' 4673' 6219' 6432' 6535' 6551' 6729' KEcelVtD SEP 1 0 2002 't '~Ika 011 & GaG {.;ons t;ümm:,~( I- Anmnr~Qf 31. List of Attachments: Submitted on 08/20/02: Summary of Daily Drilling Reports and Post-Rig Work, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie HUbble~l\Ì..t - t{u ~ Title Technical Assistant L -1 05i 202-058 Well Number Permit No. / Approval No. Date Oq.ocr.O~ Prepared By Name/Number: Terrie Hubble, 564-4628 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Legal Name: L-105 Common Name: L-105 Test Date 7/8/2002 Test Type Test Depth {TMD} 2,887.0 (ft) LOT BP EXPLORATION Leak-Off Tesf Sum 111 a ry Test Depth(TVD} 2,650.0 (ft) AMW 9.50 (ppg) Surface Pressure 700 (psi) Leak Off Pressure (BHP) 2,008 (psi) Page 1 of 1 EMW 14.58 (ppg) ~ Printed: 7/22/2002 9:54:19 AM ( Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L -105 L-105 DRILL +COMPLETE NABORS NABORS 9ES Start: 4/1/2002 Rig Release: 7/21/2002 Rig Number: 9-ES Spud Date: 4/1/2002 End: 7/21/2002 7/512002 00:00 - 04:00 4.00 RIGU P PRE Continue de-pressure IA and tubing on well L-106 to atmosphere. Move rig over slot L-105i. Rig up and prepare to mix mud. ACCEPT RIG ON WELL L-105i AT 04:00 HRS ON 07/05/2002. 04:00 - 08:30 4.50 RIGU P PRE Start taking on water and mixing spud mud. RlU riser valves in cellar. Mix spud mud. Load & bring BHA to rig floor. Prep same. CIO bails. 08:30 - 09:00 0.50 RIGU P PRE MIU jar stand & stand back in derrick. 09:00 - 09:30 0.50 RIGU P PRE Hold pre-spud mtg wI all personnel. 09:30 - 11 :00 1.50 RIGU P PRE MIU BHA #1 as per directional driller & RIH. Orient tools. 11 :00 - 11 :30 0.50 RIGU P PRE Fill conductor pipe, break circulation & check all lines for leaks. 11 :30 - 00:00 12.50 DRILL P SURF Spud 12 1/4" hole directionally drill from 108' to 1471'. Gyro survey every stand to 910', then RID gyro equip. 220 SPM, 650 GPM, 80 RPM, TORQ OFF 3-4k, TORQ ON 5-6k. 2260 PSI ON BTM, 1850 PSI OFF BTM, 35KWOB, P/U WT 81K, SIO 76K, ROT 77K. AST 2.71 HRS, ART 4.22 HRS 7/6/2002 00:00 - 01 :30 1.50 DRILL P SURF DIRECTIONALLY DRILL FROM 1471 TO 1751'. P/U 84K, SIO 82K, ROT 83K. TORQ OFF 3-4K, ON 4-6K. 220 SPM, 650 GAL, 2560 PSI ON, 2175 PSI OFF, 80 RPM. AST .21, ART 1.0. 01 :30 - 02:30 1.00 DRILL P SURF CIRCULATE HOLE CLEAN FOR BIT TRIP, 650 GPM, 80 RPM. 02:30 - 04:00 1.50 DRILL P SURF POOH & UD UBHO & CHANGE BIT. 04:00 - 04:30 0.50 DRILL P SURF CLEAR & CLEAN RIG FLOOR. 04:30 - 06:00 1.50 DRILL P SURF RIH TO 900'. HIT OBSTRUCTION. PUSH TO 1655'.M/U TOP DRIVE. FILL PIPE. REAM LAST STAND TO BOTTOM. 06:00 - 11 :00 5.00 DRILL P SURF DIRECTIONALLY DRILL FROM 1751 TO 2867'. TD SURFACE HOLE @ 2867' @ 1100 HRS, 7/6/2002. 220 SPM, 650 GPM, 2820 PSI ON, 2460 PSI OFF, 80 RPM, TORQ ON 7-10K, TORQ OFF 4K, 50K WOB.ART 1.34, AST 1.40. (DRILL HYDRATES F/1800 TO 2400') 11 :00 - 12:00 1.00 DRILL P SURF PUMP HI-LO VIS SWEEP & CLEAN HOLE FI SHORT TRIP. 12:00 - 13:30 1.50 DRILL P SURF MAKE SHORT TRIP TO 726'. PULLED 25K OVER@ 2700', 2350',2100',1950',1185', PULLED 35K OVER @2540'. P/U 100K, SIO 65K. 13:30 - 15:00 1.50 DRILL P SURF TRIP BACK TO BOTTOM @ 2867'. WORKED PIPE FROM 1700 TO 2700'. 15:00 - 16:00 1.00 DRILL P SURF CIRCULATE HI-LO SWEEP & CLEAN UP HOLE. 16:00 - 18:00 2.00 DRILL P SURF POOH TO RUN 9 5/8" CSG. PULLED 35K OVER @ 1850', WORKED THRU. 18:00 - 19:30 1.50 DRILL P SURF STAND BACK JARS & DCS. MILK MOTOR, BREAK OFF BIT, UD MWD, STABS, LEAD DC & MOTOR. 19:30 - 20:00 0.50 DRILL P SURF CLEAR & CLEAN RIG FLOOR. 20:00 - 20:30 0.50 DRILL P SURF P/U CASING HANGER & MAKE DUMMY RUN. 20:30 - 22:00 1.50 DRILL P SURF RlU CASING TOOLS TO RUN 9 5/8" SURF CASING. 22:00 - 00:00 2.00 DRILL P SURF HELD PJSM. MIU FLOAT EQUIP & CHECK SAME. RUN 9 5/8" SURFACE CASING AS PER PROGRAM. 28 JTS IN @ 2400 HRS. 7/7/2002 00:00 - 03:00 3.00 CASE P SURF CONTINUE RUNNING 68 JTS OF 9 5/8" 40# L-80 BTC CASING. 03:00 - 03:30 0.50 CASE P SURF MU HANGER AND LANDING JOINT. LAND CASING WITH SHOE AT 2856'. LD FRANKS TOOL AND MU HOWCO CEMENT HEAD. Printed: 7/2212002 9:54:26 AM (' BPEXPLORA TION - - , - . . - . - - Op~rati()I1$-$ummary.RêPOrt Page 2 ot8 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L -105 L-105 DRILL +COMPLETE NABORS NABORS 9ES Start: 4/1/2002 Rig Release: 7/21/2002 Rig Number: 9-ES Spud Date: 4/1/2002 End: 7/21/2002 71712002 03:30 - 05:00 1.50 CEMT P SURF CIRC & COND MUD. STAGE UP TO 10 BPM @ 700 PSI AND ADJUST RHEOLOGY FOR CEMENT JOB. 05:00 - 05:30 0.50 CEMT N RREP SURF WASHOUT IN STANDPIPE MANIFOLD. STOP CIRC AND WELD REPAIR SAME. 05:30 - 06:00 0.50 CEMT P SURF PJSM FOR CEMENT JOB. 06:00 - 06:30 0.50 CEMT P SURF CONT CIRC AND COND MUD WHILE GETTING TRUCKS IN POSITION. AIR/PRIME UP HOWCO. 06:30 - 07:00 0.50 CEMT P SURF PUMP 5 BBL WATER. TEST LINES TO 3500 PSI. PUMP 15 BBL WATER FOLLOWED BY 50 BBL ALPHA SPACER AT 11.0 PPG - 5 BPM/150 PSI. UP WT 145KLBS. DOWN WEIGHT 120 KLBS. 07:00 - 08:00 1.00 CEMT P SURF RELEASE BOTTOM PLUG. MIX & PUMP 341 BBL (465SX) PERMAFROST LAT 10.5 PPG (SURFACE WT). 6 BPM @ 150 PSI. MANDREL HANGER PLUGGED OFF BRIEFLY AT 250 BBL SLURRY AWAY. PU INTO RISER TO CLEAR AND CONTINUE RECIPROCATING - 5.5 BPM @ 150 PSI. 08:00 - 08: 15 0.25 CEMT P SURF MIX & PUMP 62 BBL (305 SX) PREMIUM G TAIL SLURRY AT 15.8 PPG. 2-4 BPM @ 50-200 PSI. 08: 15 - 09:00 0.75 CEMT P SURF RELEASE TOP PLUG AND HOWCO PUMP 10 BBL WATER TO CLEAR LINES. DISPLACE WITH 200.8 BBL MUD @ 7 BPM @ 450-850 PSI. STARTED SEEING DYE IN SPACER AND THEN GETTING GOOD CEMENT BACK 90 BBL BEFORE BUMPING PLUG. LAND CASING ON RING 50 BBL PRIOR TO BUMPING PLUG. SLOW TO 2 BPM AND BUMP PLUG AS CALC WITH 1800 PSI. CIP AT 0850 HRS. BLEED OFF PRESSURE - FLOATS HOLDING. DRAIN RISER. 09:00 - 11 :00 2.00 CEMT P SURF FLUSH FLOWLINE & RISER. BACK OUT LANDING JT. RD CEMENT EQUIPMENT. CLEAR FLOOR. 11 :00 - 12:30 1.50 BOPSUR P PROD1 ND RISER AND CONDUCTOR SPOOL. 12:30 - 14:30 2.00 WHSUR P PROD1 NU FMC SPEEDHEAD ASSEMBLY AND DSAF. TEST WELLHEAD SEAL TO 1000 PSI - OK. 14:30 - 17:00 2.50 BOPSUR P PROD1 NU BOP STACK. 17:00 - 20:00 3.00 BOPSUR P PROD1 RUN TEST PLUG AND TEST BOPE TO 250 PSI LOW, 4000 PSI HIGH, ANNULAR 3500 PSI. WITNESS OF TEST WAIVED BY CHUCK SCHEVE - AOGCC. 20:00 - 20:30 0.50 WHSUR P PROD1 PULL TEST PLUG AND INSTALL WEAR RING. 20:30 - 20:45 0.25 DRILL P PROD1 PJSM FOR PU DP. 20:45 - 23:00 2.25 DRILL P PROD1 PU DP IN SINGLES FROM PIPESHED. 23:00 - 00:00 1.00 DRILL P PROD1 SLIP & CUT 100' DRILLING LINE. 7/8/2002 00:00 - 03:00 3.00 DRILL P PROD1 PIU & STAND BACK 4" DP. 03:00 - 05:00 2.00 DRILL P PROD1 MIU 8 3/4" BIT & DIRECTIONAL BHA #3 AS PER ANADRILL DIRECTIONAL DRILLER. SHALLOW TEST MWD, OK. 05:00 - 08:00 3.00 DRILL P PROD1 RIH WI HWDP. PIU 51 SINGLES FROM PIPE SHED. PERFORM SHALLOW CASING TEST PAST TAM COLLAR. TEST TO 1000 PSI, OK. HOLD TRIP DRILL. 08:00 - 08:30 0.50 DRILL P PROD1 M/U TOP DRIVE FILL DP & BREAK CIRCULATION @ 2516'. CIRC & WASH DOWN TO 2700'. 08:30 - 09:30 1.00 DRILL P PROD1 PRESSURE TEST 9 5/8" CASING TO 3500 PSI, FOR 30 MIN, OK. CHART SAME. 09:30 - 12:00 2.50 DRILL P PROD1 REAM DOWN. TAG UP ON FLOAT COLLAR @ 2769'. DRILL OUT SHOE TRACK. TAG SHOE @ 2856'. DRILL WI 170 SPM,500 GPM, 1940 PSI ON, 1750 PSI OFF, 50 RPM, TORQ ON 4K, OFF 3.2K, PIU 105K, SIO 81K ROT 92K. WOB 5K. Printed: 7/22/2002 9:54:26 AM (' Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-105 L -105 DRILL +COMPLETE NABORS NABORS 9ES Start: 4/1/2002 Rig Release: 7/21/2002 Rig Number: 9-ES Spud Date: 4/1/2002 End: 7/21/2002 7/8/2002 09:30 - 12:00 2.50 DRILL P PROD1 DRILL RA THOLE & 20' OF NEW HOLE TO 2887'. 12:00 - 12:30 0.50 DRILL P PROD1 CIRCULATE BOTTOMS UP & SWAP MUD TO LSND @ 9.5 PPG. 12:30 - 13:00 0.50 DRILL P PROD1 PERFORM LEAK OFF TEST TO EMW OF 14.6 PPG. 13:00 - 13:30 0.50 DRILL P PROD1 ESTABLISH BENCHMARK ECD @ 10.1 PPG. 13:30 - 20:00 6.50 DRILL P PROD1 DIRECTIONALL Y DRILL FROM 2887 TO 4101'. P/U 125K, S/O 9OK, ROT 105K.TORQ ON 5K, OFF 3-4K, 600 GPM, 2540 PSI ON, 2250 PSI OFF. 20:00 - 20:30 0.50 DRILL P PROD1 CIRCULATE & PUMP HI-LO SWEEP SURFACE TO SURFACE. ECD 10.4. 20:30 - 22:30 2.00 DRILL P PROD1 POH F/ SHORT TRIP. PULL UP TO SHOE @ 2856'. STARTED SWABBING @ 3356'. BACK REAM FROM THIS POINT UP TO SHOE. CBU AT SHOE. AST 0.17 HRS, ART 2.0 HRS. MD 4007' TVD 3520'. 22:30 - 23:00 0.50 DRILL P PROD1 SERVICE TOP DRIVE. 23:00 - 00:00 1.00 DRILL P PROD1 RIH TO BOTTOM. 7/9/2002 00:00 - 15:00 15.00 DRILL P PROD1 DRILL AHEAD IN 8.75" HOLE F/4101' TO 6156' MD. CALC ECD -10.5. ACT ECD -10.8. 15:00 - 16:00 1.00 DRILL P PROD1 PUMP LO/HI VIS SWEEP AND CIRC HOLE CLEAN. 16:00 - 16:45 0.75 DRILL P PROD1 POH TO 5585' - OK. OVERPULLS TO 30 KLBS. WORK STAND #8 - SWABBING. NO GO. 16:45 - 18:30 1.75 DRILL P PROD1 KELLY UP AND BACKREAM EACH STAND OUT TO 4600'. ECD INCREASING TO 12.8 PPG. INTERMITTENT TORQUE 10-13K. 18:30 -19:00 0.50 DRILL P PROD1 STOP AND CBU WITH LOW/HIGH VIS SWEEP TO HELP REDUCE HIGH ECD PRIOR TO CONTINUE POH. 19:00 - 20:30 1.50 DRILL P PROD1 CONTINUE BACKREAMING TO 4000' 20:30 - 21 :30 1.00 DRILL P PROD1 CIRC HOLE CLEAN WITH LOW/HIGH VIS SWEEP. 21:30 - 22:30 1.00 DRILL P PROD1 TIH. HOLE LOOKS GOOD. REAM LAST STAND DOWN. 22:30 - 00:00 1.50 DRILL P PROD1 DRILL AHEAD F/6156' TO 6251'. CALC ECD 10.26 ACT ECD 10.5 @ 580 GPM. 10-15K WOB. ON BOTTOM 3250 PSI OFF BOTTOM 2900 PSI. DRILLING INTERBEDDED MUDSTONES RESULTING IN SLOWER ROP A VG. 7/10/2002 00:00 - 17:00 17.00 DRILL P PROD1 Continue drilling ahead in 8 3/4" hole from 6251' to 7465' with occasional sweep to clean hole and nutplug sweeps to clear bit balling. Start weight-up to 10.1 ppg at 7278'. 185 spm 3370 psi on btm. 3125 psi off btm. Tq on 7-8k off 7k, WOB 15k, ROP +/- 100 fph. Cal ECD 10.63 Act ECD 10.86 Slide time: 1.1 hr 85' 77fph Rotate time: 12.7 hr 1129' 89.2fph 17:00 -18:00 1.00 DRILL P PROD1 Circulate low/high vis sweep at 580 gpm 110 rpm. 18:00 - 20:00 2.00 DRILL P PROD1 TOH to shoe. Hole ok to 3262' then started to swab. Break circ & started to pack off. Circ slowly and clean up hole. Increase to 580 gpm & backream last 5 stds out to shoe. 20:00 - 21 :00 1.00 DRILL P PROD1 Circulate low/high vis pill to surface to clean up casing. 21 :00 - 00:00 3.00 DRILL P PROD1 Service topdrive. Cut and slip 45' of drill line. Change liners in #1 pump f/5.5" to 5". 7/11/2002 00:00 - 00:30 0.50 DRILL P PROD1 Finish changing liners in #1 pump to 5". 00:30 - 03:15 2.75 DRILL P PROD1 TIH took some weight at 3250', wash last stand to bottom. (change out liners in #2 while TIH) 03:15 - 04:00 0.75 DRILL P PROD1 Circulate clean up hole from trip. Calculated ECD 10.6 actual 11.4ppg. Establish new SPR Printed: 7/2212002 9:54:26 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-105 L -105 DRILL +COMPLETE NABORS NABORS 9ES Start: 4/1/2002 Rig Release: 7/21/2002 Rig Number: 9-ES Spud Date: 4/1/2002 End: 7/21/2002 7/11/2002 04:00 - 13:30 9.50 DRILL P PROD1 Drill ahead from 7465' to TD at 8360'. 580 gpm 3820 psi on btm, 3460 psi off btm. Cal ECD 10.49 Act ECD 10.75 Tq on 8-10 off 8k 1 Q...20k wob Rotating time: 6.71 hrs Sliding time: 0 hrs 13:30 -14:30 1.00 DRILL P PROD1 Pump lowlhigh vis sweep at 580 gpm with 110 rpm while working pipe. ECD= 10.57 14:30 - 17:00 2.50 DRILL P PROD1 Monitor well. TOH to 9 5/8" casing shoe. 17:00 - 17:30 0.50 DRILL P PROD1 Service topdrive. 17:30 - 18:30 1.00 DRILL P PROD1 RIH started taking weight at 3169'. Using 1 pump and rotating pipe working through to 3262'. 18:30 -19:00 0.50 DRILL P PROD1 Circulate hole clean. ECD= 10.68 19:00-21:15 2.25 DRILL P PROD1 Continue to RIH to TD no other problems. 21 :15 - 00:00 2.75 DRILL P PROD1 Circulate sweeps and condition hole. Pump 200 bbl "lube pill" to cover fl TD to 5500'. 7/12/2002 00:00 - 01 :30 1.50 DRILL P PROD1 TOH to 5497'. 01:30 - 02:15 0.75 DRILL P PROD1 Pump 195 bbl "Steel Seal" pill from 5497' to cover area up to surface casing shoe. 02:15 - 04:00 1.75 DRILL P PROD1 TOH to 2950' & run back through troublesome spot to 3355' without problems. Pull up into casing. 04:00 - 05:00 1.00 DRILL P PROD1 Circulate 25 bbl high vis pill around to clean up casing. ECD 10.9 ppg. 05:00 - 06:00 1.00 DRILL P PROD1 TOH to directional BHA. 06:00 - 08:00 2.00 DRILL P PROD1 UD Anadrill directional tools. 08:00 - 08:30 0.50 DRILL P PROD1 Layout tools and clear floor. 08:30 - 15:00 6.50 EVAL P PROD1 PJSM with SLB. RIU logging equipment. P/U tools and RIH wI PEX-BHC Sonic. No problem RIH below surface casing. Log fl TD to csg shoe. UD logging tools and RD SWS equipment. 15:00 - 15:30 0.50 WHSUR P COMP Pull wear-bushing. Flush BOP stack. 15:30 - 16:30 1.00 BOPSUR P COMP PJSM. Change out upperVBR rams to 7" csg rams. 16:30 - 17:00 0.50 BOPSUR P COMP PT door seals on upper rams to 3500 psi. Okay 17:00 - 17:30 0.50 CASE P COMP P/U 7" casing hanger and make dummy test run into wellhead. 17:30 - 18:30 1.00 CASE P COMP RIU casing running tools. 18:30 - 18:45 0.25 CASE P COMP PJSM wI crews. Review hazards and csg running tally. 18:45 - 00:00 5.25 CASE P COMP P/U shoe track and test floats. Run 7" 26# L-80 BTC-M casing. Make-up tq 8k. Break circ every 5 jts. Circl10 min every 20jts. CBU/40 jts. Hole not taking fluid while running. 7/13/2002 00:00 - 13:30 13.50 CASE P COMP Continue to run 7" 26# L-80 BTC-M casing. Break circ every 5 jts. Circ 10 min/20jts. CBU/40 jts. Reduce running speed below 2000' to 60-90 secljt. Started pushing fluid away when running faster than 1 min~t. Run 206 jts total. MU hanger and landing joint. Land casing - OK. 13:30 - 15:00 1.50 CEMT P COMP MU Howco cement head. Break circ & stage up to 7 BPM. Good circ - no losses. Start batch mixing tail slurry at 14:45 hrs. Tail slurry at weight @ 15:00 hrs. 15:00 - 15:25 0.42 CEMT P COMP Pump 5 bbl water. Test lines to 4500 psi. Pump 5 bbl water followed by 35 bbl Alpha spacer at 11.1 ppg. 4 BPM @ 200 psi. 15:25 - 15:45 0.33 CEMT P COMP Release bottom plug. Mix & pump 120 bbls Premium G with Microlite - lead slurry at 12.5 ppg. 15:45 - 15:50 0.08 CEMT P COMP Switch to tail slurry Premium wI Latex at 15.8 ppg. Approx 8 bbl into pumping tail, cement started setting in batch mixer - no longer pumpable. Abort cement job. 15:50 - 16:40 0.83 CEMT N CEMT COMP Switch to rig pumps and circulate out cement from well at 10 Printed: 7/22/2002 9:54:26 AM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-105 L -105 DRILL +COMPLETE NABORS NABORS 9ES Start: 4/1/2002 Rig Release: 7/21/2002 Rig Number: 9-ES Spud Date: 4/1/2002 End: 7/21/2002 Date. Fro1'n~To Hours/TaS~ -COOe,NPT, 7/13/2002 15:50 - 16:40 0.83 CEMT N CEMT COMP 16:40 -17:15 0.58 CEMT N CEMT COMP 17:15 -18:00 0.75 CEMT N CEMT COMP 18:00 - 19:45 1.75 CEMT N CEMT COMP 19:45 - 20:15 0.50 CEMT N CEMT COMP 20: 15 - 00:00 3.75 CEMT N CEMT COMP 7/14/2002 00:00 - 03:45 3.75 CEMT N CEMT COMP 03:45 - 05:15 1.50 CEMT N CEMT COMP 05:15 - 05:30 0.25 CEMT N CEMT COMP 05:30 - 06:00 0.50 CEMT N CEMT COMP 06:00 - 06:30 0.50 CEMT N CEMT COMP 06:30 - 07:00 0.50 CEMT N CEMT COMP 07:00 - 08:30 1.50 CEMT N CEMT COMP 08:30 - 09:30 1.00 WHSUR P COMP 09:30 - 11 :00 1.50 CEMT P COMP 11:00 -12:30 1.50 CASE P COMP 12:30 - 13:00 0.50 CASE P COMP 13:00 - 14:00 1.00 CLEAN P COMP 14:00 - 18:00 4.00 CLEAN P COMP 18:00 -19:00 1.00 CLEAN P COMP 19:00 - 20:00 1.00 CLEAN P COMP 20:00 - 00:00 4.00 RUNCOI\IP COMP 7/15/2002 00:00 - 01 :00 1.00 RUNCOI\P COMP 01 :00 - 02:00 1.00 RUNCOI\IP COMP BPM. Approx 10000 stks (575 bbl) surf»surf. Started getting cement back to surface approx 8500 stks (485 bbl away). Able to reciprocate pipe throughout. Circ out cement and contaminated mud until pumps sucking air. Returns sporadic but getting mud back at end of circulating before returns died off completely. Still able to move pipe freely. Mix up mud to circ while waiting on vac truck to turn around and bring mud back to location. Attempt to establish circulation and get returns - no success. Minimal returns on pipe upstroke but nothing on downstroke. Shut annular and pump 20 bbl mud down backside to insure ablity to freeze protect if needed. 2 bpm at 650 psi decreasing to 520 psi. Bleed off and open annular. Reciprocate pipe w/o pump. 270k up 125k dwn. Pumping 10 bbls mud every 20 min while waiting on Dowell Schlumberger to load out and test slurry properties. ETA cementers 0300 hrs. Continue to wait for Dowell cementers. Rig up DS cementing equipment and lines. Air up tanks PJSM with DS cementers, crew. Mix Mudpush spacer and batch mix tail slurry - (at weight @ 06:05 hrs). Line up to DS cementers. Pump 10 bbl CW100. Test lines to 4500 psi. Pump 10 bbl CW100 followed by 54 bbl Mudpush at 11.0 ppg. 5 BPM @ 1100 psi. Switch to lead slurry. Pump 115 bbls LiteCrete @ 12.5 ppg. Final pessure 6 BPM @ 600 psi. Follow with 37 bbls Premium G with latex at 15.8 ppg. 6 BPM @ 550 psi. Wash up cement line. Release top plug and displace cement with 100 deg seawater at 6.5-7 BPM. With cement at shoe had 1150 psi climbing to 2400 psi with 115 bbllead slurry in annulus. Slow rate to 4 BPM @ 2250 psi and final 20 bbl displacement at 2 BPM @ 2250 psi. Bump plug with 4000 psi as calculated at 316 bbl away. CIP at 0815 hrs. Hold pressure for 10 min - OK. Bleed off pressure and check floats holding - OK. Flush stack, pull landing jt. install FMC pack-off and test to 5k. Rigdown casing running equipment. Change out bales. Clean and clear floor. Change out top rams from 7" casing back to VBR. RU and test door seals to 3500 psi. OK Install wear-bushing. P/UBHA #4 for cleanout run. TlH. Tag up on float collar at 8263'. (AOGCC rep John Crisp wavied BOP test due today. No test required for remainder of well-work as scheduled. And with estimated rig move Tuesday AM) Circulate and reciprocate pipe 115 rpm's at 580 gpm 2040 psi.. Reverse circulate 20 bbl hi-vis sweep followed by 400 bbl filtered seawater. TOH laydown drillpipe Continue to laydown drillpipe. Cut and slip 114' of drill line. Printed: 7/2212002 9:54:26 AM ( ,BP-EXPtORATION. . . ~ - ~ -- . . -Ope'".ti(),.s~:SIÎ~rnàly,-~~pørt.~ Page>6of 8 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-105 L-105 DRILL +COMPLETE NABORS NABORS 9ES Start: 4/1/2002 Rig Release: 7/21/2002 Rig Number: 9-ES Spud Date: 4/1/2002 End: 7/21/2002 Date From - To Hours Task Code NPT Phase Description of Operations 7/15/2002 02:00 - 02:30 0.50 RUNCOI\IP COMP Service top drive and blocks. 02:30 - 03:30 1.00 RUNCOI\P COMP Laydown drill collars and BHA #4. Clean and clear floor. 03:30 - 05:00 1.50 RUNCOI\P COMP PJSM w/ SWLS. P/U shooting nipple. M/U luricator ext, pack-off. P/U SWLS USIT log. 05:00 - 09:00 4.00 RUNCOI\P COMP RIH USIT log f/ 3960' to 8250'. Log showing basically little or no cement behind pipe. 09:00 - 15:00 6.00 RUNCOI\ tJ CEMT COMP WOO. While waiting pulled wear-bushing and made dummy run with 4 1/2" tbg hanger, reinstall WB. Also tried to pump down 7" x 9 5/8" annulus without success. Tried various pressures. No bleed-off to indicate possible communication. Pulled casinghead valve off and found dough-like cement/mud packed in wellhead. Flushed surface lines with clear water - OK. No blockage in line. Tried to run "snake" down annulus but completely packed-off at surface. Reinstall valve assembly. Attempt to pump water down annulus. Pressured to 4200 psi and slowly bleed-off to 3600 psi after 10 min. Mixed citric acid and spotted that at wellhead. Pressured up to 4200 psi bleeding off to 3800 psi in 5 min. 15:00 - 16:00 1.00 RUNCOIVN CEMT COMP Load pipe shed with 72 jts dp. 16:00 - 17:30 1.50 RUNCOI\ tJ CEMT COMP Pick up dp and rih to 2238'. Start maintenance work on pipe skate. Replaced teflon runners for skate chain. 17:30 - 00:00 6.50 RUNCOIVN CEMT COMP Circulate hot seawater into well while maintaining 3000 psi on annulus. No bleed off. (Held weekly Toolpushers HSE meeting with crews). Continue to perform some work on pipe skate for Summer maintenance. 7/16/2002 00:00 - 02:00 2.00 RUNCOIVN CEMT COMP Continue to circulate hot seawater from 2238' 120* in 115* out. Annulus continues to maintain 3000 psi without bleeding off. Perform prep work on top drive for Summer maintenance shutdown. 02:00 - 03:30 1.50 RUNCOrvt-J CEMT COMP Pressure annulus to 4200 psi and bled down to 3800 psi after 5 min. Maintaining 4200 psi while circulating at 2238'. 03:30 - 04:30 1.00 RUNCOl\tJ CEMT COMP Bleed down annulus. TOH f/ SLB USIT log. 04:30 - 04:45 0.25 RUNCOIVN CEMT COMP Rig up shooting nipple. 04:45 - 05:00 0.25 RUNCOrvt-J CEMT COMP PJSM with SWLS and crews. 05:00 - 09:00 4.00 RUNCOl\tJ CEMT COMP P/U and RIH w/ US IT 10g.TOH 09:00 - 10:00 1.00 RUNCOl\tJ CEMT COMP UD logging tools, sheaves and shooting nipple. 10:00 - 12:00 2.00 RUNCOl\tJ CEMT COMP Load pipe shed with drillpipe and strap. 12:00 - 15:00 3.00 RUNCOI\t4 CEMT COMP Weekly pressure test of BOPE. 250 psi/low 4000 psi/high. Witnessing wavied by AOGCC rep. John Spaulding. 15:00 - 15:30 0.50 RUNCOI\'" CEMT COMP Pull test plug and install wear-bushing. 15:30 - 16:00 0.50 RUNCO""" CEMT COMP Pressure test 7" casing to 4000 psi/30 min held ok. 16:00 -17:30 1.50 RUNCOI\ tJ CEMT COMP P/U BHA #5. Same time PT choke manifold. 250 psi/low 4000 psi/high. 17:30 - 20:30 3.00 RUNCOI\ tJ CEMT COMP RIH while P/U drillpipe. 20:30 - 21 :30 1.00 RUNCOI\ tJ CEMT COMP Topdrive's 8"-flex air transfer cooling hose started unraveling, and came down out of derrick. No one injured. Hose was weather-checked. Refit new and different type of hose. 21 :30 - 22:00 0.50 RUNCOl\tJ CEMT COMP Continue p/u drillpipe 22:00 - 23:30 1.50 RUNCOrvt-J CEMT COMP TIH w/ 23 stands stood back from derrick to 8260'. 23:30 - 00:00 0.50 RUNCOrvt-J CEMT COMP Swap hole to 9.6 pgg mud. 7/17/2002 00:00 - 00:30 0.50 RUNCOI\ tJ CEMT COMP Finish displacing casing to 9.6 ppg mud. 00:30 - 03:45 3.25 RUNCOIVN CEMT COMP TOH 03:45 - 04:00 0.25 RUNCOI\ tJ CEMT COMP PJSM w/ SWLS and crews review perf gun handling Printed: 7/22/2002 9:54:26 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ( ( BP EXPLORATION Operations Summary ,Report Page 7of8 L-105 L-105 DRILL +COMPLETE NABORS NABORS 9ES Start: 4/1/2002 Rig Release: 7/21/2002 Rig Number: 9-ES Spud Date: 4/1/2002 End: 7/21/2002 Date From - To . Hours Task Code NPT Phase Description of Operations 7/17/2002 03:45 - 04:00 0.25 RUNCO"foJ CEMT COMP procedures and plan forward. 04:00 - 04:30 0.50 RUNCO"foJ CEMT COMP Install shooting nipple and p/u SWLS tools and 1 st perf gun. 04:30 - 09:30 5.00 RUNCO" foJ CEMT COMP 3 separate runs w/20' 41/2" guns w/4621 PowerFlo "Big Hole" charges @ 6spf. Tie-in to SWLS USIT log dated 7-16-02. Perf intervals: 8023' - 8043' 7785'-7805' 7700'-7022' all guns fired. Initially lined up to circulate across well from kill-line through choke-line during perforating operations. Was unable to pump through kill line. Later found kill line hose's inner rubber liner had at some time ruptured. Replaced hose with new one. 09:30 - 12:30 3.00 RUNCO"N CEMT COMP M/U 5.95" gauge ring RIH to 8000'. POH 12:30 - 18:00 5.50 RUNCO"foJ CEMT COMP P/U and RIH w/ Howco EZSV stopped at 7700' (top perf zone). POH w/EZSV. P/U and run junk basket. Retrieved piece of rubber from kill line hose. (see above). Re-ran junk basket but nothing was retrieved. 18:00 - 20:30 2.50 RUNCO""" CEMT COMP P/U EZSV and RIH. Stopped again at 7700' but was able to work through 1st and 2nd set of perf zones. Made tie-in. Set EZSV at 8008'. Confirm w/setdown. POH. 20:30 - 21 :00 0.50 RUNCOIVN CEMT COMP RID SWLS and shooting nipple. 21 :00 - 21 :30 0.50 RUNCOIVN CEMT COMP RlU to run 3.5" 9.2# EUE tbg. 21:30 - 23:30 2.00 RUNCOIVN CEMT COMP P/U Howco Star Guide stinger and 29 jts (908.65') of tbg. Make-up tq 3200ft# 23:30 - 00:00 0.50 RUNCO" N CEMT COMP Change out elevators and I/d tbg tongs. 7/18/2002 00:00 - 03:00 3.00 RUNCOIVN CEMT COMP RIH w/ BHA #6 to 7948'. 03:00 - 04:00 1.00 RUNCO""" CEMT COMP CBU establish SPR. Est. rates/choke line pressures. 04:00 - 04:50 0.83 RUNCO" N CEMT COMP P/U 15' pup jt. RIH stab into EZSV. Pressure up under packer to 1700 psi. Holding tight no bleed off to upper perf zones. 04:50 - 05:10 0.33 RUNCO" foJ CEMT COMP PJSM with DS and crews. Review balanced plug procedures. 05: 1 0 - 06:00 0.83 RUNCOIVN CEMT COMP Close annular and establish injection rates in upper perf zones. 1 bpm @ 2030psi. Call town confirm go ahead with cement job. Line up to pump spot 10 bbls of water at EOP. Batch mixing cement @ 0535 hrs. Spot 10 bbls H2O on bottom. Close bag. Breakdown perfs. Est inj rate @3 bpm wI 2040 psi. 06:00 - 09:00 3.00 RUNCO""" CEMT COMP Spot balanced 22.5 bbls 15.9 ppg squeeze slurry on bottom. Slowly pull 13 stds. Close bag. Inject 6 bbls @ 1 bpm w/1520»21 OOpsi. Hesitate 4 min. Pump 1 bbl @ 1/2 bpm w/ 1820»1950 psi. Hesitate 4 min pump 1 bbl @ 1/2 bpm w/1875»2070 psi. Hesitate 5 min. Pump 1/2 bbl @ 1/2 bpm w/1880»2050 psi. Hesitate 5 min. Pump 1/2 bbl @ 1/2 bpm w/1900»2065 psi. Hesitate 10 min. Pump 1 bbl @ 1/2 bpm w/1900»2125 psi. Hold pressure 5 min. 5 min shut-in 2020. Bleed off 09:00 - 10:00 1.00 RUNCO"N CEMT COMP CBU x2. No cement with returns. 10:00 - 12:30 2.50 RUNCOIVN CEMT COMP TOH to 3 1/2" tbg. 12:30 - 14:30 2.00 RUNCOIVN CEMT COMP UD tbg and Howco stinger BHA 14:30 - 15:00 0.50 RUNCO"foJ CEMT COMP UD tbg tongs change out elevators. Clear rig floor. 15:00 - 16:00 1.00 RUNCO"foJ CEMT COMP P/U BHA#7. 16:00 - 19:15 3.25 RUNCO"f\J CEMT COMP TIH wash last 5 stds to bottom. Tagged cement at 7598'. 19:15 - 22:15 3.00 RUNCO"f\J CEMT COMP Drill cement with 500 gpm 80 rpm's 8k wob 120-130'/hr 22: 15 - 23:45 1.50 RUNCOIVN CEMT COMP Tagged EZSC at 8007'. Drill EZSV with 250 gpm 60 rpm 2-5k wob. 23:45 - 00:00 0.25 RUNCO" N CEMT COMP TIH tagged PBTD at 8263', Printed: 7/22/2002 9:54:26 AM ( ( Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date L -105 L-105 DRILL +COMPLETE NABORS NABORS 9ES 7/19/2002 . From - To Hours Task CodeNPT Phase 00:00-01:15 1.25 RUNCOf\N CEMT COMP 01:15 - 05:00 3.75 RUNCOf\IN CEMT COMP 05:00 - 05:30 0.50 RUNCOPl'" CEMT COMP 05:30 - 06:30 1.00 RUNCOM\l CEMT COMP 06:30 - 10:30 4.00 RUNCOPlN CEMT COMP 10:30 - 11 :00 0.50 RUNCOPl '" CEMT COMP 11 :00 - 14:00 3.00 RUNCOPl P COMP 14:00 - 22:30 8.50 RUNCOrvP COMP 22:30 - 23:00 0.50 RUNCOrvP COMP 23:00 - 00:00 1.00 RUNCOrvP COMP 00:00 - 00:45 0.75 RUNCOPlP COMP 00:45 - 01 :00 0.25 RUNCOPlP COMP 01 :00 - 16:00 15.00 RUNCOPlP COMP 7/20/2002 16:00 - 18:00 2.00 RUNCOrvP COMP 18:00 - 18:30 0.50 RUNCOf\ P COMP 18:30 - 19:00 0.50 RUNCOPl P COMP 19:00 - 19:45 0.75 RUNCOrvP COMP 19:45 - 20:15 0.50 RUNCOPl P COMP 20:15 - 21 :00 0.75 RUNCOrvP COMP 21 :00 - 00:00 3.00 RUNCOPlP COMP 7/21/2002 00:00 - 01 :30 1.50 RUNCOrvP COMP 01 :30 - 03:30 2.00 RUNCOfJP COMP 03:30 - 04:00 0.50 RUNCOPl P COMP 04:00 - 07:00 3.00 RUNCOPlP COMP 07:00 - 09:00 2.00 RUNCOI\ P COMP Start: 4/1/2002 Rig Release: 7/21/2002 Rig Number: 9-ES Spud Date: 4/1/2002 End: 7/21/2002 . Description of Operations CBU x2. Displace hole over to 9.6 ppg NaCI water. TOH Standbackk HWDP & Dc's I/d jars, junk baskets and csg scrapper. Clean and clear floor. PJSM w/ SWLS and crews. RlU shooting nipple, sheaves and pack-off. P/U USIT log. Log USIT f/6750' > 8250'. UD tools and rId shooting nipple. P/U BHA #8. RIH to 8262'. TOH laying down drillpipe, drill collars. Clear floor. Pull wear-bushing. Change out bales. RlU Torque-Turn, and tbg running equipment. Continue to RlU for running 41/2" completion string. PJSM with crews. Review tbg running procedure and running order. Run 41/2" 12.6# L-80 TCII completion string. Make-up tq using Best-O-Life 2000 PTC & Torque-Turn: TCII > 2700 ft/#, NSCT > 4000 ftJ# (No fricton factor allowance used). Baker-Locked connections below Baker S-3 parker. P/U landing jt and landout in wellhead. Reverse in 275 bbls clean 9.6ppg NaCI brine followed by 40 bbl corrision inhibited brine. Drop ball/rod assembly. Pressure test tbg to 4200 psi for 30 min. Held ok. Bleed off to 2500 psi. Pressure test IA to 4000 psi for 30 min. Held ok. Bleed off IA then bleed off tbg. With tbg at 0 psi, pressure up IA to 2250 psi and shear RP valve. Reverse circ 2 bpm @ 1500 psi. Line up on tbg and try to circ. Tbg pressured up to 2200 after pumping 2 bbls. Stopped pumping and pressure bleed off to 500 psi after 3 min. Appears RP is partially shutting or restricted in some way. Check ability to reverse again @ 2 bpm..ok. Drain BOP stack. Set TWC and PT with 2800 psi from below. Nipple down BOP stack. Finish nipple down BOP stack. N/U 11" x 4" 5M adapter fig and 4 1/8" 5M production tree. Test adaptor, tree and pack-off to 5000 psi. RlU lubricator and pull TWC. RIU and reverse in 140 bbls diesel to 7" x 41/2" annulus to FP to 4100' in IA and tbg after U-tubing. Initial rate: 2 bpm @ 1900psi Final: 1.7 bpm @ 2000 psi. Install BPV and test to 1000 psi. RID lubricator. RID Little Red. Secure tree and cellar area for move. Nabors 9ES released at 0900 hrs. 7-21-2002 Move to L-103i for summer maintenance Printed: 7/22/2002 9:54:26 AM ( ( Well: Field: API: Permit: L -1 05i Prudhoe Bay Unit 50-029-23075-00 202-058 Rig Accept: 07/05/02 Rig Spud: 07/05/02 Rig Release: 07/21/02 Drilling Rig: Nabors 9ES POST RIG WORK 08/05/02 PULL B & R. PULL 1" RP SHEAR VLV @ STA 1. PULL 1" DGLV @ STA 3. SET 1" LGLV (1/4" PORT,BK) @ STA 3. SET 1" SO (5/16" PORT, BK) @ STA 1. PULLED 4-1/2" RHC. START IN WELL W/ 3.50" DUMMY GUN. 08/06/02 TAG EOT@ 7868' SLM. MD-7885. CORRECTION-17'. TAG BOTTOM @ 8119' SLM + 17' = 8136' CORRECTED DEPTH. BOTTOM SHOT TO BE 8110'. PBTD-8267' MD. BAILER HAD SAMPLE OF DRILLING MUD. RIG DOWN. NOTIFIED DSO OF WELL STATUS. 08/07/02 RAN JEWELRYfTEMP LOG FROM 8247 TO 7500, RAN 1ST GUN RUN AND PERFORATED 8104' - 8110',6 SPF --1ST GUN STUCK IN TUBING TAIL WHILE POOH AFTER FIRING -- UNABLE TO FREE, TRIED TO PUMP OUT BUT NO GO, PULLED FREE AT WIRELlNE WEAK POINT AND RETRIEVED ALL CABLE 08/14/02 RAN 4 1/2" GR & 30" X 3.70" OVERSHOT AND PLANTED ON E-LlNE TOOL STRING @ 7845' WLM. RAN 4 1/2" GS. 08/15/02 FISHED PERF GUN OUT OF TAILPIPE. NOTE: 4-6 SHOTS MISFIRED CAUSING GUN TO DEFORM - PROBLEM WITH CHARGES BEING INVESTIGATED BY SWS. 08/18/02 PERFORATED WITH POWERJET 3 3/8" 6 SPF, 60 DEG PHASING, FROM 8104'-8110',8040'-8074' AND 8012'- - 8032'. CHARGE DATA: 3406 PJ, 38.6" PENE, 0.45" EH, 22.7 GMS. WELL LEFT SI, RETURNED TO PAD OPA. 08/19/02 PUMPED 100 BBLS DIESEL DOWN IA @ 190°, FOLLOWED BY 30 BBLS NEAT MEOH. WELL SI UNTIL PRESSURE BUILDS UP. ö { 218 JTS ON RACK 8766.81 FT ON RACK CASING SUMMARY RIG WELL # CASING CASING WT. ITEM Description Includes: SIZE. TYPE, CONNECTION (JTS #-#) ITEM HES Super Seal Float Shoe 2 Jt 7" 26# L-80 BTC-Mod (#1-2) HE$.$UÞi3rsÊtål:l5l(jat..Ç(jlltir 5 Jts 7" 26# L-80 BTC-Mod (#3-7) 7" Marker Jtwl RATag in coupling 3 Jts 7" 26# L-80 BTC-Mod (#8-10) 7" Marker Jt wI RA Tag in coupling 196 Jts 7" 26# L-80 BTC-Mod (#11-206) 7' Hanger Pup Jt 7" FMC Mandrel Hanger Body RTE » Base Flange KuparukCentralizers 1 centraliser on Jt 1 2 centralisers free floating above & below stop ring on: Jts # 3,5,7,9.11.13.15,17,19 1 centraliser free floating between couplings on: Jts # 4',6, 8, 10, 12. 14. 16, 18. 20 Schrader Centralizers 1 centraliser per jt free floating on: Jts # 65 through # 84 (20 Total) Centralisers are 7" x 8 1/4" rigid straight blade ID ( Nabors 9ES Date 7/12/2002 L-105i 7" L-80 BTC-Mod 26# 206 JTS RAN 24.94 OKB TO BF 8281.30 FT RAN 83/4" TD = 8360' MD aD LENGTH TOP BOTTOM 7.70 1.64 8348.85 8350.49 7.656 80.93 8267.92 8348.85 7.70 8266;88 8267.92 7.656 202.10 8064.78 8266.88 7.656 19.83 8044;95 8064.78 7.656 121.02 7923.93 8044.95 7.656 19.87 7904.06 7923.93 7.656 7877.25 26.81 7904.06 7.656 1.32 25.49 26.81 11.25 .55 24.94 25.49 24.94 24.94 6.276 6.276 6;276 6.276 6.276 6.276 6.276 6.151 Operator: BP EXPLORATION Well: L-105 Field: PRUDHOE BAY Depth MD: 8,360.0 (ft) Est. TVD: 6,852.0 (ft) Progress: (ft) Auth Depth: 8,756.0 (ft) Hole Size: 8.750 (in) DOUDFSrrarget: 8.80/8.50/15.10 Geologist: Engineer: Supervisor: Current Status: Wait on DS cement to arrive. 24hr Summary: Run & land casing. Tail cmt prematurely set while pumping. Circ to surface. 24hr Forecast: Cement 7" casing. Make scraper cleanout run. Comments: NO INCIDENTS. NO INJURIES. NO SPILLS. HSE & Well Control All Free Days: 8 Last Envir. Incident: 3/16/2001 Last Abandonment Drill: 7/5/2002 Last Accum. Drill (D4): 6/23/2002 Last Spill Drill: 7/13/2002 Regulatory Agency Insp: N KICK WHILE DRILL (D2)7/9/2002 Pump Slow Pump Rates (Circ) Slow Pump Rates (Choke) Slow Pump Rates (Kill) Stroke Rate PressureO Stroke Rate PressureO Stroke Rate PressureO MAGEE MASKELUFEKETI Days Since Last DAFWC: 1332 Last Csg Test Press.: 3,500 (psi) Last BOP Press. Test: 7/8/2002 Next BOP Press. Test: 7/15/2002 No. Stop Cards: FIRE: LOT TVD: LOT EMW: MAASSP: Test Pressure: Kick Tolerance: Kick Volume: ROP Daily: ROP Cum.: WOB (min): WOB (max): RPM Min.: RPM DH: Torq. on Bottom: Torq. off Bottom: Type: Time/Loc: Depth: Temp: Density: Funnel Visc.: ECD: PV: YP: pH: 7/12/2002 2,650.0 (ft) 14.58 (ppg) 617 (psi) 700 (psi) (ppg) (bbl) LSND 23:00/PIT 8,360.0 (ft) (OF) 10.10 (ppg) 54 (s/qt) (ppg) 19 (cp) 20 (lb/100ft2) 11.9 From-To Hrs Phase Task Op. Depth (hr) 00:00-13:30 13.50 COMP CASE 8,350 ( ( BPEXPLORATION Daily Qperatiøns. Report Rig: NABORS 9ES 9-ES Event: DRILL +COMPLETE Well Type: DEVELOPMENT Current Well Status Casing Size: 9.625 (in) Costs in: USD Casing (MD): 2,856.0 (ft) Daily Mud: 2,312 Next Casing Size: 7.000 (in) Cum. Mud: 117,355 Next Casing (MD): 8,350.0 (ft) Daily Well: 208,987 Next Casing (TVD):6,844.0 (ft) Cum. Well: 1,399,936 Page 1 of 3 Report: 9 Date: 7/13/2002 Rig Accept: 04:007/5/2002 Rig Release: Spud Date: 4/1/2002 WX Date: Elev Ref: SEA LEVEL Program: Weather: KB Elev: 75.50 (ft) Tot. Personnel: 30 Cost Ahead 500,000 USD, Days Ahead 0.00 Lt Fog, 32 deg, 2 mph wind Last Trip Drill (D1): Last Safety Meeting: 7/10/2002 7/13/2002 Non-compliance Issued: N Operational Parameters Daily Bit Hrs: (hr) Daily Sliding Hrs:O.OO (hr) Cum. Bit Hrs: Pump Status - Drilling and Riser Pump Type Eff. Strokes Liner Size Circ. Rate 0 0 0 0 Rotating Weight: Pick Up Wt.: Slack Off Wt.: Circ. Rate Riser: Circ. Rate Hole: Circ. Off Bottom: Circ. On Bottom: Jar Hrs since Inspect: 68 (hr) Drilling Fluid 8 (lb/100ft2) Ca: 34 (lb/100ft2) K+: 5.2 (cc/30min) CaCI2: 200 (OF) NaCI: 11.2 (cc/30min) CI-: 2 (/32") Sand: 15.00 (ppb) HGS: 3.21 (ppb) LGS: 14.00 (mL) Pf/Mf: Ann. Vel. Riser: (ft/min) Ann. Vel. DC: 463.9 (ft/min) Ann. Vel. DP: 222.6 (ft/min) 92 (mg/L) (mg/L) (%) (%) 350 (mg/L) 1.00 (%) 54.56 (ppb) 55.29 (ppb) 1.15/2.2 (mUmL) ES: (mV) Solids: 9.80 (%) Oil: 2.0 (%) Water: 88.0 (%) Oil/Water: / Daily Cuttings: (bbl) Cum. Cuttings: 172.7 (bbl) Lost Downhole: 439.0 (bbl) Lost Surface: (bbl) 10 sec gels: 10 min gels: Fluid Loss: HTHP Temp: HTHP WL: Cake: MBT: Lime: PM: Activity Operations Summary Code NPT Operation RUN P Contine to run 7" 26# L-80 BTC-M casing. Break circ every 5 jts. Circ 10 min/20jts. CBU/40 jts. Reduce running speed below 2000' to 60-90 sec/jt. Started pushing fluid away when running faster than 1 min/jt. Run 206 jts total. MU hanger and landing joint. Land casing - OK. MU Howco cement head. Break circ & stage up to 7 BPM. Good circ- no losses. Start batch mixing tail slurry at 14:45 hrs. Tail slurry at weight @ 15:00 hrs. 13:30-15:00 1.50 COMP CEMT 8,350 CIR P / Printed: 7/14/2002 5:30:42 AM ( Page 1. of3 Report: 10 Date: 7/14/2002 Current Status: Laying down drillpipe. 24hr Summary: Cement 7" casing. RIH w/csg scraper & cleanout. UD drillpipe. 24hr Forecast: Finish UD drillpipe. Run USIT log. Start p/u of 41/2" tbg Comments: NO INCIDENTS. NO INJURIES. NO SPILLS. , HSE&WeIlC()ntrol All Free Days: Last Envir. Incident: 3/16/2001 Last Abandonment Drill: 7/5/2002 Last Accum. Drill (D4): 6/23/2002 Last Spill Drill: 7/14/2002 Regulatory Agency Insp: N KICK WHILE DRILL (D2)7/9/2002 Pump Slow Pump Rates (Circ) Stroke Rate Pressure{) Operator. BP EXPLORATION Well: L-105 Field: PRUDHOE BAY Depth MD: 8,360.0 (ft) Est. TVD: 6,852.0 (ft) Progress: (ft) Auth Depth: 8,756.0 (ft) Hole Size: 8.750 (in) DOUDFS/Target: 9.80/9.50/15.10 Geologist: Engineer: Supervisor: MAGEE MASKELUFEKETI Days Since Last DAFWC: 1333 Last Csg Test Press.: 3,500 (psi) Last BOP Press. Test: 717/2002 Next BOP Press. Test: 7/14/2002 No. Stop Cards: FIRE: 7/12/2002 LOT TVD: 2,650.0 (ft) LOT EMW: 14.58 (ppg) MAASSP: 617 (psi) Test Pressure: 700 (psi) Kick Tolerance: (ppg) Kick Volume: (bbl) ROP Daily: ROP Cum.: WOB (min): WOB (max): RPM Min.: RPM DH: Torq. on Bottom: (ft-Ibf) Torq. oft Bottom: (ft-Ibf) BPEXPLORATION Daily.Opøréltiöns.Report Rig: NABORS 9ES 9-ES Event: DRILL +COMPLETE Well Type: DEVELOPMENT Current Well Status Casing Size: 9.625 (in) Costs in: USD Casing (MD): 2,856.0 (ft) Daily Mud: 1,575 Next Casing Size: 7.000 (in) Cum. Mud: 118,930 Next Casing (MD): 8,350.0 (ft) Daily Well: 117,353 Next Casing (TVD):6,844.0 (ft) Cum. Well: 1,517,289 Rig Accept: 04:007/5/2002 Rig Release: Spud Date: 4/1/2002 WX Date: Elev Ref: SEA LEVEL Program: Weather: KB Elev: 75.50 (ft) Tot. Personnel: 30 Cost Ahead 350,000 USD, Days Ahead 3.00 Clear 41 deg 8m ph winds 9 Last Trip Drill (D1): Last Safety Meeting: 7/14/2002 7/14/2002 Non-compliance Issued: N Slow Pump Rates (Choke) Slow Pump Rates (Kill) Stroke Rate Pressure{) Stroke Rate Pressure{) , Operational Parameters Rotating Weight: 190,000 (Ibs) Daily Bit Hrs: (hr) Pick Up Wt.: 212,000 (Ibs) Daily Sliding Hrs:O.OO (hr) Slack OftWt.: 185,000 (Ibs) Cum. Bit Hrs: Circ. Rate Riser: Circ. Rate Hole: Ann. Vel. Riser: (ftImin) Circ. Oft Bottom: (psi) Ann. Vel. DC: (ftImin) Circ. On Bottom:3, 190 (psi) Ann. Vel. DP: (ftImin) Jar Hrs since Inspect: 68 (hr) Pump Status - Drilling and Riser Pump Type Eft. Strokes Liner Size Circ. Rate 0 () () () 8,360.0 Bits I Serial # F04JH Cum Hrs I BHA Bha Weight: 26,570 Wt Below Jars: 11,330 Cum Length OD ID Blade OD Bend Angle (ft) (in) (in) (in) (a) 0.60 6.125 3.58 4.750 1.938 8.27 4.750 1.563 282.89 4.625 2.250 285.07 4.750 2.500 314.99 5.250 2.250 959.52 5.125 PIB Bit Run # IRe-Run I Size (in) I Manuf. I Type 4 6.125 HUGHES STX-1 Cum Prog{ft) I RPM ~in/MaxlwOB ~in/Maxl Daily Hrs I Bha No: 4 Depth In: Bha Type: CLEAN OUT Depth Out: Component Component Detail BIT SUB BIT BIT SUB CSG SCRAPER DRILL COLLAR XO JAR HWDP I Nozzles 10/10/101111 Cum ROP I 0 I 0 I I TFA (in2) ¡Depth In (ft) Depth Out (ft) 0.230 8,360.0 Condition I I Jts Length (ft) 1 0.60 1 2.98 1 4.69 9 274.62 1 2.18 1 29.92 21 644.53 Connection Size (in) Type Printed: 7/15/2002 5:45:23 AM BPEXPLORATION Daily. Operations 'RØport Rig: NABORS 9ES 9-ES Event: DRILL +COMPLETE Well Type: DEVELOPMENT Drilling. Fluid (lb/10OO2) Ca: (lb/10OO2) K+: (cc/30min) CaCI2: eF) NaCI: (cc/30min) CI-: (/32") Sand: (ppb) HGS: (ppb) LGS: (mL) Pf/Mf: OpèråtiOr1$. Summary Code NPT ( Operator. BP EXPLORATION Well: L-105 Field: PRUDHOE BAY Type: Time/Lee: Depth: Temp: Density: Funnel Visc.: ECD: PV: YP: pH: SEA WATER 21 :OO/PIT 8,360.0 (ft) (OF) 8.40 (ppg) 28 (s/qt) (ppg) (cp) (lb/10OO2) 10 sec gels: 10 min gels: Fluid Loss: HTHP Temp: HTHP WL: Cake: MBT: Lime: PM: From-To Hrs Phase Task Activity Op. Depth (hr) 00:00-03:45 3.75 COMP CEMT WAIT 8,350 03:45-05:15 1.50 COMP CEMT CMT 8,350 05:15-05:30 0.25 COMP CEMT SAFETY 8,350 05:30-06:00 0.50 COMP CEMT CMT 8,350 06:00-06:30 0.50 COMP CEMT CMT 8,350 06:30-07:00 0.50 COMP CEMT CMT 8,350 07:00-08:30 1.50 COMP CEMT CMT 8,350 08:30-09:30 1.00 COMP WHSU INSTAL P 8,350 09:30-11 :00 1.50 COMP CEMT RD P 8,350 11:00-12:30 1.50 COMP CASE INSTAL P 8,350 12:30-13:00 0.50 COMP CASE INSTAL P 8,350 13:00-14:00 1.00 COMP CLEAN BHPULD P 8,350 14:00-18:00 4.00 COMP CLEAN RIH P 8,263 18:00-19:00 1.00 COMP CLEAN CIR P 8,263 19:00-20:00 1.00 COMP CLEAN CIRREV P 8,263 20:00-00:00 4.00 COMP RUNCO LD P 8,263 N CEMT Page2of3 Report: 10 Date: 7/14/2002 (mg/L) (mg/L) (%) (%) (mg/L) (%) (ppb) (ppb) I (mUmL) ES: Solids: Oil: Water: OillWater: Daily Cuttings: Cum. Cuttings: Lost Downhole: Lost Surface: (mV) (%) (%) (%) I (bbl) 172.7 (bbl) (bbl) (bbl) N CEMT Continue to wait for Dowell cementers. Operation Rig up OS cementing equipment and lines. Air up tanks PJSM with OS cementers, crew. Mix Mudpush spacer and batch mix tail slurry - (at weight @ 06:05 hrs). Line up to OS cementers. Pump 10 bbl CW100. Test lines to 4500 psi. Pump 10 bbl CW100 followed by 54 bbl Mudpush at 11.0 ppg. 5 BPM @ 1100 psi. Switch to lead slurry. Pump 115 bbls LiteCrete @ 12.5 ppg. Final pessure 6 BPM @ 600 psi. Follow with 37 bbls Premium G with latex at 15.8 ppg. 6 BPM @ 550 psi. Wash up cement line. Release top plug and displace cement with 100 deg seawater at 6.5-7 BPM. With cement at shoe had 1150 psi climbing to 2400 psi with 115 bbllead slurry in annulus. Slow rate to 4 BPM @ 2250 psi and final 20 bbl displacement at 2 BPM @ 2250 psi. Bump plug with 4000 psi as calculated at 316 bbl away. CIP at 0815 hrs. Hold pressure for 10 min - OK. Bleed off pressure and check floats holding - OK. Flush stack, pull landing jt. install FMC pack-off and test to 5k. Rigdown casing running equipment. Change out bales. Clean and clear floor. Change out top rams from 7" casing back to VBR. RU and test door seals to 3500 psi. OK Install wear-bushing. P/U BHA #4 for cleanout run. TIH. Tag up on float collar at 8263'. (AOGCC rep John Crisp wavied BOP test due today. No test required for remainder of well-work as scheduled. And with estimated rig move Tuesday AM) Circulate and reciprocate pipe 115 rpm's at 580 gpm 2040 psi.. Reverse circulate 20 bbl hi-vis sweep followed by 400 bbl filtered seawater. TOH laydown drillpipe 06:00 Update From-To Hrs Phase Task Activity Code NPT Operation Op. Depth (hr) 00:00-01 :00 1.00 COMP RUNCO LO P Continue to laydown drillpipe. 8,263 01 :00-02:00 1.00 COMP RUNCO RIGSER P Cut and slip 114' of drill line. 8,263 I P N CEMT N CEMT N CEMT N CEMT Printed: 7/1512002 5:45:23 AM ( From-To Hrs Phase Task Activity Op. Depth (hr) 02:00-02:30 0.50 COMP RUNCO RIGSER 8,263 02:30-03:30 1.00 COMP RUNCO lD 8,263 03:30-05:00 1.50 COMP RUNCO lOG 8,263 05:00-06:00 1.00 COMP RUNCO lOG 8,263 BPEXPLORATION Daily. Operations. R~pørt Rig: NABORS 9ES 9-ES Event: DRill +COMPlETE Well Type: DEVELOPMENT 06:00 Update NPT Page 30f3 Report: 10 Date: 7/14/2002 Operator: BP EXPLORATION Well: l-105 Field: PRUDHOE BAY Code Operation P Service topdrive and blocks. P laydown drill collars and BHA #4. Clean and clear floor. P PJSM wI SWlS. P/U shooting nipple. M/U luricator ext, pack-off. P/U SWlS US IT log. RIH wI log P Item Mud Log Information I Form. Top MD. 4.0 (ft) I Bkgrnd Gas Conn. Gas Materials I Consumption Usage On Hand Item 0 (ppm) I Trip Gas (ppm) Pore. Press (ppm) (ppg) Formation MllUVICH lithology SHALE Company No. Hours 2 2 0 Company NABORS ANADRlll SCHlUMBERGER No. Hours 2 0 Company NABORS ANADRlll SCHlUMBERGER No. Hours 24 0 BP BAROID PETROTECHNICAl RESOUR Phase SURF PRE PROD1 COMP TOTALS Prod % Total 47.00 98.9% 11.50 100.0% 124.00 100.0% 40.58 71.2% 223.08 93.0% Cumulative Phase Breakdown Planned Change of Scope NPT % Total WOW % Total Prod % Total NPT % Total WOW % Total 0.50 1.1% 16.42 28.8% 16.92 7.1% 0.00 0.0% 0.00 0.0% Remarks 0.00 0.0% 0.00 0.0% Total Hours 47.50 11.50 124.00 57.00 240.00 Total Cost USD 516,403.40 11,500.00 829,241.14 115,778.00 1,472,922.5 Printed: 7/15/2002 5:45:23 AM BP EXPLORATION Daily, QpE!l"élti()l1sRE!P()rt Rig: NABORS 9ES 9-ES Event: DRILL +COMPLETE Well Type: DEVELOPMENT CurrentWeUStatus Depth MD: 8,360.0 (ft) Casing Size: 9.625 (in) Costs in: USD Est. TVD: 6,852.0 (ft) Casing (MD): 2,856.0 (ft) Daily Mud: 1,433 Progress: (ft) Next Casing Size: 7.000 (in) Cum. Mud: 120,362 Auth Depth: 8,756.0 (ft) Next Casing (MD): 8,350.0 (ft) Daily Well: 125,359 Hole Size: 8.750 (in) Next Casing (TVD):6,844.0 (ft) Cum. Well: 1,657,148 DOUDFSlTarget: 10.80/10.50/15.10 Geologist: Engineer: Supervisor: Operator: BP EXPLORATION Well: L-105 Field: PRUDHOE BAY MAGEE MASKELUFEKETI Days Since Last DAFWC: 1334 Last Csg Test Press.: 3,500 (psi) Last BOP Press. Test: 717/2002 Next BOP Press. Test: 7/14/2002 No. Stop Cards: FIRE: 7/12/2002 LOT TVD: 2,650.0 (ft) LOT EMW: 14.58 (ppg) MAASSP: 617 (psi) Test Pressure: 700 (psi) Kick Tolerance: (ppg) Kick Volume: (bbl) Rap Daily: ROP Cum.: WOB (min): WOB (max): RPM Min.: RPM DH: Torq. on Bottom: Torq. oft Bottom: ( Page1()f3 Report: 11 Date: 7/15/2002 Rig Accept: 04:007/5/2002 Rig Release: Spud Date: 4/1/2002 WX Date: Elev Ref: SEA LEVEL Program: Weather: KB Elev: 75.50 (ft) Tot. Personnel: 30 Cost Ahead 250,000 USD, Days Ahead 2.00 Clear 41deg 8mph winds Operational Parameters Daily Bit Hrs: (hr) Daily Sliding Hrs:O.OO (hr) Cum. Bit Hrs: Rotating Weight: Pick Up Wt.: Slack Oft Wt.: Circ. Rate Riser: Circ. Rate Hole: Circ. Oft Bottom: Circ. On Bottom: Jar Hrs since Inspect: 68 (hr) Ann. Vel. Riser: (ftImin) Ann. Vel. DC: (ftImin) Ann. Vel. DP: (ftlmin) Current Status: Circulate hot seawater at 2238'. 24hr Summary: UD DP and BHA. RIU and run SLB USIT log. Questionable cmt. WOC. 24hr Forecast: wac. Re-run USIT log. Comments: NO INCIDENTS. NO INJURIES. NO SPILLS. HSE & Well Control All Free Days: 10 Last Envir. Incident: 3/16/2001 Last Abandonment Drill: 7/5/2002 Last Accum. Drill (04): 6/23/2002 Last Spill Drill: 7/14/2002 Regulatory Agency Insp: N KICK WHILE DRILL (02)7/9/2002 Pump Slow Pump Rates (Circ) Slow Pump Rates (Choke) Slow Pump Rates (Kill) Stroke Rate Pressure() Stroke Rate Pressure() Stroke Rate Pressure() 1 1 1 9 1 1 21 Length (ft) 0.60 2.98 4.69 274.62 2.18 29.92 644.53 Bits I Serial # F04JH Cum Hrs I BHA Bha Weight: Wt Below Jars: Cum Length 00 10 (ft) (in) (in) 0.60 6.125 3.58 4.750 1.938 8.27 4.750 1.563 282.89 4.625 2.250 285.07 4.750 2.500 314.99 5.250 2.250 959.52 5.125 Bit Run # IRe-Run I Size (in) I Manuf. I Type 4 6.125 HUGHES STX-1 Cum Prog(ft) I RPM ~inlMaX I WOB ~in/Maxl Daily Hrs I Last Trip Drill (01): Last Safety Meeting: 7/14/2002 7/15/2002 Non-compliance Issued: N Pump Status - Drilling and Riser Pump Type Eft. Strokes Liner Size Circ. Rate () () () 0 I Nozzles 10/10/10//11 Cum ROP I 0 I 0 I I TFA (in2) I Depth In (ft) Depth Out (ft) 0.230 8,360.0 8,360.0 Condition I I Bha No: 4 Depth In: 8,360.0 Bha Type: CLEAN OUT Depth Out: 8,360.0 Component Component Detail Jts BIT SUB BIT BIT SUB CSG SCRAPER DRILL COLLAR XO JAR HWDP Blade 00 Bend Angle (in) (°) Connection Size (in) Type P/B Printed: 7/16/2002 5:51 :13 AM BPEXPLORATION Délily .Qp~..êlti()l'1s.R~p()rt Rig: NABORS 9ES 9-ES Event: DRILL +COMPLETE Well Type: DEVELOPMENT Drilling.Fluid (lb/10OO2) Ca: (lb/10OO2) K+: (cc/30min) CaCI2: eF) NaCI: (cc/30min) CI-: (/32") Sand: (ppb) HGS: (ppb) LGS: (mL) Pf/Mf: ( Operator: BP EXPLORATION Well: L-105 Field: PRUDHOE BAY Type: Time/Loc: Depth: Temp: Density: Funnel Vise.: ECD: PV: YP: pH: 10 see gels: 10 min gels: Fluid Loss: HTHP Temp: HTHP WL: Cake: MBT: Lime: PM: SEA WATER 22:00/PIT 8,360.0 (ft) (OF) 8.40 (ppg) 28 (s/qt) (ppg) (cp) (lb/10OO2) From-To Hrs Phase Task Activity Op. Depth (hr) 00:00-01 :00 1.00 COMP RUNCO LD 8,263 01 :00-02:00 1.00 COMP RUNCO RIGSER 8,263 02:00-02:30 0.50 COMP RUNCO RIGSER 8,263 02:30-03:30 1.00 COMP RUNCO LD 8,263 03:30-05:00 1.50 COMP RUNCO LOG 8,263 05:00-09:00 4.00 COMP RUNCO LOG 8,263 09:00-15:00 6.00 COMP RUNCO WAIT 8,263 ( Page 2 of3 Report: 11 Date: 7/15/2002 (mg/L) (mg/L) (%) (%) 15,000 (mg/L) (%) (ppb) (ppb) I (mUmL) ES: Solids: Oil: Water: OillWater: Daily Cuttings: Cum. Cuttings: Lost Downhole: Lost Surface: (mV) (%) (%) (%) / (bbl) 172.7 (bbl) (bbl) (bbl) Opèrations. Summary Code NPT P P P P P P N CEMT 15:00-16:00 1.00 COMP RUNCO PU N CEMT 8,263 16:00-17:30 1.50 COMP RUNCO PU N CEMT 8,263 17:30-00:00 6.50 COMP RUNCO CIR N CEMT 8,263 Operation Continue to laydown drillpipe. Cut and slip 114' of drill line. Service top drive and blocks. Laydown drill collars and BHA #4. Clean and clear floor. PJSM wI SWLS. P/U shooting nipple. M/U luricator ext, pack-off. P/U SWLS USIT log. RIH US IT log fl 3960' to 8250'. Log showing basically little or no cement behind pipe. WOO. While waiting pulled wear-bushing and made dummy run with 4 1/2" tbg hanger, reinstall WB. Also tryed to pump down 7" x 9 5/8" annulus without success. Tryed various pressures. No bleed-off to indicate possible communication. Pulled casinghead valve off and found dough-like cement/mud packed in wellhead. Flushed surface lines with clear water - OK. No blockage in line. Tried to run "snake" down annulus but completely packed-off at surface. Reinstall valve assembly. Attempt to pump water down annulus. Pressured to 4200 psi and slowly bleed-off to 3600 psi after 10 min. Mixed citric acid and spotted that at wellhead. Pressured up to 4200 psi bleeding off to 3800 psi in 5 min. Load pipe shed with 72 jts dp. Pick up dp and rih to 2238'. Start maintenance work on pipe skate. Replaced teflon runners for skate chain. Circulate hot seawater into well while maintaining 3000 psi on annulus. No bleed off. (Held weekly Toolpushers HSE meeting with crews). Continue to perform some work on pipe skate for Summer maintenance. 06:00 Update From-To Hrs Phase Task Activity Code NPT Operation Op. Depth (hr) 00:00-02:00 2.00 COMP RUNCO CIR N CEMT Continue to circulate hot seawater from 2238' 120* in 115* out. 8,263 Annulus continues to maintain 3000 psi without bleeding off. Perform prep work on top drive for Summer maintenance shutdown. 02:00-03:30 1.50 COMP RUNCO CIR N CEMT Pressure annulus to 4200 psi and bled down to 3800 psi after 5 min. 8,263 Maintaining 4200 psi while circulating at 2238'. 03:30-04:30 1.00 COMP RUNCO POH N CEMT Bleed down annulus. TOH fl SLB USIT log. 8,263 04:30-04:45 0.25 COMP RUNCO RU N CEMT Rig up shoot nipple. 8,263 04:45- 0.00 COMP RUNCO SAFETY N CEMT PJSM with SWLS and crews. 8,263 Printed: 7/16/2002 5:51:13 AM Operator. BP EXPLORATION Well: L-105 Field: PRUDHOE BAY Formation MILUVICH Uthology SHALE DIESEL Item Company BP BAROID PETROTECHNICAL RESOUR Phase SURF PRE PROD1 COMP TOTALS Prod % Total 47.00 98.9% 11.50 100.0% 124.00 100.0% 49.58 61.2% 232.08 87.9% BPEXPLORATION , paily()perati()nsR~port Rig: NABORS 9ES 9-ES Event: DRILL +COMPLETE Well Type: DEVELOPMENT M udLog Inforrnåtion I Form. Top MD. 4.0 (ft) I Bkgrnd Gas Conn. Gas Materials IConsurnption I Units I Usage I On Hand I Item GAL 1032 7344 BARITE Personnel Company NABORS ANADRILL SCHLUMBERGER ( No. 2 2 0 Hours No. Hours 2 0 ( (ppm) I Trip Gas (ppm) Pore. Press Page30f3 Report: 11 Date: 7/15/2002 (ppm) (ppg) Company NABORS ANADRILL SCHLUMBERGER Cumulative Phase Breakdown Planned Change of Scope NPT % Total WOW % Total Prod % Total NPT % Total WOW % Total 0.50 1.1% 31.42 38.8% 31.92 12.1% 0.00 0.0% 0.00 0.0% Remarks 0.00 0.0% 0.00 0.0% Total Hours 47.50 11.50 124.00 81.00 264.00 No. Hours 24 0 Total Cost USD 516,403.40 34,875.00 843,742.14 215,849.26 1,610,869.8 Printed: 7/1612002 5:51:13 AM BPEXPLORATl(>N DailY'.'Qperåti()r1$.R~port Rig: NABORS 9ES 9-ES Event: DRILL +COMPLETE Well Type: DEVELOPMENT CurrentWeUStatU$ Depth MD: 8,360.0 (ft) Casing Size: 9.625 (in) Costs in: USD Est. TVD: 6,852.0 (ft) Casing (MD): 2,856.0 (ft) Daily Mud: 1,416 Progress: (ft) Next Casing Size: 7.000 (in) Cum. Mud: 121,778 Auth Depth: 8,756.0 (ft) Next Casing (MD): 8,350.0 (ft) £?~ily Well: 90,376 Hole Size: 8.750 (in) Next Casing (TVD):6,844.0 (ft} - çum. Well: 1.747,524 DOUDFSlTarget: 11.80/11.50/15.10 Geologist: Engineer: Supervisor: ( Operator: BP EXPLORATION Well: L-105 Field: PRUDHOE BAY ( , Page1of3 Report: 12 Date: 7/1612002 Rig Accept: 04:007/5/2002 Rig Release: Spud Date: 4/1/2002 WX Date: Elev Ref: SEA LEVEL MAGEE ANGLEN/FEKETI Program: Weather: KB Elev: 75.50 (ft) Tot. Personnel: 30 Cost Ahead 200,000 USD, Days Ahead 1.75 Clear 60* calm & mosquitos Current Status: 24hr Summary: 24hr Forecast: Comments: Displacing casing over to 9.6 ppg mud. Run 2nd USIT log. Test BOP's. P/U drillpipe RIH to PBTD. Displace to mud. Perf Kuparuk. Set EZSV & remedial cmt same. PU cleanout BHA Topdrive's 8" air cooling hose feel from upper attachment point to rig floor. Portion of it hit floorhand on top of hardhat. No injuries. HSE,&.Well.Control All Free Days: Last Envir. Incident: 3/16/2001 Last Abandonment Drill: 7/5/2002 Last Accum. Drill (D4): 7/16/2002 Last Spill Drill: . 7/14/2002 Regulatory Agency Insp: N KICK WHILE DRILL (D2)7/9/2002 Pump Slow Pump Rates (Circ) Stroke Rate Pressure() 11 Days Since Last DAFWC: 1335 Last Csg Test Press.: 4,000 (psi) Last BOP Press. Test: 7/16/2002 Next BOP Press. Test: 7/23/2002 No. Stop Cards: FIRE: 7/12/2002 Slow Pump Rates (Choke) Slow Pump Rates (Kill) Stroke Rate Pressure() Stroke Rate Pressure() LOT TVD: 2,650.0 (ft) LOT EMW: 14.58 (ppg) MAASSP: 617 (psi) Test Pressure: 700 (psi) Kick Tolerance: (ppg) Kick Volume: (bbl) ROP Daily: ROP Cum.: WOB (min): WOB (max): RPM Min.: RPM DH: Torq. on Bottom: Torq. off Bottom: Operational Parameters Daily Bit Hrs: (hr) Daily Sliding Hrs:O.OO (hr) Cum. Bit Hrs: Rotating Weight: Pick Up Wt.: Slack Off Wt.: Circ. Rate Riser: Circ. Rate Hole: Circ. Off Bottom: Circ. On Bottom: Jar Hrs since Inspect: 68 (hr) Ann. Vel. Riser: (ftImin) Ann. Vel. DC: (ftImin) Ann. Vel. DP: (ftImin) Bit Run # IRe-Run I Size (in) I Manuf. I Type 5 Y 6.125 HUGHES STX-1 Cum Prog(ft) I RPM ~in/MaxlwOB ~in/Maxl Daily Hrs I Bits Serial # F04JH Cum Hrs I BHA Bha Weight: Wt Below Jars: Cum Length OD 10 (ft) (in) (in) 0.60 6.125 3.58 4.750 1.938 278.51 4.625 2.250 280.69 4.750 2.500 310.64 5.250 2.250 955.22 5.125 Last Trip Drill (D1): Last Safety Meeting: 7/16/2002 7/16/2002 Non-compliance Issued: N Pump Status - Drilling and Riser Pump Type Eff. Strokes Liner Size Circ. Rate () () () () I Nozzles 111111 Cum ROP I 0 I 0 I I TFA (in2) IDepth In (ft) Depth Out (ft) 8,360.0 Condition I I Bha No: 5 Depth In: Bha Type: CLEAN OUT Depth Out: Component Component Detail 8,360.0 Jts Length (ft) 1 0.60 1 2.98 9 274.93 1 2.18 1 29.95 21 644.58 BIT SUB BIT BIT SUB DRILL COLLAR XO JAR HWDP Blade 00 Bend Angle (in) n Connection Size (in) Type P/B Printed: 7/17/2002 6:29:09 AM (' BPEXPLORATION Daily . Qperåti()rls . R~p()rt Rig: NABORS 9ES 9-ES Event: DRILL +COMPLETE Well Type: DEVELOPMENT Drilling.FIUid 6 (lb/10OO2) Ca: 14 (lb/10OO2) K+: 13.0 (ccI30min) CaCI2: (OF) NaCI: (ccl30min) CI-: 2 (/32") Sand: 11.30 (ppb) HGS: 1.20 (ppb) LGS: 7.50 (mL) Pf/Mf: Page2of3 Report: 12 Date: 7/16/2002 Operator: BP EXPLORATION Well: L-105 Field: PRUDHOE BAY (mV) 8.70 (%) 1.0 (%) 90.0 (%) I (bbl) 172.7 (bbl) (bbl) (bbl) 340 (mg/L) (mg/L) (%) (%) 2,400 (mg/L) 0.20 (%) 17.03 (ppb) 68.73 (ppb) 0.40/2.4 (mUmL) ES: Solids: Oil: Water: Oil/Water: Daily Cuttings: Cum. Cuttings: Lost Downhole: Lost Surface: 10 sec gels: 10 min gels: Fluid Loss: HTHP Temp: HTHP WL: Cake: MBT: Lime: PM: LSND 22:00/PIT 8,360.0 (ft) eF) 9.65 (ppg) 42 (s/qt) (ppg) 13 (cp) 16 (lb/10OO2) 11.6 Type: Time/Loc: Depth: Temp: Density: Funnel Visc.: ECD: PV: YP: pH: Operations Summary Code NPT Operation Activity From-To Hrs Phase Task Op. Depth (hr) 00:00-02:00 2.00 COMP RUNCO 8,263 Continue to circulate hot seawater from 2238' 120* in 115* out. Annulus continues to maintain 3000 psi without bleeding off. Perform prep work on top drive for Summer maintenance shutdown. Pressure annulus to 4200 psi and bled down to 3800 psi after 5 min. Maintaining 4200 psi while circulating at 2238'. Bleed down annulus. TOH f/ SLB US IT log. CEMT CIR N CEMT 02:00-03:30 1.50 COMP RUNCO CIR N 8,263 03:30-04:30 1.00 COMP RUNCO POH N 8,263 04:30-04:45 0.25 COMP RUNCO RU N 8,263 04:45-05:00 0.25 COMP RUNCO SAFETY N 8,263 05:00-09:00 4.00 COMP RUNCO LOG N 8,263 09:00-10:00 1.00 COMP RUNCO LOG N 8,263 10:00-12:00 2.00 COMP RUNCO PU N 8,263 12:00-15:00 3.00 COMP RUNCO TSTPRS N 8,263 15:00-15:30 0.50 COMP RUNCO PUL N 8,263 15:30-16:00 0.50 COMP RUNCO TSTPRS N 8,263 16:00-17:30 1.50 COMP RUNCO BHPULD N 8,263 17:30-20:30 3.00 COMP RUNCO PU N 8,263 20:30-21 :30 1.00 COMP RUNCO INSTAL N 8,263 21 :30-22:00 0.50 COMP RUNCO PU N 8,263 22:00-23:30 1.50 COMP RUNCO RIH N 8,263 23:30-00:00 0.50 COMP RUNCO CIR N 8,263 From-To Hrs Phase Task Activity Code Op. Depth (hr) 00:00-00:30 0.50 COMP RUNCO CIR N 8,263 00:30-03:45 3.25 COMP RUNCO POH N 8,263 03:45-04:00 0.25 COMP RUNCO SAFETY N 8,263 04:00-04:30 0.50 COMP RUNCO RU N 8,263 CEMT Rig up shooting nipple. CEMT PJSM with SWLS and crews. CEMT CEMT P/U and RIH w/ USIT log.TOH UD logging tools, sheaves and shooting nipple. CEMT Load pipe shed with drillpipe and strap. CEMT CEMT Weekly pressure test of BOPE. 250 psi/low 4000 psi/high. Witnessing wavied by AOGCC rep. John Spaulding. CEMT Pull test plug and install wear-bushing. Pressure test 7" casing to 4000 psi/30 min held ok. CEMT CEMT P/U BHA #5. Same time PT choke manifold. 250 psillow 4000 psi/high. CEMT RIH while P/U drill pipe. Topdrive's 8"-flex air transfer cooling hose started unraveling, and came down out of derrick. No one injured. Hose was weather-checked. Refit new and different type of hose. Continue p/u drillpipe CEMT CEMT TIH w/ 23 stands stood back from derrick to 8260'. CEMT CEMT Swap hole to 9.6 pgg mud. 06:00 Update NPT Operation Finish displacing casing to 9.6 ppg mud. CEMT CEMT TOH PJSM w/ SWLS and crews review perf gun handling procedures and plan forward. Install shooting nipple and p/u SWLS tools and 1st perf gun. CEMT CEMT Printed: 7/17/2002 6:29:09 AM (' (" BPEXPLORATION Paily.Operatiohs.Repørt ' Rig: NABORS 9ES 9-ES Event: DRILL +COMPLETE Well Type: DEVELOPMENT 06:00 Update NPT Operator. BP EXPLORATION Well: L-105 Field: PRUDHOE BAY Report: 12 Date: 7/16/2002 From-To Hrs Phase Task Op. Depth (hr) 04:30- 0.00 COMP RUNCO 8,263 Activity Code Operation RIH N CEMT RIH Company No. Hours 2 2 0 , Mud Log Information ¡Form. Top MD. 4.0 (ft) Bkgmd Gas Conn. Gas Måterials I Consumption I Units I Usage I On Hand I Item GAL 0 7344 BARITE Personnel Company NABORS ANADRILL SCHLUMBERGER Formation MILUVICH Lithology SHALE (ppm) I Trip Gas (ppm) Pore. Press (ppm) (ppg) Item I Units TON I Usage I On Hand 0 14.2 DIESEL BP BAROID PETROTECHNICAL RESOUR No. Hours 2 0 Company NABORS ANADRILL SCHLUMBERGER No. Hours 24 0 Phase SURF PRE PROD1 COMP TOTALS Prod % Total 47.00 98.9% 11.50 100.0% 124.00 100.0% 49.58 47.2% 232.08 80.6% Cumulåtive. Phase Breakdown Planned Change of Scope NPT % Total WOW % Total Prod % Total NPT % Total WOW % Total 0.50 1.1% 55.42 52.8% 55.92 19.4% 0.00 0.0% 0.00 0.0% Remarks 0.00 0.0% 0.00 0.0% Total Hours 47.50 11.50 124.00 105.00 288.00 Total Cost USD 516,403.40 34,875.00 843,742.14 306,225.12 1,701 ,245.6 Printed: 7/17/2002 6:29:09 AM BPEXPLORATION Paily.Qpèrêlti()t1s.R~p()" Rig: NABORS 9ES 9-ES Event: DRILL +COMPLETE Well Type: DEVELOPMENT CurrentWéUStåtus Depth MD: 8,360.0 (ft) Casing Size: 9.625 (in) Costs in: USD Est. TVD: 6,852.0 (ft) Casing (MD): 2,856.0 (ft) Daily Mud: 1,140 Progress: (ft) Next Casing Size: 7.000 (in) Cum. Mud: 122,918 Auth Depth: 8,756.0 (ft) Next Casing (MD): 8,350.0 (ft) Daily Well: 82,803 Hole Size: 8.750 (in) Next Casing (TVD):6,844.0 (ft) Cum. Well: 1,830,327 DOUDFSIT arget: 12.80/12.50/15.10 Geologist: Engineer: Supervisor: Operator: BP EXPLORATION Well: L-105 Field: PRUDHOE BAY MAGEE ANGLEN/FEKETI ( Pagë1 of3 Report: 13 Date: 7/17/2002 Rig Accept: 04:007/5/2002 Rig Release: Spud Date: 4/1/2002 WX Date: Elev Ref: SEA LEVEL Program: Weather: KB Elev: 75.50 (ft) Tot. Personnel: 30 Cost Ahead 0 USD, Days Ahead 0.00 Clear 46* 10 mph winds Current Status: Pick-up 3 1/2" tbg tailpipe. 24hr Summary: Perforate at selected intervals. Set EZSV. P/U stinger & 31/2" tailpipe. 24hr Forecast: RIH w/cmt BHA. Sqz cmt Kuparuk. PU cleanout BHA & WOC Comments: No Accidents No Spills. Days Since Last DAFWC: 1336 Last Csg Test Press.: 4.000 (psi) Last BOP Press. Test: 7n/2002 Next BOP Press. Test: 7/14/2002 No. Stop Cards: FIRE: 7/12/2002 LOT TVD: 2.650.0 (ft) LOT EMW: 14.58 (ppg) MAASSP: 617 (psi) Test Pressure: 700 (psi) Kick Tolerance: (ppg) Kick Volume: (bbl) HSE & Well Control All FreeDays: Last Envir. Incident: 3/16/2001 Last Abandonment Drill: 7/5/2002 Last Accum. Drill (D4): 6/23/2002 Last Spill Drill: 7/17/2002 Regulatory Agency Insp: N KICK WHILE DRILL (D2)7/9/2002 Pump Slow Pump Rates (Circ) Stroke Rate PressureO 12 Last Trip Drill (D1): Last Safety Meeting: 7/17/2002 7/16/2002 Non-compliance Issued: N Slow Pump Rates (Choke) Slow Pump Rates (Kill) Stroke Rate PressureO Stroke Rate PressureO Operational Parameters Daily Bit Hrs: (hr) Daily Sliding Hrs:O.OO (hr) Cum. Bit Hrs: ROP Daily: ROP Cum.: WOB (min): WOB (max): RPM Min.: RPM DH: Torq. on Bottom: Torq. off Bottom: Rotating Weight: Pick Up Wt.: Slack Off Wt.: Circ. Rate Riser: Circ. Rate Hole: Circ. Off Bottom: Circ. On Bottom: Jar Hrs since Inspect: 68 (hr) Bit Run # IRe-Run I Size (in) 1 Manuf. I Type 5 Y 6.125 HUGHES STX-1 Cum Prog(ft) RPM ~in/MaxlwOB ~in/Maxl Daily Hrs I Bha No: 5 Depth In: 8.360.0 Bha Type: CLEAN OUT Depth Out: 8.360.0 Component Component Detail Jts BIT SUB BIT BIT SUB DRILL COLLAR XO JAR HWDP Bha No: 6 Depth In: Bha Type: Depth Out: Component Component Detail Star Guide Stinger XO 1 1 9 1 1 21 8,360.0 Jts Length (ft) 4.17 0.95 Ann. Vel. Riser: (ftImin) Ann. Vel. DC: (ftlmin) Ann. Vel. DP: (ftImin) Length (ft) 0.60 2.98 274.93 2.18 29.95 644.58 Bits I Serial # F04JH Cum Hrs I BHA Bha Weight: Wt Below Jars: Cum Length OD ID (ft) (in) (in) 0.60 6.125 3.58 4.750 1.938 278.51 4.625 2.250 280.69 4.750 2.500 310.64 5.250 2.250 955.22 5.125 Bha Weight: Wt Below Jars: Cum Length OD ID (ft) (in) (in) 4.17 5.500 5.12 4.750 Pump Status - Drilling and Riser Pump Type Eff. Strokes Liner Size Circ. Rate 0 0 0 0 I Nozzles 1/11/1 Cum ROP I 0 I 0 I I TFA (in2) IDepth In (ft)1 Depth Out (ft) 8,360.0 8,360.0 Condition I I Blade OD Bend Angle (in) (°) Connection Size (in) Type P/B Blade OD Bend Angle (in) (°) Connection Size (in) Type I P/B Printed: 7/18/2002 5:46:13 AM Operator: BP EXPLORATION Well: L-105 Field: PRUDHOE BAY (; Bha No: 6 Depth 1m Bha Type: Depth Out: Component Component Detail Type: Time/Loc: Depth: Temp: Density: Funnel Vise.: ECD: PV: YP: pH: From-To Op. Depth 00:00-00:30 8,263 00:30-03:45 8,263 03:45-04:00 8,263 04:00-04:30 8,263 04:30-09:30 8,263 TUBING XO XO STDS. DRILLPIPE LSND 22:00/PIT 8,360.0 (ft) (OF) 9.65 (ppg) 41 (slqt) (ppg) 10 (cp) 13 (lb/10OO2) 11.5 Hrs Phase Task (hr) 0.50 COMP RUNCO 3.25 COMP RUNCO 10 see gels: 10 min gels: Fluid Loss: HTHP Temp: HTHP WL: Cake: MBT: Lime: PM: Activity CIR 0.25 COMP RUNCO SAFETY POH 0.50 COMP RUNCO 5.00 COMP RUNCO PERF 09:30-12:30 3.00 COMP RUNCO 8,263 12:30-18:00 5.50 COMP RUNCO SETOTR 8,263 CAL 18:00-20:30 2.50 COMP RUNCO SETOTR 8,263 20:30-21 :00 8,263 21 :00-21 :30 8,263 21 :30-23:30 8,263 23:30-00:00 8,263 From-To Op. Depth 00:00-03:00 8,263 03:00-04:00 8,263 0.50 COMP RUNCO SETOTR 0.50 COMP RUNCO BHPULD 2.00 COMP RUNCO BHPULD 0.50 COMP RUNCO BHPULD Hrs Phase Task (hr) 3.00 COMP RUNCO 1.00 COMP RUNCO Activity RIH CIR BPEXPLORATION Daily.Qperati()ns.RE!P()rt Rig: NABORS 9ES 9-ES Event: DRILL +COMPLETE Well Type: DEVELOPMENT BHA Bha Weight: Wt Below Jars: Cum Length 00 10 Blade OD Bend Angle (ft) (in) (in) (in) (°) 913.77 3.500 915.11 4.750 917.29 5.130 8,008.79 4.000 RU 8,360.0 Jts Length (ft) 29 908.65 1.34 2.18 93 7,091.50 4 (lb/10OO2) 10 (lb/10OO2) 17.7 (cc/30min) (OF) (ccl30min) 3 (/32") 10.00 (ppb) 1.60 (ppb) 6.50 (mL) ( Pagë2of3 Report: 13 Date: 7/17/2002 Connection Size (in) Type P/B K+: CaCI2: NaCI: CI-: Sand: HGS: LGS: Pf/Mf: 360 (mg/L) (mg/L) (%) (%) 2,700 (mg/L) 0.20 (%) 16.87 (ppb) 68.73 (ppb) 0.35/2.2 (mUmL) (mV) 8.70 (%) 1.0 (%) 90.0 (%) I (bbl) 172.7 (bbl) (bbl) (bbl) ES: Solids: Oil: Water: OillWater: Daily Cuttings: Cum. Cuttings: Lost Downhole: Lost Surface: Operations. Summary Code NPT N N N N N N N N N N N N Code N N CEMT CEMT TOH CEMT CEMT CEMT CEMT CEMT CEMT CEMT Operation Finish displacing casing to 9.6 ppg mud. PJSM w/ SWLS and crews review perf gun handling procedures and plan forward. Install shooting nipple and p/u SWLS tools and 1st perf gun. 3 separate runs w/20' 41/2" guns w/4621 PowerFlo "Big Hole" charges @ 6spf. Tie-in to SWLS US IT log dated 7-16-02. Perf intervals: 8023' - 8043' 7785'-7805' 8023'-8043' all guns fired. Initially lined up to circulate across well from kill-line through choke-line during perforating operations. Was unable to pump through kill line. Later found kill line hose's inner rubber liner had at some time ruptured. Replaced hose with new one. M/U 5.95" gauge ring RIH to 8000'. POH PIU and RIH wI Howco EZSV stopped at 7700' (top perf zone). POH w/EZSV. P/U and run junk basket. Retrieved piece of rubber from kill line hose. (see above). Re-ran junk basket but nothing was retrieved. P/U EZSVand RIH. Stopped again at 7700' but was able to work through 1st and 2nd set of perf zones. Made tie-in. Set EZSV at 8008'. Confirm w/setdown. POH. RID SWLS and shooting nipple. CEMT RlU to run 3.5" 9.2# EUE tbg. CEMT CEMT P/U Howco Star Guide stinger and 29 jts (908.65') of tbg. Make-up tq 32000# Change out elevators and I/d tbg tongs. 06:00 Update NPT Operation CEMT CEMT RIH w/ BHA #6 to 7948'. CBU establish SPR. Est. rates/choke line pressures. Printed: 7/18/2002 5:46:13 AM ( Operator: BP EXPLORATION Well: L-105 Field: PRUDHOE BAY From-To Op. Depth 04:00-04:50 8,263 04:50-05:10 8,263 05:10- 8,263 Hrs Phase Task (hr) 0.83 COMP RUNCO Activity BP<EXPLORATION DailyOþerati()nsRE!Þørt , Rig: NABORS 9ES 9-ES Event: DRILL +COMPLETE Well Type: DEVELOPMENT 06:00 Update NPT Code Operation CIR CEMT P/U 15' pup jt. RIH stab into EZSV. Pressure up under packer to 1700 psi. Holding tight no bleed off to upper perf zones. PJSM with OS and crews. Review balanced plug procedures. N 0.00 COMP RUNCO 0.33 COMP RUNCO SAFETY N CEMT Close annular and establish injection rates in upper perf zones. 1 bpm @ 2030psi. Call town confirm go ahead with cement job. Line up to pump spot 10 bbls of water at EOP. Batch mixing cement @ 0535 hrs. M udLog .lnformatiOr1 ' I Form. Top MD. 4.0 (ft) I Bkgrnd Gas (ppm) ¡Trip Gas Conn. Gas (ppm) Pore. Press Materials I Consumption I Units I Usage I On Hand I Item GAL 0 7344 BARITE , Personnel Company NABORS ANADRILL SCHLUMBERGER N CEMT CIR Formation MILUVICH Lithology SHALE DIESEL Item Company BP BAROID PETROTECHNICAL RESOUR Phase 'SURF PRE PROD1 COMP 'TOTALS Prod % Total 47.00 98.9% 11.50 100.0% 124.00 100.0% 49.58 38.4% 232.08 74.4% I Units TON No. 2 2 0 No. Hours 2 0 Hours Company NABORS ANADRILL SCHLUMBERGER Cumulative' Phase Breakdown Planned Change of Scope NPT % Total WOW % Total Prod % Total NPT % Total WOW % Total 0.50 1.1% 79.42 61.6% 79.92 25.6% 0.00 0.0% 0.00 0.0% Remarks 0.00 0.0% 0.00 0.0% Report: Date: (ppm) (ppg) I Usage I On Hand 0 14.2 No. 24 0 Hours Total Hours 47.50 11.50 124.00 129.00 312.00 Total Cost USD 516,403.40 34,875.00 843,742.14 389,028.12 1,784,048.6 Printed: 7/18/2002 5:46:13 AM BPEXPLORATION Daily. Qpøratiol1s. RE!Pott Rig: NABORS 9ES 9-ES Event: DRILL +COMPLETE Well Type: DEVELOPMENT Current WeU StatO$ Depth MD: 8,360.0 (ft) Casing Size: 9.625 (in) Costs in: USD Est. TVD: 6,852.0 (ft) Casing (MD): 2,856.0 (ft) Daily Mud: 2,302 Progress: (ft) Next Casing Size: 7.000 (in) Cum. Mud: 125,220 Auth Depth: 8,756.0 (ft) Next Casing (MD): 8,350.0 (ft) Daily Well: 90,304 Hole Size: 8.750 (in) Next Casing {TVD):6,844.0 (ft) Cum. Well: 1,920,631 DOUDFSlTarget: 13.80113.50/15.10 Geologist: Engineer: Supervisor: Operator: BP EXPLORATION Well: L-105 Field: PRUDHOE BAY MAGEE ANGLENIFEKETI ( ( Page'1.()f3 Report: 14 Date: 7/18/2002 Rig Accept: 04:00 7/512002 Rig Release: Spud Date: 4/1/2002 WX Date: Elev Ref: SEA LEVEL Program: Weather: KB Elev: 75.50 (ft) Tot. Personnel: 30 Cost Ahead 50,000 USD, Days Ahead -1.00 Clear 42* Calm Current Status: TOH for US IT log. 24hr Summary: Cement squeeze perfs above EZSV. TOH. P/U bit. RIH drill cmt & EZSV. 24hr Forecast: Swap to 9.6 NaCI water. TOH. Log wI SWLS USIT. TIH LOOP Comments: No Accidents. No Spills. Days Since Last DAFWC: 1337 Last Csg Test Press.: 4,000 (psi) Last BOP Press. Test: 71712002 Next BOP Press. Test: 7114/2002 No. Stop Cards: FIRE: 7/18/2002 LOT TVD: 2,650.0 (ft) LOT EMW: 14.58 (ppg) MAASSP: 617 (psi) Test Pressure: 700 (psi) Kick Tolerance: (ppg) Kick Volume: (bbl) HSE & Well Control All Free Days: Last Envir. Incident: 3/16/2001 Last Abandonment Drill: 7/512002 Last Accum. Drill (D4): 6/23/2002 Last Spill Drill: 7/14/2002 Regulatory Agency Insp: N KICK WHILE DRILL (D2)7/9/2002 Pump Slow Pump Rates (Circ) Stroke Rate PressureO 13 Last Trip Drill (D1): Last Safety Meeting: 7/18/2002 7/16/2002 Non-compliance Issued: N Slow Pump Rates (Choke) Slow Pump Rates (Kill) Stroke Rate Pressure() Stroke Rate Pressure() ROP Daily: ROP Cum.: WOB (min): WOB (max): RPM Min.: RPM DH: Torq. on Bottom:9,OOO (ft-Ibf) Torq. off Bottom:8,OOO (ft-Ibf) Operational Parameters Rotating Weight: (Ibs) Daily Bit Hrs: (hr) Pick Up Wt.: (Ibs) Daily Sliding Hrs:O.OO (hr) Slack Off Wt.: (Ibs) Cum. Bit Hrs: Circ. Rate Riser: Circ. Rate Hole: 503 (gpm) Ann. Vel. Riser: (fUmin) Circ. Off Bottom:2,900 (psi) Ann. Vel. DC: 728.3 (fUmin) Circ. On Bottom:3,000 (psi) Ann. Vel. DP: (ftImin) Jar Hrs since Inspect: 68 (hr) Jts Length (ft) 0.60 4.02 Bits I Serial # W99ZX Cum Hrs / BHA Bha Weight: Wt Below Jars: Cum Length OD ID (ft) (in) (in) 4.17 5.500 5.12 4.750 913.77 3.500 915.11 4.750 917.29 5.130 8,008.79 4.000 Bha Weight: Wt Below Jars: Cum Length OD ID (ft) (in) (in) 0.60 6.125 4.62 4.688 1.500 Bit Run # IRe-Run I Size (in) I Manuf. I Type 6 6.125 HUGHS STX-1 Cum Prog(ft) I RPM ~in/MaxlwOB ~in/Maxl Daily Hrs I I Nozzles 111111 Cum ROPI 0 I 0 I Bha No: 6 Depth In: 8,360.0 Bha Type: Depth Out: 8,360.0 Component Component Detail Jts Length (ft) 4.17 0.95 29 908.65 1.34 2.18 93 7,091.50 8,360.0 Star Guide Stinger XO TUBING XO XO STDS. DRILLPIPE Bha No: 7 Depth In: Bha Type: DRILUDRESS CE~1h Out: Component Component Detail BIT SUB BIT JUNK BASKET Pump Status - Drilling and Riser Pump Type Eff. Strokes Liner Size Circ. Rate (%) (spm) (in) (gpm) D 96 93 5.000 228 D 96 93 5.500 275 1 2 I TFA (in2) /Depth In (ft) Depth Out (ft) 8,360.0 Condition I I Blade OD Bend Angle (in) n Blade OD Bend Angle (in) n 0 Connection Size (in) Type PIS Connection Size (in) Type I P/B Printed: 7/19/2002 5:30:56 AM ( ( 'Bha No: 7 Depth In: Bha Type: DRILUDRESS CEMBiij¡Ih Out: Component Component Detail 8,360.0 BPEXPLORATION Daily Operation$. Reþ()rt Rig: NABORS 9ES 9-ES Event: DRILL +COMPLETE Well Type: DEVELOPMENT BHA Bha Weight: Wt Below Jars: Cum Length 00 10 Blade 00 Bend Angle (ft) (in) (in) (in) (O) 9.13 4.750 1.500 12.11 4.750 16.80 6.125 1.500 291.74 4.750 2.375 293.92 5.250 2.250 323.87 5.125 2.250 968.45 4.000 2.563 Page 2of3 Report: 14 Date: 7/18/2002 Operator: BP EXPLORATION Well: L-105 Field: PRUDHOE BAY 0 SUB SUB JUNK BASKET FLOAT SUB CSG SCRAPPER DRILL COLLAR XO JAR HWDP Jts Length (ft) 4.51 2.98 4.69 9 274.94 1 2.18 1 29.95 21 644.58 Connection Size (in) Type P/B Type: LSNDIWBM 10 sec gels: 5 (lb/100ft2) (mg/L) ES: (mV) Time/Loc: 22:00/PIT 10 min gels: 12 (lb/10Oft2) K+: (mg/L) Solids: 8.70 (%) Depth: 8,360.0 (ft) Fluid Loss: 18.0 (cc/30min) CaCI2: (%) Oil: (%) Temp: eF) HTHP Temp: eF) NaCI: (%) Water: (%) Density: 9.60 (ppg) HTHP WL: (cc/30min) CI-: 25,000 (mg/L) Oil/Water: / Funnel Visc.: 45 (s/qt) Cake: 3 (/32") Sand: 0.10 (%) Daily Cuttings: (bbl) ECD: (ppg) MBT: 10.00 (ppb) HGS: (ppb) Cum. Cuttings: 172.7 (bbl) PV: 9 (cp) Lime: (ppb) LGS: 72.14 (ppb) Lost Downhole: (bbl) YP: 12 (lb/10Oft2) PM: 6.40 (mL) Pf/Mf: 0.35/2.0 (mUmL) Lost Surface: (bbl) pH: 11.6 Operations Summary From-To Hrs Phase Task Activity Code NPT Operation Op. Depth (hr) 00:00-03:00 3.00 COMP RUNCO RIH N CEMT RIH w/ BHA #6 to 7948'. 8,263 03:00-04:00 1.00 COMP RUNCO CIR N CEMT CBU establish SPR. Est. rates/choke line pressures. 8,263 04:00-04:50 0.83 COMP RUNCO CIR N CEMT P/U 15' pup jt. RIH stab into EZSV. Pressure up under packer to 1700 8,263 psi. Holding tight no bleed off to upper perf zones. 04:50-05:10 0.33 COMP RUNCO SAFETY N CEMT PJSM with OS and crews. Review balanced plug procedures. 8,263 05:10-06:00 0.83 COMP RUNCO CIR N CEMT Close annular and establish injection rates in upper perf zones. 1 bpm 8,263 @ 2030psi. Call town confirm go ahead with cement job. Line up to pump spot 10 bbls of water at EOP. Batch mixing cement @ 0535 hrs. Spot 10 bbls H2O on bottom. Close bag. Breakdown perfs. Est inj rate @3 bpm w/ 2040 psi. 06:00-09:00 3.00 COMP RUNCO CMT N CEMT Spot balanced 22.5 bbls 15.9 ppg squeeze slurry on bottom. Slowly 8,263 pull 13 stds. Close bag. Inject 6 bbls @ 1 bpm w/1520»2100psi. Hesitate 4 min. Pump 1 bbl @ 1/2 bpm w/ 1820»1950 psi. Hesitate 4 min pump 1 bbl @ 1/2 bpm w/1875»2070 psi. Hesitate 5 min. Pump 1/2 bbl @ 1/2 bpm w/1880»2050 psi. Hesitate 5 min. Pump 1/2 bbl @ 1/2 bpm w/1900»2065 psi. Hesitate 10 min. Pump 1 bbl @ 1/2 bpm w/1900»2125 psi. Hold pressure 5 min. 5 min shut-in 2020. Bleed off 09:00-10:00 1.00 COMP RUNCO CIR N CEMT CBU x2. No cement with returns. 8,263 10:00-12:30 2.50 COMP RUNCO POH N CEMT TOH to 31/2" tbg. 8,263 12:30-14:30 2.00 COMP RUNCO BHPULD N CEMT UD tbg and Howco stinger BHA 8,263 14:30-15:00 0.50 COMP RUNCO BHPULD N CEMT UD tbg tongs change out elevators. Clear rig floor. 8,263 15:00-16:00 1.00 COMP RUNCO BHPULD N CEMT P/U BHA#7. 8,263 16:00-19:15 3.25 COMP RUNCO RIH N CEMT TIH wash last 5 stds to bottom. Tagged cement at 7598'. 8,263 Printed: 7/19/2002 5:30:56 AM ( (' From-To Op. Depth 19:15-22:15 8,263 22:15-23:45 8,263 23:45-00:00 8,263 Hrs Phase Task (hr) 3.00 COMP RUNCO BPEXPLORATION DCiily. QperCltiQl1s. RepQrt Rig: NABORS 9ES 9-ES Event: DRILL +COMPLETE Well Type: DEVELOPMENT Operations Summary , Code NPT Pägë3óf3 Report: 14 Date: 7/18/2002 Operator: BP EXPLORATION Well: L-105 Field: PRUDHOE BAY Activity Operation 1.50 COMP RUNCO DRLCMT N CEMT Drill cement with 500 gpm 80 rpm's 8k wob 120-130'/hr DRL N CEMT Tagged EZSC at 8007'. Drill EZSV with 250 gpm 60 rpm 2-5k wob. RIH N CEMT TIH tagged PBTD at 8263'. 0.25 COMP RUNCO 06:00 Update NPT From-To Hrs Phase Task Activity Code Op. Depth (hr) 00:00-01: 15 1.25 COMP RUNCO RIH N 8,263 01:15-04:45 3.50 COMP RUNCO POH N 8,263 04:45- 0.00 COMP RUNCO LOG N 8,263 Operation CEMT CBU x2. Displace hole over to 9.6 ppg NaCI water. CEMT TOH CEMT RlU SWLS Item Mud Log Information I Form. Top MD. (ft) I Bkgrnd Gas Conn. Gas Materials I Consumption Usage On Hand Item (ppm) I Trip Gas (ppm) Pore. Press (ppm) (ppg) Formation MILUVICH Lithology SHALE Company No. Hours 2 2 0 Company NABORS ANADRILL SCHLUMBERGER No. Hours 2 0 Company NABORS ANADRILL SCHLUMBERGER No. Hours 24 0 BP BAROID PETROTECHNICAL RESOUR Cumulative Phase Breakdown Planned Change of Scope Total Total Cost Phase Prod % Total NPT % Total WOW % Total Prod % Total NPT % Total WOW % Total Hours USD SURF 47.00 98.9% 0.50 1.1% 47.50 516,403.40 PRE 11.50 100.0% 11.50 34,875.00 PROD1 124.00 100.0% 124.00 843,742.14 COMP 49.58 32.4% 103.42 67.6% 153.00 477,030.12 TOTALS 232.08 69.1% 103.92 30.9% 0.00 0.0% 0.00 0.0% 0.00 0.0% 0.00 0.0% 336.00 1,872,050.6 Printed: 7/1912002 5:30:56 AM BPEXPLORATION Dé1ilyQpøratipl1$RøPQrt " Rig: NABORS 9ES 9-ES Event: DRILL +COMPLETE Well Type: DEVELOPMENT CurrentWeUStatus ' Depth MD: 8,360.0 (ft) Casing Size: 9.625 (in) Costs in: USD Est. TVD: 6,852.0 (ft) Casing (MD): 2,856.0 (ft) Daily Mud: 13,555 Progress: (ft) Next Casing Size: 7.000 (in) Cum. Mud: 138,774 Auth Depth: 8,756.0 (ft) Next Casing (MD): 8,350.0 (ft) Daily Well: 104,561 Hole Size: 8.750 (in) Next Casing (TVD):6,844.0 (ft) Cum. Well: 2,025,191 DOUDFSrrarget: 14.80/14.50/15.10 Geologist: Engineer: Supervisor: Operator: BP EXPLORATION Well: L-105 Field: PRUDHOE BAY MAGEE ANGLEN/FEKETI Pagë1of3 Report: 15 Date: 7/19/2002 Rig Accept: 04:007/5/2002 Rig Release: Spud Date: 4/1/2002 WX Date: Elev Ref: SEA LEVEL Program: KB Elev: 75.50 (ft) Tot. Personnel: 30 Cost Ahead 100,000 USD, Days Ahead -0.25 Current Status: Prep to run 41/2" completion string. 24hr Summary: Displace csg to brine. TOH. Run USIT log. TIH. TOH UD DP&DC. Prep to tbg. 24hr Forecast: Run and set cmpl. string. N/D BOP's. N/U tree FP IA. Comments: No Accidents. No Spills. HSE & Well Control All Free Days: Last Envir. Incident: 3/16/2001 Last Abandonment Drill: 7/5/2002 Last Accum. Drill (04): 7/16/2002 Last Spill Drill: 7/18/2002 Regulatory Agency Insp: N KICK WHILE DRILL (02)7/9/2002 Pump Slow Pump Rates (Circ) Stroke Rate PressureO Days Since Last DAFWC: 1338 Last Csg Test Press.: 4,000 (psi) Last BOP Press. Test: 7/16/2002 Next BOP Press. Test: 7/23/2002 No. Stop Cards: FIRE: 7/19/2002 LOT TVD: 2,650.0 (ft) LOT EMW: 14.58 (ppg) MAASSP: 617 (psi) Test Pressure: 700 (psi) Kick Tolerance: (ppg) Kick Volume: (bbl) ROP Daily: ROP Cum.: WOB (min): WOB (max): RPM Min.: RPM DH: Torq. on Bottom: Torq. off Bottom: Rotating Weight: Pick Up Wt.: Slack Off Wt.: Circ. Rate Riser: Circ. Rate Hole: Circ. Off Bottom: Circ. On Bottom: Jar Hrs since Inspect: 68 (hr) Size (in) Manuf. 6.125 HUGHS Y 6.125 HUGHS RPM MiniMax WOB Min/Max / / / / Type STX-1 STX-1 Daily Hrs Bit Run # Re-Run 6 7 - Cum Prog(ft) Bha No: 7 Depth In: 8,360.0 Bha Type: DRILUDRESS CE~Th Out: 8,360.0 Component Component Detail Jts BIT SUB SUB SUB BIT JUNK BASKET JUNK BASKET FLOAT SUB CSG SCRAPPER DRILL COLLAR XO JAR HWDP 9 1 1 21 14 Last Trip Drill (01): Last Safety Meeting: 7/19/2002 7/16/2002 Non-compliance Issued: N Slow Pump Rates (Choke) Slow Pump Rates (Kill) Stroke Rate PressureO Stroke Rate PressureO Blade 00 Bend Angle (in) (°) Operational Parameters Daily Bit Hrs: (hr) Daily Sliding Hrs:O.OO (hr) Cum. Bit Hrs: Ann. Vet. Riser: (ftImin) Ann. Vel. DC: (ftImin) Ann. Vet. DP: (ftlmin) Bits I Serial # I W99ZX I W99ZX Cum Hrs Nozzles 111111 111111 Cum ROP Length (ft) 0.60 4.02 4.51 2.98 4.69 274.94 2.18 29.95 644.58 BHA Bha Weight: Wt Below Jars: Cum Length 00 ID (ft) (in) (in) 0.60 6.125 4.62 4.688 1.500 9.13 4.750 1.500 12.11 4.750 16.80 6.125 1.500 291.74 4.750 2.375 293.92 5.250 2.250 323.87 5.125 2.250 968.45 4.000 2.563 Pump Status - Drilling and Riser Pump Type Eff. Strokes Liner Size Circ. Rate 0 0 0 0 2 I 2 2 2 TFA (in2) Depth In (ft) Depth Out (ft) 8,360.0 8,360.0 8,360.0 8,360.0 Condition I CT I G I 2 I 'I NO I DP I CT G 2 I NO TO Connection Size (in) Type P/B Printed: 7120/2002 5:29:04 AM BPEXPLORATION ' Pélily Operations Report Rig: NABORS 9ES 9-ES Event: DRILL +COMPLETE Well Type: DEVELOPMENT BHA' Bha No: 8 Depth In: 8,360.0 Bha Weight: Bha Type: OTHER Depth Out: 8,360.0 Wt Below Jars: Component Component Detail Jts Length Cum Length 00 ID Blade OD Bend Angle (ft) (ft) (in) (in) (in) (°) 1 0.60 0.60 6.125 1 2.98 3.58 4.750 9 274.94 278.52 4.750 2.375 1 2.18 280.70 5.250 2.250 1 29.95 310.65 5.125 2.250 21 644.58 955.23 4.000 2.563 Drilling Fluid (lb/10OO2) Ca: (lb/100ft2) K +: (cc/30min) CaCI2: (OF) NaCI: (cc/30min) CI-: (/32") Sand: (ppb) HGS: (ppb) LGS: (mL) Pf/Mf: Operator. BP EXPLORATION Well: L-105 Field: PRUDHOE BAY BIT SUB ( ( Pagë2of3 Report: 15 Date: 7/19/2002 BIT FLOAT SUB DRILL COLLAR XO JAR HWDP Type: Time/Loc: Depth: Temp: Density: Funnel Visc.: ECD: PV: YP: pH: From-To Op. Depth 00:00-01: 15 8,263 01:15-05:00 8,263 05:00-05:30 8,263 05:30-06:30 8,263 06:30-10:30 8,263 10:30-11 :00 8,263 11:00-14:00 8,263 14:00-22:30 8,263 22:30-23:00 8,263 23:00-00:00 8,263 From-To Op. Depth 00:00-00:45 8,263 00:45-01 :00 8,263 01 :00-06:00 8,263 SEA WATER 22:00/PIT 8,360.0 (ft) (OF) 9.60 (ppg) 28 (s/qt) (ppg) (cp) (lb/10Oft2) Connection Size (in) Type P/B 10 sec gels: 10 min gels: Fluid Loss: HTHP Temp: HTHP WL: Cake: MBT: Lime: PM: (mg/L) (mg/L) (%) (%) 15,000 (mg/L) (%) (ppb) (ppb) I (mUmL) ES: Solids: Oil: Water: OillWater: Daily Cuttings: Cum. Cuttings: Lost Downhole: Lost Surface: (mV) (%) (%) 75.0 (%) I (bbl) 172.7 (bbl) (bbl) (bbl) Operations Summary Hrs Phase Task Activity Code NPT Operation (hr) 1.25 COMP RUNCO RIH N CEMT CBU x2. Displace hole over to 9.6 ppg NaCI water. 3.75 COMP RUNCO POH N CEMT TOH Standbackk HWDP & Dc's lId jars, junk baskets and csg scrapper. 0.50 COMP RUNCO RIH N CEMT Clean and clear floor. 1.00 COMP RUNCO LOG N CEMT PJSM wI SWLS and crews. RIU shooting nipple, sheaves and pack-off. P/U USIT log. 4.00 COMP RUNCO LOG N CEMT Log USIT f/6750' > 8250'. UD tools and rId shooting nipple. 0.50 COMP RUNCO BHPULD N CEMT P/U BHA #8. 3.00 COMP RUNCO RIH P RI H to 8262'. 8.50 COMP RUNCO LD P TOH laying down drillpipe, drill collars. Clear floor. 0.50 COMP RUNCO RU P Pull wear-bushing. Change out bales. 1.00 COMP RUNCO RU P RIU Torque-Turn, and tbg running equipment. Hrs Phase Task (hr) 0.75 COMP RUNCO Activity Code 06:00 Update NPT Operation RU Continue to RIU for running 41/2" completion string. P P PJSM with crews. Review tbg running procedure and running order. 5.00 COMP RUNCO 0.25 COMP RUNCO SAFETY RUN P Formation MILUVICH Lithology SHALE Run 41/2" 12.6# L-80 TCII completion string. Make-up tq using Best-O-Life 2000 PTC & Torque-Turn: TCII > 2700 ftJ#, NSCT > 4000 ftJ# (No fricton factor allowance used). Baker-Locked connections below Baker S-3 parker. Mud Log Information I Form. Top MD. 4.0 (ft) I Bkgrnd Gas Conn. Gas (ppm) I Trip Gas (ppm) I Pore. Press (ppm) (ppg) Printed: 7/20/2002 5:29:04 AM ( (' DIESEL I Units GAL , BPEXPLORATION Da.ily.Qpørati()ns.R~p()rt Rig: NABORS 9ES 9-ES Event: DRILL +COMPLETE Well Type: DEVELOPMENT Materials I Consumption I Usage I On Hand I Item 1296 4680 BARITE Personnel Company NABORS ANADRILL SCHLUMBERGER Page3öf3 Report: 15 Date: 7/19/2002 Operator. BP EXPLORATION Well: L-105 Field: PRUDHOE BAY Item Company No. Hours 2 2 0 No. Hours 2 0 Company NABORS ANADRILL SCHLUMBERGER No. Hours 24 0 BP BAROID PETROTECHNICAL RESOUR Cumulative Phase Breakdown Planned Change of Scope Total Total Cost Phase Prod % Total NPT % Total WOW % Total Prod % Total NPT % Total WOW % Total Hours USD SURF 47.00 98.9% 0.50 1.1% 47.50 516,403.40 PRE 11.50 100.0% 11.50 34,875.00 PROD1 124.00 100.0% 124.00 843,742.14 COMP 62.58 35.4% 114.42 64.6% 177.00 581,590.72 TOTALS 245.08 68.1% 114.92 31.9% 0.00 0.0% 0.00 0.0% 0.00 0.0% 0.00 0.0% 360.00 1,976,611.2 Printed: 712012002 5:29:04 AM (" ( '''-~... Of,b,P " TUBING SUMMARY RIG WEll # TUBING TaG WT. Nabors 9ES l-1051 41/2" 12.6# TC-II 205 JTS ON RACK 8102.13 FT ON RACK ITEM Description Includes: SIZE, TYPE, CONNECTION (JTS #-#) ITEM 4.5" WLEG 4.5" 12.6# l-80 NSCT Pup 4.5" HES 'XN' Nipple: 3.725" ID (w/RHC-M plug) 4.5" 12.6# l-80 NSCT Pup 4.5" 12.6# l-80 NSCT 4.5" 12.6# L-80 NSCT Pup 4.5" 12.6# L-80 NSCT 4.5" 12.6# L-80 NSCT Pup 4;5", HES'X',<Nipph~~ :3'~8t3" '10 4.5" 12.6# L-80 XO pup (TC-II Box x NSCT pin) 4.5" 12.6# L-80 TC-II Pup 3 Jts (#1-3) 4.5" 12.6# L-80 Te-II Tubing 4.5" 12.6# l-80 XO pup (NSCT Box x TC-II pin) 4.5" 12.6# L-80 NSCT Pup 7"x4:5't Baker ',Premier', Packer 4.5" 12.6# L-80 NSCT Pup 4.5": HE$'X'. Nipple: 3;813"10 4.5" 12.6# L-80 XO pup (TC-II Box x NSCT pin) 1 Jt (#4) 4.5" 12.6# l-80 TC-II Tubing 4.5" 12.6# L-80 XO Pup (L 80 NSCT box X TC-II pin) .,GlM~t,~,4~5,í1x1/'J~aß,~~ w/RP,$hear, &al<~5~ latch, 4.5" 12.6# L-80 XO Pup (L 80 TC-II box x NSCT pin) 57 Jts (#5-61) 4.5" 12.6# L-80 TC-II Tubing 4.5" 12.6# L-80 XO pup (NSCT box x TC-II pin) GlM #2'-4~5,"x1~' KBG-2,wlDúmmy &BK~5 latch 4.5" 12.6# l-80 XO Pup (TC-II box x NSCT pin) 33 Jts (#62-94) 4.5" 12.6# l-80, TC-II Tubing 4.5" 12.6# L-80 XO pup (NSCT box x TC-II pin) GLM#3 ~,4.5'~xt"KBG~2,'tN/ Dummy:BK:5:látch 4.5" 12.6# L-80 XO Pup (TC-II box x NSCT pin) 44 Jts (#95-138) 4.5" 12.6# l-80 Tubing 4.5~' 12.6# L-80 X? pup(N~CTbOX x TC-II pin) , 4.$:''LHES,'X:;Niþp,I~:!3.81:3'\ 10'; 4.5" 12.6# L-80 XO Pup (TC-II box x NSCT pin) 55 Jts (#139-193) 4.5" 12.6# l-80 TC-II 4.5" 12.6# L-80 TC-II Hanger Pup (NSCT x TC-II) FMC Tubing Hanger Body - 4.5" NSCT lift Thread Nabors 9ES RT to TS . ' Bakerlocked all connections below Baker "S-3' Packer PUW: 128K SOW: 93K Date 7/19/2002 l-80 193 JTS RAN 7621.76 FT RAN 22.75 OKB TO TS 10 00 lENGTH TOP BOTTOM 4.000 4.980 1.36 7883.88 7885.24 3.958 5.020 9.85 7874.03 7883.88 3.725 5.030 1.21 7872.82.. 7874.03' 3.958 5.020 9.87 7862.95 7872.82 3.958 5.020 9.90 7853.05 7862.95 3.958 5.020 9.90 7842.01 7851.91 3.958 4.940 9.87 7832.14 7842.01 3.958 4.940 9.85 7818.49 7828.34 3;813 5;000 ,1.14 ' 7817 ;35; '7818~49' 3.983 4.930 9.21 7808.14 7817.35 3.980 4.940 19.71 7788.43 7808.14 3.980 4.940 121.88 7666.55 7788.43 3.980 4.940 3.14 7663.41 7666.55 3.980 4.940 9.82 7653.59 7663.41 3:890' 5'.980 '7;55 ",7646.04, 7653.59 , 3.980 4.940 9.82 7636.22 7646.04 3;813 5.000 1.15 7635.01," ", :7636.22, 3.983 4.930 9.55 7625.52 7635.07 3.943 4.930 39.66 7585.86 7625.52 3.958 5.020 9.94 7575.92 7585.86 '3:g38 '5;9ð4 6.88 756S~0~ ", ' 75,75392 3.958 4.950 9.61 7559.43 7569.04 3.943 4.930 2257.79 5301.64 7559.43 3.958 5.020 9.89 5291.75 5301.64 3J}38 5~984 6.89 5284.86 :5291.75 3.958 4.950 9.60 5275.26 5284.86 3.943 4.930 1292.16 3983.10 5275.26 3.958 5.020 9.89 3973.21 3983.10 3;813' 5;030 6;89 3966:32 3973;2,1 3.958 4.950 9.60 3956.72 3966.32 3.943 4.930 1751.52 2205.20 3956.72 3.958 5.020 9.96 2195.24 2205.20 3;81.3 .::5.Ò30 " 1:13' '2194;11 "2195;24~, 3.958 4.950 9.40 2184.71 2194.11 3.943 4.930 2158.75 25.96 2184.71 3.943 4.930 2.38 23.58 25.96 12.5 .83 22.75 23.58 22.75 22.75 ( BPEXPLORATION Da.ily. Qpi!ratiøl1$. Report Rig: NABORS 9ES 9-ES Event: DRILL +COMPLETE Well Type: DEVELOPMENT Current WeU Status Depth MD: 8,360.0 (ft) Casing Size: 9.625 (in) Costs in: USD Est. TVD: 6,852.0 (ft) Casing (MD): 2,856.0 (ft) Daily Mud: 3,984 Progress: (ft) Next Casing Size: 7.000 (in) Cum. Mud: 142,758 Auth Depth: 8,756.0 (ft) Next Casing (MD): 8,350.0 (ft) Daily Well: 282,333 Hole Size: 8.750 (in) Next Casing (TVD):6,844.0 (ft) Cum. Well: 2,307,524 DOUDFSlTarget: 15.80/15.50/15.10 Geologist: Engineer: Supervisor: Operator: BP EXPLORATION Well: L-105 Field: PRUDHOE BAY MAGEE ANGLEN/FEKETI ( Page 1 of2 Report: 16 Date: 7/20/2002 Rig Accept: 04:007/5/2002 Rig Release: Spud Date: 4/1/2002 WX Date: Elev Ref: SEA LEVEL Program: Weather: KB Elev: 75.50 (ft) Tot. Personnel: 30 Cost Ahead -50,000 USD, Days Ahead -0.75 Clear 43* calm Current Status: N/D BOPE 24hr Summary: Finish running 41/2" tbg. Set packers. Test tbg & IA. NO BOPE 24hr Forecast: Finsih NO BOPE. N/U prod tree & test. FP IA & tbg. Rei rig Comments: No Accidents. No Spills. Days Since Last DAFWC: 1339 Last Csg Test Press.: 4,000 (psi) Last BOP Press. Test: 7/16/2002 Next BOP Press. Test: 7/23/2002 No. Stop Cards: FIRE: 7/19/2002 LOT TVD: 2,650.0 (ft) LOT EMW: 14.58 (ppg) MAASSP: 617 (psi) Test Pressure: 700 (psi) Kick Tolerance: (ppg) Kick Volume: (bbl) ROP Daily: ROP Cum.: WOB (min): WOB (max): RPM Min.: RPM DH: Torq. on Bottom: Torq. oft Bottom: Type: Time/Loc: Depth: Temp: Density: Funnel Vise.: ECD: PV: YP: pH: From-To Op. Depth 00:00-00:45 8,263 00:45-01 :00 8,263 01:00-16:00 8,263 SEA WATER 19:00/PIT 8,360.0 (ft) eF) 9.60 (ppg) 28 (s/qt) (ppg) (cp) (lb/10OO2) Hrs Phase Task (hr) 0.75 COMP RUNCO HSE & Well Control All Free Days: Last Envir. Incident: 3/16/2001 Last Abandonment Drill: 7/5/2002 Last Accum. Drill (04): 7/16/2002 Last Spill Drill: 7/20/2002 Regulatory Agency Insp: N KICK WHILE DRILL (02)7/9/2002 Pump Slow Pump Rates (Circ) Stroke Rate Pressure() 10 see gels: 10 min gels: Fluid Loss: HTHP Temp: HTHP WL: Cake: MBT: Lime: PM: Activity RU 15.00 COMP RUNCO 0.25 COMP RUNCO SAFETY RUN 15 Last Trip Drill (01): Last Safety Meeting: 7/19/2002 7/16/2002 Non-compliance Issued: N Slow Pump Rates (Choke) Slow Pump Rates (Kill) Stroke Rate Pressure() Stroke Rate Pressure() Operational Parameters Daily Bit Hrs: (hr) Daily Sliding Hrs:O.OO (hr) Cum. Bit Hrs: Ann. Vel. Riser: (ft/min) Ann. Vel. DC: (ftlmin) Ann. Vel. DP: (ft/min) Operations Summary Code NPT Pump Status - Drilling and Riser Pump Type Eft. Strokes Liner Size Circ. Rate () () () () (mg/L) (mg/L) (%) (%) 15,000 (mg/L) (%) (ppb) (ppb) / (mUmL) ES: Solids: Oil: Water: Oil/Water: Daily Cuttings: Cum. Cuttings: Lost Downhole: Lost Surface: (mV) (%) (%) 94.0 (%) / (bbl) 172.7 (bbl) (bbl) (bbl) Rotating Weight: Pick Up Wt.: Slack Oft Wt.: Circ. Rate Riser: Circ. Rate Hole: Circ. Off Bottom: Circ. On Bottom: Jar Hrs since Inspect: 68 (hr) Drilling Fluid (lb/10OO2) Ca: (lb/100ft2) K+: (cc/30min) CaCI2: (OF) NaCI: (cc/30min) CI-: (/32") Sand: (ppb) HGS: (ppb) LGS: (mL) Pf/Mf: P Continue to RIU for running 41/2" completion string. Operation P PJSM with crews. Review tbg running procedure and running order. P Run 41/2" 12.6# L-80 TCII completion string. Make-up tq using Best-O-Life 2000 PTC & Torque-Turn: TCII > 2700 ft/#, NSCT> 4000 ft/# (No fricton factor allowance used). Baker-Locked connections Printed: 7/21/2002 5:29:33 AM ( Operator. BP EXPLORATION Well: L-105 Field: PRUDHOE BAY From-To Op. Depth 01:00-16:00 8,263 16:00-18:00 8,263 18:00-18:30 8,263 18:30-19:00 8,263 19:00-19:45 8,263 19:45-20: 15 8,263 Hrs Phase Task (hr) 15.00 COMP RUNCO Activity RUN 2.00 COMP RUNCO CIRREV 0.50 COMP RUNCO 0.50 COMP RUNCO TSTPRS 0.75 COMPo RUNCO TSTPRS 0.50 COMP RUNCO TSTFN 20:15-21:00 0.75 COMP RUNCO SETOTR 8,263 21 :00-00:00 3.00 COMP RUNCO' NO 8,263 From-To Op. Depth 00:00-01 :30 8,263 01 :30-03:30 8,263 03:30-06:00 8,263 N/U ,11" x 4" 5M adapter fig and 4 1/8" 5M production tree. Test adaptor, tree and pack-off to 5000 psi. RIU and reverse in 140 bbls diesel @ 2.5bpm 1900 psi to 7" x 4 1/2" annulus to FP to 4100' in IA and tbg after U-tubing. Mud Log Information I Form. Top MD. 4.0 (ft) ¡ Bkgrnd Gas Conn. Gas Materials I Consumption I Units I Usage I On Hand I Item GAL 960 6120 BARITE Personnel Company NABORS ANADRILL SCHLUMBERGER Hrs Phase Task (hr) 1.50 COMP RUNCO Activity 2.00 COMP RUNCO 2.50 COMP RUNCO CIRREV Formation MILUVICH Lithology SHALE DIESEL Item Company BP BAROID PETROTECHNICAL RESOUR No. 2 2 0 Phase SURF PRE PROD1 COMP TOTALS Cumulative Phase Breakdown Planned Change of Scope NPT % Total WOW % Total Prod % Total NPT % Total WOW % Total 0.50 1.1% Hours Prod % Total 47.00 98.9% 11.50 100.0% 124.00 100.0% 86.33 43.0% 268.83 70.0% 114.67 57.0% 115.17 30.0% ( , BPEXPLORATION [)élily. QpèratiOr1$ . RèPOrt Rig: NABORS 9ES 9-ES Event: DRILL +COMPLETE Well Type: DEVELOPMENT Operations Summary Code NPT Page2óf 2 Report: 16 Date: 7/20(2002 Operation P below Baker S-3 parker. P/U landing jt and landout in wellhead. P Reverse in 275 bbls clean 9.6ppg NaCI brine followed by 40 bbl corrision inhibited brine. Drop ball/rod assembly. P P Pressure test tbg to 4200 psi for 30 min. Held ok. Bleed off to 2500 psi. Pressure test IA to 4000 psi for 30 min. Held ok. Bleed off IA then bleed off tbg. With tbg at 0 psi, pressure up IA to 2250 psi and shear RP valve. Reverse circ 2 bpm @ 1500 psi. Line up on tbg and try to circ. Tbg pressured up to 2200 after pumping 2 bbls. Stopped pumping and pressure bleed off to 500 psi after 3 min. Appears RP is partially shutting or restricted in some way. Check ability to reverse again @ 2 bpm..ok. Drain BOP stack. Set TWC and PT with 2800 psi from below. P P P P Nipple down BOP stack. Code 06:00 Update NPT Operation ND P Finish nipple down BOP stack. NU P P (ppm) I Trip Gas (ppm) Pore. Press (ppm) (ppg) I Units TON I Usage I On Hand 0 14.2 No. Hours 2 0 Company NABORS ANADRILL SCHLUMBERGER No. Hours 24 0 0.00 0.0% 0.00 0.0% Remarks Total Hours 47.50 11.50 124.00 201.00 384.00 Total Cost USD 516,403.40 34,875.00 843,742.14 863,923.72 2,258,944.2 0.00 0.0% 0.00 0.0% Printed: 7/21/2002 5:29:33 AM BPEXPLORATION Daily' OperafionsRE!Þøt1 Rig: NABORS 9ES 9-ES Event: DRILL +COMPLETE Well Type: DEVELOPMENT CurrentWeUStatus Depth MD: 8,360.0 (ft) Casing Size: 9.625 (in) Costs in: USD Est. TVD: 6,852.0 (ft) Casing (MD): 2,856.0 (ft) Daily Mud: 1,115 Progress: (ft) Next Casing Size: 7.000 (in) Cum. Mud: 143,873 Auth Depth: 8,756.0 (ft) Next Casing (MD): 8,350.0 (ft) Daily Well: 181,476 Hole Size: 8.750 (in) Next Casing (TVD):6,844.0 (ft) Cum. Well: 2,489,000 DOUDFSlTarget: 16.80/16.50/15.10 Geologist: Engineer: Supervisor: Operator. BP EXPLORA TJON Well: L-105 Field: PRUDHOE BAY MAGEE ANGLEN/FEKETJ (' Page 1of2 Report: 17 Date: 7/21/2002 Rig Accept: 04:007/5/2002 Rig Release: 7/21/2002 Spud Date: 4/1/2002 WX Date: Elev Ref: SEA LEVEL Program: KB Elev: 75.50 (ft) Tot. Personnel: 30 Cost Ahead -82,000 USD, Days Ahead -0.75 Current Status: Rig Released 24hr Summary: Finish ND BOPE. Install prod tree and test. FP IA and tbg. Release rig. 24hr Forecast: Move to L 1 03i for rig's summer maintenance. Comments: No Accidents. No Spills. Rotating Weight: Pick Up Wt.: Slack Off Wt.: Circ. Rate Riser: Circ. Rate Hole: Circ. Off Bottom: Circ. On Bottom: Jar Hrs since Inspect: 68 (hr) Drilling Fluid (lb/100ft2) Ca: (lb/100fe) K +: (cc/30min) CaCI2: (OF) NaCI: (cc/30min) CI-: (/32") Sand: (ppb) HGS: (ppb) LGS: (mL) Pf/Mf: Days Since Last DAFWC: 1340 Last Csg Test Press.: 4,000 (psi) Last BOP Press. Test: 7/16/2002 Next BOP Press. Test: 7/23/2002 No. Stop Cards: FIRE: 7/19/2002 LOT TVD: 2,650.0 (ft) LOT EMW: 14.58 (ppg) MAASSP: 617 (psi) Test Pressure: 700 (psi) Kick Tolerance: (ppg) Kick Volume: (bbl) ROP Daily: ROP Cum.: WOB (min): WOB (max): RPM Min.: RPM DH: Torq. on Bottom: Torq. off Bottom: Type: Time/Lac: Depth: Temp: Density: Funnel Vise.: ECD: PV: YP: pH: SEA WATER OO:OO/PIT 8,360.0 (ft) (OF) 9.60 (ppg) 28 (s/qt) (ppg ) (cp) (lb/100ft2) HSE & Well Control All Free Days: Last Envir. Incident: 3/16/2001 Last Abandonment Drill: 7/5/2002 Last Accum. Drill (D4): 7/16/2002 Last Spill Drill: 7/18/2002 Regulatory Agency Insp: N KICK WHILE DRILL (D2)7/9/2002 Pump Slow Pump Rates (Circ) Stroke Rate Pressure() 10 see gels: 10 min gels: Fluid Loss: HTHP Temp: HTHP WL: Cake: MBT: Lime: PM: From-To Hrs Phase Task Activity Op. Depth (hr) 00:00-01 :30 1.50 COMP RUNCO ND 8,263 01 :30-03:30 2.00 COMP RUNCO NU 8,263 03:30-04:00 0.50 COMP RUNCO PUL 8,263 16 Last Trip Drill (D1): Last Safety Meeting: 7/19/2002 7/16/2002 Non-compliance Issued: N Slow Pump Rates (Choke) Slow Pump Rates (Kill) Stroke Rate Pressure() Stroke Rate pressure() Operational Parameters Daily Bit Hrs: (hr) Daily Sliding Hrs:O.OO (hr) Cum. Bit Hrs: Pump Status - Drilling and Riser Pump Type Eff. Strokes Liner Size Circ. Rate () () () () Ann. Vel. Riser: (ftImin) Ann. Vel. DC: (ftImin) Ann. Vel. DP: (ftImin) (mg/L) ( mg/L) (%) (%) (mg/L) (%) (ppb) (ppb) / (mUmL) (mV) (%) (%) 94.0 (%) / (bbl) 172.7 (bbl) (bbl) (bbl) ES: Solids: Oil: Water: Oil/Water: Daily Cuttings: Cum. Cuttings: Lost Downhole: Lost Surface: Operations Summary Code NPT Operation P Finish nipple down BOP stack. P N/U 11" x 4" 5M adapter fig and 4 1/8" 5M production tree. Test adaptor, tree and pack-off to 5000 psi. RIU lubricator and pull TWC. P Printed: 7/22/2002 5:31:11 AM Operator: BP EXPLORATION Well: L-105 Field: PRUDHOE BAY Activity From-To Hrs Phase Task Op. Depth (hr) 04:00-07:00 3.00 COMP RUNCO CIRREV 8,263 07:00-09:00 2.00 COMP RUNCO INSTAL 8,263 Formation MILUVICH Lithology SHALE Item DIESEL Company BP BAROID PETROTECHNICAL RESOUR Phase SURF PRE PROD1 COMP TOTALS Prod % Total 47.00 98.9% 11.50 100.0% 124.00 100.0% 95.33 45.4% 277.83 70.7% No. 2 2 0 Hours ( BPEXPLORATION Daily Operations Røpørt Rig: NABORS 9ES 9-ES Event: DRILL +COMPLETE Well Type: DEVELOPMENT Operåtions. Summary Code NPT Operation Page2óf 2 Report: 17 Date: 7/21/2002 RlU and reverse in 140 bbls diesel to 7" x 41/2" annulus to FP to 4100' in IA and tbg after U-tubing. Initial rate: 2 bpm @ 1900psi Final: 1.7 bpm @ 2000 psi. Install BPV and test to 1000 psi. RID lubricator. RID Little Red. Secure tree and cellar area for move. P P (ppm) ¡Trip Gas (ppm) Pore. Press I Units TON No. Hours 2 0 Company NABORS ANADRILL SCHLUMBERGER Nabors 9ES released at 0900 hrs. 7-21-2002 Move to L-103i for summer maintenance Mud Log Information I Form. Top MD. 4.0 (ft) I Bkgmd Gas Conn. Gas Materials I Consumption I Units I Usage I On Hand I Item GAL 0 6120 BARITE Personnel Company NABORS ANADRILL SCHLUMBERGER Cumulative Phase Breakdown Planned Change of Scope NPT % Total WOW % Total Prod % Total NPT % Total WOW % Total 0.50 1.1% 114.67 54.6% 115.17 29.3% 0.00 0.0% 0.00 0.0% Remarks 0.00 0.0% 0.00 0.0% (ppm) (ppg) I Usage I On Hand 0 14.2 No. Hours 24 0 Total Hours 47.50 11.50 124.00 210.00 393.00 Total Cost USD 516,403.40 34,875.00 843,742.14 1,045,399.7 2,440,420.2 Printed: 7/2212002 5:31:11 AM ANADRILL SCHLUMBERGER Survey report Client......... .... ......: BP Exploration (Alaska) Inc. Field... ...... ..... ......: Prudhoe Bay 1 Borealis Well. . . . . . . . . . . . . . . . . . . . .: L-105i API number.. ...... .......: 50-029-23075-00 Engineer.... ......... ....: Franco COUNTY: ..... ...... .... ...: Nabors 9ES STATE: . . . . . . . . . . . . . . . . . . .: Alaska ---~- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS... ."'" ..: Mason & Taylor ----- Depth reference ----------------------- Permanent datum.... ......: Mean Sea Level Depth reference.... ......: Drill Floor GL above permanent.......: 50.30 ft KB above permanent.... ...: N/A DF above permanent. . . . . . . : 78.80 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 rotary table to target: 98.07 degrees [(c)2002 Anadrill IDEAL ID6_1C_10] 11-Jul-2002 17:21:24 Spud date. . . . . . . . . . . . . . . . : Last survey date.. .......: Total accepted surveys...: MD of first survey. ......: MD of last survey... .....: Page 1 of 5 05-July-02 11-July-02 94 0.00 ft 8360.00 ft ----- Geomagnetic data ---------------------- Magnetic model.... .......: BGGM version 2001 Magnetic date..... ... ....: 05-Jul-2002 Magnetic field strength..: 1149.54 HCNT Magnetic dec (+E/W-) .....: 25.98 degrees Magnetic dip... ..........: 80.77 degrees ----- MWD Reference Reference Reference Tolerance Tolerance Tolerance survey Reference G..............: H..............: Dip. . . . . . . . . . . . : of G...........: of H...........: of Dip.........: Criteria --------- 1002.68 mGal 1149.54 HCNT 80.77 degrees (+1-) 2.50 mGal (+1-) 6.00 HCNT (+1-) 0.45 degrees ~ ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 25.87 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 25.87 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N) ...,.. ..: No degree: 0.00 APADRILL SCHLUMBERGER Survey Report 11-Jul-2002 17:21:24 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 qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 1 0.00 0.00 98.07 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP - 2 50.00 0.37 132.80 50.00 50.00 0.13 -0.11 0.12 0.16 132.80 0.74 GYRO 3 100.00 0.38 146.44 50.00 100.00 0.38 -0.36 0.33 0.49 137.42 0.18 GYRO 4 150.00 0.35 130.81 50.00 150.00 0.61 -0.60 0.54 0.80 138.02 0.21 GYRO 5 200.00 0.49 130.46 50.00 200.00 0.92 -0.83 0.81 1.17 135.70 0.28 GYRO ,~, 6 250.00 0.43 119.62 50.00 249.99 1.28 -1.07 1.14 1.56 133.07 0.21 GYRO 7 358.00 0.70 104.48 108.00 357.99 2.31 -1.43 2.13 2.57 123.88 0.28 GYRO 8 451.00 0.99 98.03 93.00 450.98 3.68 -1.69 3.48 3.86 115.86 0.33 GYRO 9 542.00 1.57 95.53 91.00 541.96 5.71 -1.92 5.50 5.82 109.21 0.64 GYRO 10 633.00 2.37 94.98 91.00 632.90 8.83 -2.20 8.61 8.89 104.32 0.88 GYRO 11 725.00 3.62 96.88 92.00 724.77 13.64 -2.71 13.39 13.66 101.45 1.36 GYRO 12 817.00 4.74 105.12 92.00 816.53 20.31 -4.05 19.94 20.35 101.48 1.38 GYRO 13 851.25 5.39 103.10 34.25 850.64 23.32 -4.78 22.88 23.37 101.81 1.97 MWD_IFR_MSA 14 945.27 5.69 103.66 94.02 944.23 32.36 -6.89 31.71 32.45 102.25 0.32 MWD_IFR_MSA 15 1038.52 7.46 92.33 93.25 1036.86 42.98 -8.22 42.25 43.04 101.02 2.34 MWD_IFR_MSA 16 1132.44 9.29 94.68 93.92 1129.78 56.62 -9.09 55.90 56.63 99.24 1.98 MWD_IFR_MSA 17 1224.95 10.29 92.36 92.51 1220.94 72.30 -10.04 71.59 72.30 97.98 1.16 MWD_IFR_MSA 18 1318.72 11.92 94.87 93.77 1312.95 90.30 -11.21 89.61 90.31 97.13 1.81 MWD_IFR_MSA 19 1413.52 14.30 97.36 94.80 1405.27 111.78 -13.54 110.98 111.81 96.96 2.58 MWD_IFR_MSA 20 1506.90 17.03 96.98 93.38 1495.18 136.99 -16.68 136.00 137.02 96.99 2.93 MWD_IFR_MSA ~ 21 1599.64 17.13 95.04 92.74 1583.83 164.21 -19.53 163.08 164.25 96.83 0.62 MWD_IFR_MSA 22 1693.23 19.06 95.05 93.59 1672.78 193.24 -22.08 192.04 193.30 96.56 2.06 MWD_IFR_MSA 23 1780.75 20.16 96.82 87.52 1755.23 222.58 -25.13 221.25 222.67 96.48 1.43 MWD_IFR_MSA 24 1874.69 22.11 100.29 93.94 1842.85 256.44 -30.21 254.72 256.51 96.76 2.47 MWD_IFR_MSA 25 1968.04 24.33 99.51 93.35 1928.63 293.22 -36.53 290.98 293.26 97.16 2.40 MWD_IFR_MSA 26 2061.28 28.84 99.26 93.24 2011.99 334.93 -43.33 332.13 334.95 97.43 4.84 MWD_IFR_MSA 27 2152.90 32.67 96.89 91.62 2090.71 381.76 -49.85 378.51 381.78 97.50 4.38 MWD_IFR_MSA 28 2246.60 35.82 97.44 93.70 2168.16 434.48 -56.44 430.82 434.50 97.46 3.38 MWD_IFR_MSA 29 2341.64 38.43 101.86 95.04 2243.95 491.78 -66.11 487.32 491.79 97.73 3.93 MWD_IFR_MSA 30 2435.13 40.76 101.67 93.49 2315.98 551.24 -78.26 545.65 551.24 98.16 2.50 MWD_IFR_MSA . > ~ADRILL SCHLUMBERGER Survey Report 11-Jul-2002 17:21:24 Page 3 of 5 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Inc1 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 qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 31 2529.34 40.36 102.88 94.21 2387.56 612.33 -91.28 605.51 612.35 98.57 0.94 MWD_IFR_MSA 32 2623.44 41.17 100.19 94.10 2458.83 673.65 -103.55 665.70 673.71 98.84 2.06 MWD_IFR_MSA 33 2716.46 40.40 99.93 93.02 2529.26 734.37 -114.17 725.53 734.46 98.94 0.85 MWD_IFR_MSA 34 2806.50 40.23 97.81 90.04 2597.92 792.62 -123.15 783.08 792.71 98.94 1.53 MWD_IFR_MSA 35 2899.43 38.85 98.59 92.93 2669.59 851.77 -131.58 841.64 851.86 98.89 1.58 MWD_IFR_MSA 36 2993.34 38.85 98.72 93.91 2742.72 910.68 -140.45 899.87 910.77 98.87 0.09 MWD_IFR_MSA 37 3085.86 38.58 98.35 92.52 2814.91 968.54 -149.04 957.10 968.63 98.85 0.38 MWD_IFR_MSA 38 3180.01 38.66 97.51 94.15 2888.47 1027.31 -157.14 1015.30 1027.39 98.80 0.56 MWD_IFR_MSA 39 3273.13 39.31 96.61 93.12 2960.86 1085.88 -164.34 1073.44 1085.94 98.70 0.93 MWD_IFR_MSA 40 3364.88 39.94 94.89 91.75 3031.53 1144.34 -170.20 1131.65 1144.38 98.55 1.38 MWD_IFR_MSA 41 3458.18 40.06 94.52 93.30 3103.00 1204.21 -175.11 1191.42 1204.22 98.36 0.29 MWD_IFR_MSA 42 3550.85 40.27 93.76 92.67 3173.82 1263.84 -179.43 1251.04 1263.84 98.16 0.58 MWD_IFR_MSA 43 3643.71 40.42 93.30 92.86 3244.59 1323.76 -183.13 1311.04 1323.77 97.95 0.36 MWD_IFR_MSA 44 3737.53 40.42 93.29 93.82 3316.02 1384.39 -186.63 1371.77 1384.41 97.75 0.01 MWD_IFR_MSA 45 3830.20 40.59 92.81 92.67 3386.48 1444.34 -189.83 1431.88 1444.40 97.55 0.38 MWD_IFR_MSA 46 3923.50 41.00 92.70 93.30 3457.11 1505.04 -192.76 1492.76 1505.16 97.36 0.45 MWD_IFR_MSA 47 4017.91 40.62 92.42 94.41 3528.57 1566.46 -195.51 1554.40 1566.65 97.17 0.45 MWD_IFR_MSA 48 4108.72 40.02 93.40 90.81 3597.81 1624.98 -198.49 1613.08 1625.25 97.02 0.96 MWD_IFR_MSA 49 4202.08 39.57 93.82 93.36 3669.54 1684.55 -202.26 1672.72 1684.90 96.89 0.56 MWD_IFR_MSA 50 '4295.95 39.24 95.29 93.87 3742.07 1744.02 -206.98 1732.12 1744.44 96.81 1.05 MWD_IFR_MSA 51 4389.20 38.98 95.64 93.25 3814.43 1802.78 -212.59 1790.67 1803.25 96.77 0.37 MWD_IFR_MSA 52 4482.23 38.62 96.10 93.03 3886.93 1861.03 -218.55 1848.66 1861.53 96.74 0.50 MWD_IFR_MSA 53 4577.76 38.72 97.16 95.53 3961.52 1920.70 -225.44 1907.95 1921.22 96.74 0.70 MWD_IFR_MSA 54 4671.37 38.87 97.86 93.61 4034.48 1979.35 -233.11 1966.09 1979.86 96.76 0.50 MWD_IFR_MSA 55 4763.92 39.08 98.00 92.55 4106.43 2037.56 -241.14 2023.75 2038.07 96.79 0.25 MWD_IFR_MSA 56 4857.29 40.02 99.21 93.37 4178.42 2097.01 -250.04 2082.53 2097.49 96.85 1.30 MWD_IFR_MSA 57 4953.63 40.78 100.95 96.34 4251.79 2159.40 -260.97 2144.00 2159.82 96.94 1.41 MWD_IFR_MSA 58 5045.12 41.93 101.87 91.49 4320.46 2219.75 -272.94 2203.25 2220.09 97.06 1.42 MWD_IFR_MSA 59 5137.43 42.72 101.65 92.31 4388.71 2281.77 -285.60 2264.10 2282.04 97.19 0.87 MWD_IFR_MSA 60 5231.38 42.11 101.35 93.95 4458.07 2345.03 -298.24 2326.20 2345.24 97.31 0.68 MWD_IFR_MSA .. } ~ADRILL SCHLUMBERGER Survey Report 11-Jul-2002 17:21:24 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 qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type = -------- ------ ------- ------ -------- -------- ---------------- =====:::r========= ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- ------ 61 5324.07 42.30 100.86 92.69 4526.73 2407.21 -310.23 2387.30 2407.37 97.40 0.41 MWD_IFR_MSA 62 5418.21 42.21 99.84 94.14 4596.41 2470.46 -321.60 2449.57 2470.59 97.48 0.73 MWD_IFR_MSA 63 5511.36 42.09 99.98 93.15 4665.47 2532.94 -332.36 2511.15 2533.05 97.54 0.16 MWD_IFR_MSA 64 5605.70 42.30 99.87 94.34 4735.37 2596.27 -343.28 2573.56 2596.36 97.60 0.24 MWD_IFR_MSA 65 5702.15 41.82 99.60 96.45 4806.97 2660.85 -354.21 2637.24 2660.93 97.65 0.53 MWD_IFR_MSA 66 5794.47 42.13 100.42 92.32 4875.61 2722.56 -364.94 2698.05 2722.62 97.70 0.68 MWD_IFR_MSA ~, 67 5887.49 42.19 100.27 93.02 4944.56 2784.95 -376.15 2759.47 2784.99 97.76 0.13 MWD_IFR_MSA 68 5980.04 42.02 100.39 92.55 5013.23 2846.95 -387.28 2820.52 2846.98 97.82 0.20 MWD_IFR_MSA 69 6072.44 42.40 100.68 92.40 5081.67 2908.97 -398.63 2881.55 2908.99 97.88 0.46 MWD_IFR_MSA 70 6166.14 43.36 100.81 93.70 5150.33 2972.66 -410.52 2944.19 2972.67 97.94 1.03 MWD_IFR_MSA 71 6258.29 43.89 100.81 92.15 5217.03 3036.17 -422.44 3006.64 3036.17 98.00 0.58 MWD_IFR_MSA 72 6351.72 45.15 100.70 93.43 5283.65 3101.60 -434.67 3071.00 3101.60 98.06 1.35 MWD_IFR_MSA 73 6446.08 45.63 99.43 94.36 5349.91 3168.74 -446.40 3137.13 3168.74 98.10 1.08 MWD_IFR_MSA 74 6540.11 45.45 99.59 94.03 5415.77 3235.83 -457.49 3203.32 3235.83 98.13 0.23 MWD_IFR_MSA 75 6633.57 45.12 99.37 93.46 5481.53 3302.22 -468.43 3268.83 3302.22 98.16 0.39 MWD_IFR_MSA 76 6727.89 44.74 100.00 94.32 5548.31 3368.81 -479.64 3334.49 3368.81 98.19 0.62 MWD_IFR_MSA 77 6821.53 44.17 100.52 93.64 5615.15 3434.34 -491.32 3399.03 3434.35 98.22 0.72 MWD_IFR_MSA 78 6914.49 43.21 99.33 92.96 5682.36 3498.51 -502.39 3462.27 3498.53 98.26 1.36 MWD_IFR_MSA 79 7009.06 41.68 98.98 94.57 5752.15 3562.32 --512.55 3525.28 3562.35 98.27 1.64 MWD_IFR_MSA 80 7101.94 40.31 99.14 92.88 5822.25 3623.24 -522.14 3585.45 3623.27 98.29 1.48 MWD_IFR_MSA ~ 81 7194.12 39.62 99.71 92.18 5892.90 3682.43 -531.83 3643.86 3682.47 98.30 0.85 MWD_IFR_MSA 82 7287.33 39.21 99.53 93.21 5964.91 3741.59 -541.72 3702.21 3741.63 98.32 0.46 MWD_IFR_MSA 83 7381.00 38.61 98.92 93.67 6037.80 3800.42 -551.16 3760.28 3800.46 98.34 0.76 MWD_IFR_MSA 84 7472.77 38.03 98.88 91.77 6109.80 3857.31 -559.96 3816.50 3857.36 98.35 0.63 MWD_IFR_MSA 85 7566.80 36.72 99.47 94.03 6184.52 3914.38 -569.06 3872.84 3914.43 98.36 1.44 MWD_IFR_MSA 86 7659.81 35.64 99.00 93.01 6259.59 3969.27 -577.87 3927.04 3969.33 98.37 1.20 MWD_IFR_MSA 87 7753.68 34.25 99.39 93.87 6336.54 4023.03 -586.46 3980.11 4023.09 98.38 1.50 MWD_IFR_MSA 88 7848.37 33.07 99.90 94.69 6415.35 4075.49 -595.25 4031.85 4075.56 98.40 1.28 MWD_IFR_MSA 89 7942.30 31.47 101.05 93.93 6494.77 4125.59 -604.35 4081.17 4125.67 98.42 1.82 MWD_IFR_MSA 90 8035.64 31.26 102.28 93.34 6574.47 4174.08 -614.18 4128.74 4174.17 98.46 0.72 MWD_IFR_MSA , .. ~ADRILL SCHLUMBERGER Survey Report > --- -------- -------- Seq Measured # depth (ft) --- -------- -------- 91 92 93 8129.88 8223.26 8276.11 Projected to TD 94 8360.00 ------ ------ Incl angle (deg) ------ ------ ------- ------- ------ ------ Azimuth Course angle length (deg) ( f t) ------- ------- 31.15 102.05 31.22 101.25 31.13 101.04 31.13 101.04 ------ ------ 94.24 93.38 52.85 83. 89 [(c)2002 Anadrill IDEAL ID6_1C_10J -------- -------- TVD depth (ft) -------- -------- 6655.07 6734.96 6780.18 6851.99 11-Jul-2002 17:21:24 -------- -------- Vertical section (ft) -------- -------- ---------------- ---------------- Displ +N/S- (ft) Displ +E/W- (ft) Page --------------- --------------- Total displ (ft) At Azim (deg) --------------- --------------- 4222.78 -624.46 4176.47 4222.90 4271.03 -634.23 4223.83 4271.18 4298.35 -639.52 4250i67 4298.51 ---------------- ---------------- 4341.67 -647.82 4293.24 4341.84 98.50 98.54 98.56 98.58 5 of 5 ----- DLS (deg/ 100f) ----- Srvy tool type ----- ------ ------ Tool qual type ------ ------ 0.17 MWD_IFR_MSA 0 . 45 MWD_IFR_MSA 0.27 MWD_IFR_MSA 0.00 Projected .~ L-105 Survey Report - Geodetic Survey 1 DLS Computation Method: Vertical Section Azimuth: Vertical Section Origin: TVD Reference Datum: TVD Reference Elevation: Sea Bed 1 Ground Level Elevation: Magnetic Declination: Total Field Strength: Magnetic Dip: Declination Date: Magnetic Declination Model: North Reference: Total Corr Mag North -> True North: Local Coordinates Referenced To: bp Report Date: 16-Jul-2002 Client: BP Exploration Alaska Field: Prudhoe Bay Unit - WOA (Drill Pads) Structure 1 Slot: L-Pad /L-105 Well: L-105 Borehole: L -1 05 UWI/API#: 500292307500 Survey Name 1 Date: L -105 / July 16, 2002 Tort 1 AHD 1 DDII ERD ratio: 89.962° 14346.83 ft / 5.679 I 0.634 Grid Coordinate System: NAD27 Alaska State Planes, Zone 4, US Feet Location LatlLong: N 70 21 0.864, W 1491924.055 Location Grid NlE Y/X: N 5978139.020 ftUS, E 583342.980 ftUS Grid Convergence Angle: +0.63725055° Grid Scale Factor: 0.99990789 Station ID I MD Incl I Azim I TVD VSec NI-S (ft) r) (°) (ft) (ft) (ft) 0.00 0.00 0.00 0.00 0.00 0.00 50.00 0.37 132.80 50.00 0.13 -0.11 100.00 0.38 146.44 100.00 0.38 -0.36 150.00 0.35 130.81 150.00 0.62 -0.60 200.00 0.49 130.46 200.00 0.93 -0.83 250.00 0.43 119.62 249.99 1.29 -1.07 358.00 0.70 104.48 357.99 2.32 -1 .43 451.00 0.99 98.03 450.98 3.69 -1.69 542.00 1.57 95.53 541.96 5.72 -1.92 633.00 2.37 94.98 632.90 8.84 -2.20 725.00 3.62 96.88 724.77 13.64 -2.71 817.00 4.74 105.12 816.53 20.32 -4.05 851 .25 5.39 103.10 850.64 23.33 -4.78 945.27 5.69 103.66 944.23 32.38 -6.89 1038.52 7.46 92.33 1036.86 43.00 -8.22 1132.44 9.29 94.68 1129.78 56.63 -9.09 1224.95 10.29 92.36 1220.94 72.29 -10.04 1318.72 11.92 94.87 1312.95 90.28 -11.21 L-105 ASP Final Survey.xls Page 1 of 4 Schlumbergell Minimum Curvature I Lubinski 98.580° N 0.000 ft, E 0.000 ft KB 78.800 ft relative to MSL 44.100 ft relative to MSL +25.855° 57500.539 nT 80.775° July 16, 2002 BGGM 2002 True North +25.855° Well Head ~. Grid Coordinates Geographic Coordinates EI-W DLS Northing I Easting Latitude I Longitude (ft) (°/1 OOft) (ftUS) (ftUS) 0.00 5978139.02 583342.98 N 70 21 0.864 W 149 19 24.055 0.12 0.74 5978138.91 583343.10 N 7021 0.863 W 149 1924.051 0.33 0.18 5978138.67 583343.31 N 70 21 0.860 W 149 19 24.045 0.54 0.21 5978138.43 583343.52 N 70 21 0.858 W 149 19 24.039 0.81 0.28 5978138.20 583343.80 N 7021 0.855 W 149 1924.031 1.14 0.21 5978137.97 583344.13 N 70 21 0.853 W 149 19 24.021 2.13 0.28 5978137.61 583345.13 N 70 21 0.850 W 149 1923.992 3.48 0.33 5978137.37 583346.4 7 N 70 21 0.847 W 149 19 23.95~ 5.50 0.64 5978137.17 583348.50 N 70 21 0.845 W 149 19 23.894 8.61 0.88 5978136.92 583351.61 N 70 21 0.842 W 149 19 23.803 13.39 1.36 5978136.46 583356.40 N 70 21 0.837 W 149 1923.663 19.94 1.38 5978135.19 583362.97 N 70 21 0.824 W 149 1923.472 22.88 1.97 5978134.49 583365.91 N 70 21 0.817 W 149 1923.386 31.71 0.32 5978132.49 583374.76 N 70 21 0.796 W 149 1923.128 42.25 2.34 5978131.27 583385.31 N 70 21 0.783 W 149 1922.820 55.90 1.98 5978130.55 583398.97 N 70 21 0.774 W 149 1922.421 71.59 1.16 5978129.78 583414.68 N 7021 0.765 W 149 1921.962 89.61 1.81 5978128.81 583432.70 N 7021 0.753 W 1491921.436 I Grid Coordinates I Geographic Coordinates I 7/16/2002-2:32 PM Station ID I MD Incl Azim I TVD VSec NI-S EI-W I DLS I Northing I Easting I Latitude I Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) e /1 cOtt) (ftUS) (ftUS) 1413.52 14.30 97.36 1405.27 111 .76 -13.54 110.98 2.58 5978126.72 583454.1 0 N 7021 0.730 W 1491920.811 1506.90 17.03 96.98 1495.18 136.96 -16.68 136.00 2.93 5978123.86 583479.14 N 7021 0.700 W 149 1920.080 1599.64 17.13 95.04 1583.83 164.17 -19.53 163.08 0.62 5978121.31 583506.25 N 7021 0.672 W 149 19 19.289 1693.23 19.06 95.05 1672.78 193.18 -22.08 192.04 2.06 5978119.07 583535.23 N 7021 0.646 W 149 19 18.443 1780.75 20.16 96.82 1755.23 222.52 -25.13 221.25 1.43 5978116.35 583564.4 7 N 7021 0.616 W 149 19 17.589 1874.69 22.11 100.29 1842.85 256.38 -30.21 254.72 2.47 5978111.64 583598.00 N 7021 0.566 W 149 19 16.611 1968.04 24.33 99.51 1928.63 293.17 -36.53 290.98 2.40 5978105.73 583634.32 N 7021 0.504 W 149 19 15.551 2061.28 28.84 99.26 2011.99 334.88 -43.33 332.13 4.84 5978099.39 583675.54 N 7021 0.437 W 149 19 14.348 2152.90 32.67 96.89 2090.71 381.71 -49.85 378.51 4.38 5978093.39 583721.99 N 70 21 0.373 W 149 19 12.993~ 2246.60 35.82 97.44 2168.16 434.42 -56.44 430.82 3.38 5978087.38 583774.36 N 70 21 0.308 W 149 19 11.461 " 2341.64 38.43 101.86 2243.95 491.73 -66. 11 487.32 3.93 5978078.34 583830.96 N 7021 0.213 W 149 19 9.81~ 2435.13 40.76 101.67 2315.98 551.22 -78.26 545.65 2.50 5978066.84 583889.42 N 70 21 0.094 W 149 198.108 2529.34 40.36 102.88 2387.56 612.35 -91.28 605.51 0.94 5978054.49 583949.41 N 70 20 59.966 W 149 196.359 2623.44 41.17 100.19 2458.83 673.70 -103.55 665.70 2.06 5978042.89 584009.73 N 70 20 59.845 W 149 194.600 2716.46 40.40 99.93 2529.26 734.44 -114.17 725.53 0.85 5978032.94 584069.67 N 70 20 59.740 W 149 192.852 2806.50 40.23 97.81 2597.92 792.69 -123.15 783.08 1.53 5978024.60 584127.31 N 70 20 59.652 W 149 19 1 .170 2899.43 38.85 98.59 2669.59 851.85 -131.58 841 .64 1.58 5978016.82 584185.95 N 702059.569 W 149 1859.459 2993.34 38.85 98.72 2742.72 910.76 -140.45 899.87 0.09 5978008.60 584244.28 N 702059.482 W 149 1857.757 3085.86 38.58 98.35 2814.91 968.62 -149.04 957.10 0.38 5978000.65 584301.59 N 70 20 59.397 W 149 18 56.085 3180.01 38.66 97.51 2888.47 1027.38 -157.14 1015.30 0.56 5977993.19 584359.87 N 702059.317 W 149 1854.384 3273.13 39.31 96.61 2960.86 1085.94 -164.34 1073.44 0.93 5977986.64 584418.08 N 702059.247 W 149 1852.685 3364.88 39.94 94.89 3031.53 1144.38 -170.20 1131.65 1.38 5977981.44 584476.35 N 70 20 59.189 W 149 1850.984 3458.18 40.06 94.52 3103.00 1204.21 -175.11 1191.42 0.29 5977977.18 584536.16 N 702059.140 W 149 1849.237 3550.85 40.27 93.76 3173.82 1263.81 -179.43 1251.04 0.58 5977973.53 584595.82 N 70 20 59.098 W 149 1847.495 3643.71 40.42 93.30 3244.59 1323.69 -183.13 1311.04 0.36 5977970.50 584655.85 N 70 20 59.061 W 149 18 45.741,~ 3737.53 40.42 93.29 3316.02 1384.26 -186.63 1371.77 0.01 5977967.68 584716.61 N 70 20 59.027 W 149 18 43.96l 3830.20 40.59 92.81 3386.48 1444.17 -189.83 1431.88 0.38 5977965.15 584776.74 N 70 20 58.995 W 149 1842.210 3923.50 41.00 92.70 3457.11 1504.81 -192.76 1492.76 0.45 5977962.89 584837.65 N 70 20 58.966 W 149 18 40.431 4017.91 40.62 92.42 3528.57 1566.18 -195.51 1554.40 0.45 5977960.82 584899.31 N 70 20 58.939 W 149 18 38.629 4108.72 40.02 93.40 3597.81 1624.65 -198.49 1613.08 0.96 5977958.50 584958.02 N 702058.910 W 149 1836.914 4202.08 39.57 93.82 3669.54 1684.17 -202.26 1672.72 0.56 5977955.40 585017.69 N 702058.873 W 149 1835.172 4295.95 39.24 95.29 3742.07 1743.61 -206.98 1732.12 1.05 5977951.33 585077.13 N 70 20 58.826 W 149 18 33.436 4389.20 38.98 95.64 3814.43 1802.35 -212.59 1790.67 0.37 5977946.38 585135.74 N 70 20 58.771 W 149 18 31 .725 4482.23 38.62 96.10 3886.93 1860.58 -218.55 1848.66 0.50 5977941.07 585193.78 N 702058.712 W 149 1830.030 4577.76 38.72 97.16 3961.52 1920.23 -225.44 1907.95 0.70 5977934.83 585253.14 N 70 20 58.644 W 149 18 28.298 I Grid Coordinates I Geographic Coordinates I L-105 ASP Final Survey.xls Page 2 of 4 7/16/2002-2:32 PM Station ID MD Incl Azim TVD VSec NI-S EI-W DlS Northing I Easting I latitude I longitude (ft) n n (ft) (ft) (ft) (ft) (° /1 OOft) (ftUS) (ftUS) 4671.37 38.87 97.86 4034.48 1978.87 -233.11 1966.09 0.50 5977927.82 585311.36 N 70 20 58.569 W 149 18 26.598 4763.92 39.08 98.00 4106.43 2037.08 -241 .14 2023.75 0.25 5977920.43 585369.10 N 70 20 58.489 W 149 18 24.914 4857.29 40.02 99.21 4178.42 2096.53 -250.04 2082.53 1.30 5977912.18 585427.97 N 702058.402 W 149 1823.196 4953.63 40.78 100.95 4251.79 2158.94 -260.97 2144.00 1.41 5977901.93 585489.55 N 70 20 58.294 W 149 18 21.400 5045.12 41.93 101.87 4320.46 2219.31 -272.94 2203.25 1.42 5977890.63 585548.92 N 702058.176 W 149 18 19.668 5137.43 42.72 101.65 4388.71 2281.37 -285.60 2264.1 0 0.87 5977878.64 585609.90 N 702058.051 W 149 18 17.890 5231.38 42.11 101.35 4458.07 2344.66 -298.24 2326.20 0.68 5977866.70 585672.13 N 70 20 57.927 W 149 18 16.076 5324.07 42.30 100.86 4526.73 2406.86 -310.23 2387.30 0.41 5977855.39 585733.36 N 70 20 57.809 W 149 18 14.290 5418.21 42.21 99.84 4596.41 2470.14 -321.60 2449.57 0.73 5977844.71 585795.74 N 70 20 57.697 W 149 18 12.470 5511.36 42.09 99.98 4665.47 2532.63 -332.36 2511 .15 0.16 5977834.64 585857.43 N 70 20 57.591 W 149 18 1 0.6r~~'\ 5605.70 42.30 99.87 4735.37 2595.98 -343.28 2573.56 0.24 5977824.41 585919.96 N 70 20 57.483 W 149 18 8.84ï 5702.15 41.82 99.60 4806.97 2660.57 -354.21 2637.25 0.53 5977814.19 585983.75 N 702057.375 W 149 18 6.986 5794.47 42.13 100.42 4875.61 2722.30 -364.94 2698.05 0.68 5977804.14 586044.67 N 70 20 57.270 W149185.210 5887.49 42.19 100.27 4944.56 2784.70 -376.15 2759.47 0.13 5977793.61 586106.20 N 70 20 57.159 W 149 183.415 5980.04 42.02 100.39 5013.23 2846.73 -387.28 2820.52 0.20 5977783.17 586167.36 N 70 20 57.050 W 149 18 1.631 6072.44 42.40 100.68 5081.67 2908.77 -398.63 2881.55 0.46 5977772.50 586228.51 N 70 20 56.938 W 149 1759.848 6166.14 43.36 100.81 5150.33 2972.49 -410.52 2944.19 1.03 5977761.31 586291.28 N 70 20 56.821 W 149 17 58.017 6258.29 43.89 100.81 5217.03 3036.01 -422.44 3006.64 0.58 5977750.08 586353.85 N 70 20 56.703 W 149 17 56.192 6351.72 45.15 100.70 5283.65 3101.48 -434.67 3071.00 1.35 5977738.57 586418.33 N 70 20 56.583 W 149 1754.312 6446.08 45.63 99.43 5349.91 3168.62 -446.40 3137.13 1.08 5977727.57 586484.59 N 70 20 56.467 W 149 17 52.379 6540.11 45.45 99.59 5415.77 3235.73 -457.49 3203.33 0.23 5977717.22 586550.89 N 70 20 56.358 W 149 17 50.445 6633.57 45.12 99.37 5481.53 3302.13 -468.43 3268.83 0.39 5977707.01 586616.51 N 70 20 56.250 W 149 17 48.531 6727.89 44.74 100.00 5548.31 3368.73 -479.64 3334.50 0.62 5977696.54 586682.29 N702056.139 W1491746.612 6821.53 44.17 100.52 5615.15 3434.29 -491.32 3399.03 0.72 5977685.58 586746.94 N 70 20 56.024 W 149 1744.727 6914.49 43.21 99.33 5682.37 3498.48 -502.39 3462.27 1.36 5977675.21 586810.30 N 70 20 55.915 W 149 17 42.87~. 7009.06 41.68 98.98 5752.15 3562.30 -512.55 3525.28 1.64 5977665.76 586873.41 N 70 20 55.815 W 1491741.03 7101.94 40.31 99.14 5822.25 3623.22 -522.14 3585.45 1.48 5977656.84 586933.68 N 702055.720 W 149 1739.279 7194.12 39.62 99.71 5892.90 3682.42 -531.83 3643.86 0.85 5977647.79 586992.19 N 70 20 55.624 W 149 17 37.573 7287.33 39.21 99.53 5964.91 3741.59 -541.72 3702.21 0.46 5977638.55 587050.64 N 70 20 55.527 W 149 17 35.868 7381.00 38.61 98.92 6037.80 3800.42 -551 .16 3760.28 0.76 5977629.77 587108.80 N 70 20 55.434 W 149 1734.171 7472.77 38.03 98.88 6109.80 3857.33 -559.96 3816.50 0.63 5977621.59 587165.11 N 70 20 55.347 W 149 17 32.528 7566.80 36.72 99.47 6184.52 3914.40 -569.06 3872.84 1.44 5977613.12 587221.55 N 70 20 55.257 W 149 17 30.882 7659.81 35.64 99.00 6259.59 3969.30 -577.87 3927.04 1.20 5977604.91 587275.83 N 70 20 55.170 W 149 1729.298 7753.68 34.25 99.39 6336.54 4023.06 -586.46 3980.11 1.50 5977596.91 587328.99 N 70 20 55.086 W 149 1727.747 7848.37 33.07 99.90 6415.35 4075.54 -595.25 4031.85 1.28 5977588.70 587380.82 N 70 20 54.999 W 149 17 26.235 I Grid Coordinates I Geographic Coordinates J L-105 ASP Final Survey.xls Page 3 of 4 7/16/2002-2:32 PM Station ID I MD Incl I Azim I TVD I VSec I NI-S I EI-W I DLS I Northing I Easting I Latitude I Longitude (ft) n (°) (ft) (ft) (ft) (ft) (° /1 OOft) (ftUS) (ftUS) 7942.30 31.47 101.05 6494.77 4125.66 -604.35 4081.17 1.82 5977580.15 587430.23 N 70 20 54.909 W 149 17 24.794 8035.64 31.26 102.28 6574.47 4174.17 -614.18 4128.74 0.72 5977570.86 587477.91 N 70 20 54.812 W 149 17 23.404 8129.88 31.15 102.05 6655.08 4222.90 -624.46 4176.47 0.17 5977561.10 587525.75 N 70 20 54.711 W 149 1722.010 8223.26 31.22 101.25 6734.96 4271.18 -634.23 4223.83 0.45 5977551.86 587573.20 N 70 20 54.614 W 149 1720.626 8276.11 31.13 101.04 6780.18 4298.51 -639.52 4250.67 0.27 5977546.87 587600.10 N 702054.562 W 149 17 19.842 8360.00 31.13 101.04 6851.99 4341.84 -647.82 4293.24 0.00 5977539.04 587642.75 N 70 20 54.480 W 149 17 18.598 ~, ,~ L-105 ASP Final Survey.xls Page 4 of 4 7/16/2002-2:32 PM "" '(>""' \1)' 0 ¿ 1) bp L-105 Survey Report - Geodetic Survey I DLS Computation Method: Vertical Section Azimuth: Vertical Section Origin: TVD Reference Datum: TVD Reference Elevation: Sea Bed I Ground Level Elevation: Magnetic Declination: Total Field Strength: Magnetic Dip: Declination Date: Magnetic Declination Model: North Reference: Total Corr Mag North -> True North: Local Coordinates Referenced To: Report Date: 16-Jul-2002 Client: BP Exploration Alaska Field: Prudhoe Bay Unit - WOA (Drill Pads) Structure I Slot: L-Pad 1 L-105 Well: L -1 05 Borehole: L-1 05 UWIIAPI#: 500292307500 Survey Name I Date: L-1051 July 16, 2002 Tort I AHD I DDII ERD ratio: 89.962° 14346,83 ft 15.6791 0.634 ~ Grid Coordinate System: NAD27 Alaska State Planes, Zone 4, US Feet Location LatlLong: N 7021 0.864, W 1491924.055 Location Grid NlE Y IX: N 5978139.020 ftUS, E 583342.980 ftUS Grid Convergence Angle: +0.63725055° Grid Scale Factor: 0,99990789 Station ID MD Incl Azim TVD VSec NI-S (ft) e) (°) (ft) (ft) (ft) 0.00 0.00 0.00 0.00 0.00 0.00 50.00 0.37 132.80 50.00 0.13 -0.11 100.00 0.38 146.44 100.00 0.38 -0.36 150.00 0.35 130.81 150.00 0.62 -0.60 200.00 0.49 130.46 200.00 0.93 -0.83 250.00 0.43 119.62 249.99 1.29 -1.07 358.00 0.70 104.48 357.99 2.32 -1 .43 451.00 0.99 98.03 450.98 3.69 -1.69 542.00 1.57 95.53 541.96 5.72 -1.92 633.00 2.37 94.98 632.90 8.84 -2.20 725.00 3.62 96.88 724.77 13.64 -2.71 817.00 4.74 105.12 816.53 20.32 -4.05 851.25 5.39 103.10 850.64 23.33 -4.78 945.27 5.69 103.66 944.23 32.38 -6.89 1038.52 7.46 92.33 1036.86 43.00 -8.22 1132.44 9.29 94.68 1129.78 56.63 -9.09 1224.95 10.29 92.36 1220.94 72.29 -10.04 1318.72 11.92 94.87 1312.95 90.28 -11.21 L-105 ASP Final Survey.xls Page 1 of 4 Schlum rger Minimum Curvature I Lubinski 98,580° N 0.000 ft, E 0.000 ft KB 78.800 ft relative to MSL 44.100 ft relative to MSL +25.855° 57500.539 nT 80.775° July 16, 2002 BGGM 2002 True North +25.855° Well Head Grid Coordinates Geographic Coordinates EI-W DLS Northing Easting Latitude Longitude (ft) (° 11 OOft) (ftUS) (ftUS) 0.00 5978139.02 583342.98 N 70 21 0.864 W 149 1924.055 0.12 0.74 5978138.91 583343.10 N 70 21 0.863 W 149 1924.051 0.33 0.18 5978138.67 583343.31 N 70 21 0.860 W 149 1924.045 0.54 0.21 5978138.43 583343.52 N 70 21 0.858 W 149 1924.039 0.81 0.28 5978138.20 583343.80 N 70 21 0.855 W 149 1924.031 1.14 0.21 5978137.97 583344.13 N 7021 0.853 W 149 1924.021 2.13 0.28 5978137.61 583345.13 N 70 21 0.850 W 149 1923.992 3.48 0.33 5978137.37 583346.47 N 7021 0.847 W 149 1923.953 5.50 0.64 5978137.17 583348.50 N 70 21 0.845 W 1491923.894 8.61 0.88 5978136.92 583351.61 N 70 21 0.842 W 149 1923.803 13.39 1.36 5978136.46 583356.40 N 70 21 0.837 W 149 1923.663 19.94 1.38 5978135.19 583362.97 N 70 21 0.824 W 149 1923.472 22.88 1.97 5978134.49 583365.91 N 7021 0.817 W 149 1923.386 31.71 0.32 5978132.49 583374.76 N 7021 0.796 W 149 1923.128 42.25 2.34 5978131.27 583385.31 N 7021 0.783 W 149 1922.820 55.90 1.98 5978130.55 583398.97 N 7021 0.774 W 149 1922.421 71.59 1.16 5978129.78 583414.68 N7021 0.765 W1491921.962 89.61 1.81 5978128.81 583432.70 N 7021 0.753 W 1491921.436 I Grid Coordinates I Geographic Coordinates I 7/16/2002-2:32 PM Station ID MD Incl Azim TVD VSec NI-S EJ-W DLS Northing Easting Latitude Longitude (ft) (") n (ft) (ft) (ft) (ft) (° /1 OOft) (ftUS) (ftUS) 1413.52 14.30 97.36 1405.27 111 .76 -13.54 110.98 2.58 5978126.72 583454.10 N 7021 0.730 W 149 1920.811 1506.90 17.03 96.98 1495.18 136.96 -16.68 136.00 2.93 5978123.86 583479.14 N 7021 0.700 W 149 1920.080 1599.64 17.13 95.04 1583.83 164.17 -19.53 163.08 0.62 5978121.31 583506.25 N 70 21 0.672 W 149 19 19.289 1693.23 19.06 95.05 1672.78 193.18 -22.08 192.04 2.06 5978119.07 583535.23 N 7021 0.646 W 149 19 18.443 1780.75 20.16 96.82 1755.23 222.52 -25.13 221.25 1.43 5978116.35 583564.47 N 7021 0.616 W 149 19 17.589 1874.69 22.11 100.29 1842.85 256.38 -30.21 254.72 2.47 5978111.64 583598.00 N 70 21 0.566 W 149 19 16.611 1968.04 24.33 99.51 1928.63 293.17 -36.53 290.98 2.40 5978105.73 583634.32 N 70 21 0.504 W 149 19 15.551 2061.28 28.84 99.26 2011.99 334.88 -43.33 332.13 4.84 5978099.39 583675.54 N 70 21 0.437 W 1491914.348 2152.90 32.67 96.89 2090.71 381.71 -49.85 378.51 4.38 5978093.39 583721.99 N 70 21 0.373 W 149 19 12.993 2246.60 35.82 97.44 2168.16 434.42 -56.44 430.82 3.38 5978087.38 583774.36 N 70 21 0.308 W 149 19 11 .464 2341.64 38.43 101.86 2243.95 491 .73 -66.11 487.32 3.93 5978078.34 583830.96 N 7021 0.213 W 149 199.813 ~ 2435.13 40.76 101.67 2315.98 551 .22 -78.26 545.65 2.50 5978066.84 583889.42 N 70 21 0.094 W 149 19 8.108 2529.34 40.36 102.88 2387.56 612.35 -91.28 605.51 0.94 5978054.49 583949.41 N 702059.966 W 149 196.359 2623.44 41.17 100.19 2458.83 673.70 -103.55 665.70 2.06 5978042.89 584009.73 N 702059.845 W 149 194.600 2716.46 40.40 99.93 2529.26 734.44 -114.17 725.53 0.85 5978032.94 584069.67 N 702059.740 W 149 192.852 2806.50 40.23 97.81 2597.92 792.69 -123.15 783.08 1.53 5978024.60 584127.31 N 702059.652 W 149 19 1 .170 2899.43 38.85 98.59 2669.59 851.85 -131.58 841 .64 1.58 5978016.82 584185.95 N 702059.569 W 149 1859.459 2993.34 38.85 98.72 2742.72 910.76 -140.45 899.87 0.09 5978008.60 584244.28 N 702059.482 W 149 1857.757 3085.86 38.58 98.35 2814.91 968.62 -149.04 957.10 0.38 5978000.65 584301.59 N 70 20 59.397 W 149 18 56.085 3180.01 38.66 97.51 2888.47 1027.38 -157.14 1015.30 0.56 5977993.19 584359.87 N 702059.317 W 1491854.384 3273.13 39.31 96.61 2960.86 1085.94 -164.34 1073.44 0.93 5977986.64 584418.08 N 702059.247 W 149 1852.685 3364.88 39.94 94.89 3031.53 1144.38 -170.20 1131.65 1.38 5977981.44 584476.35 N 702059.189 W 149 1850.984 3458.18 40.06 94.52 3103.00 1204.21 -175.11 1191.42 0.29 5977977.18 584536.16 N 702059.140 W 149 1849.237 3550.85 40.27 93.76 3173.82 1263.81 -179.43 1251.04 0.58 5977973.53 584595.82 N 70 20 59.098 W 149 1847.495 3643.71 40.42 93.30 3244.59 1323.69 -183.13 1311.04 0.36 5977970.50 584655.85 N 70 20 59.061 W 149 1845.741 3737.53 40.42 93.29 3316.02 1384.26 -186.63 1371.77 0.01 5977967.68 584716.61 N 702059.027 W 149 1843.966 3830.20 40.59 92.81 3386.48 1444.17 -189.83 1431.88 0.38 5977965.15 584776.74 N 70 20 58.995 W 149 1842.210 3923.50 41.00 92.70 3457.11 1504.81 -192.76 1492.76 0.45 5977962.89 584837.65 N 702058.966 W 149 1840.431 4017.91 40.62 92.42 3528.57 1566.18 -195.51 1554.40 0.45 5977960.82 584899.31 N 70 20 58.939 W 149 1838.629 4108.72 40.02 93.40 3597.81 1624.65 -198.49 1613.08 0.96 5977958.50 584958.02 N 70 20 58.910 W 149 1836.914 4202.08 39.57 93.82 3669.54 1684.17 -202.26 1672.72 0.56 5977955.40 585017.69 N 702058.873 W 1491835.172 4295.95 39.24 95.29 3742.07 1743.61 -206.98 1732.12 1.05 5977951.33 585077.13 N 702058.826 W 149 1833.436 4389.20 38.98 95.64 3814.43 1802.35 -212.59 1790.67 0.37 5977946.38 585135.74 N 70 20 58.771 W 149 1831.725 4482.23 38.62 96.10 3886.93 1860.58 -218.55 1848.66 0.50 5977941.07 585193.78 N 702058.712 W 149 1830.030 4577.76 38.72 97.16 3961.52 1920.23 -225.44 1907.95 0.70 5977934.83 585253.14 N 70 20 58.644 W 149 18 28.298 I Grid Coordinates I Geographic Coordinates I L-105 ASP Final Survey.xls Page 2 of 4 7/16/2002-2:32 PM Station Ie Me Incl Azim rve VSec NI-S EI-W eLS Northing Easting Latitude Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) e /1 OOft) (ftUS) (ftUS) 4671.37 38.87 97.86 4034.48 1978.87 -233.11 1966.09 0.50 5977927.82 585311.36 N 70 20 58.569 W 149 1826.598 4763.92 39.08 98.00 4106.43 2037.08 -241.14 2023.75 0.25 5977920.43 585369.1 0 N 702058.489 W 149 1824.914 4857.29 40.02 99.21 4178.42 2096.53 -250.04 2082.53 1.30 5977912.18 585427.97 N 702058.402 W 149 1823.196 4953.63 40.78 100.95 4251.79 2158.94 -260.97 2144.00 1.41 5977901.93 585489.55 N 70 20 58.294 W 149 18 21 .400 5045.12 41.93 101.87 4320.46 2219.31 -272.94 2203.25 1.42 5977890.63 585548.92 N 702058.176 W 149 18 19.668 5137.43 42.72 101.65 4388.71 2281.37 -285.60 2264.10 0.87 5977878.64 585609.90 N 702058.051 W 149 18 17.890 5231.38 42.11 101.35 4458.07 2344.66 -298.24 2326.20 0.68 5977866.70 585672.13 N 70 20 57.927 W 149 18 16.076 5324.07 42.30 100.86 4526.73 2406.86 -310.23 2387.30 0.41 5977855.39 585733.36 N 70 20 57.809 W 149 18 14.290 5418.21 42.21 99.84 4596.41 2470.14 -321.60 2449.57 0.73 5977844.71 585795.74 N 7020 57.697 W 149 18 12.470 5511.36 42.09 99.98 4665.47 2532.63 -332.36 2511.15 0.16 5977834.64 585857.43 N 70 20 57.591 W 149 18 10.671 5605.70 42.30 99.87 4735.37 2595.98 -343.28 2573.56 0.24 5977824.41 585919.96 N 70 20 57.483 W 149 188.847 ~ 5702.15 41.82 99.60 4806.97 2660.57 -354.21 2637.25 0.53 5977814.19 585983.75 N 70 20 57.375 W 149 186.986 5794.47 42.13 1 00.42 4875.61 2722.30 -364.94 2698.05 0.68 5977804.14 586044.67 N 70 20 57.270 W 149 185.210 5887.49 42.19 100.27 4944.56 2784.70 -376.15 2759.47 0.13 5977793.61 586106.20 N 702057.159 W 149 183.415 5980.04 42.02 100.39 5013.23 2846.73 -387.28 2820.52 0.20 5977783.17 586167.36 N 7020 57.050 W 149 18 1.631 6072.44 42.40 100.68 5081.67 2908.77 -398.63 2881.55 0.46 5977772.50 586228.51 N 702056.938 W 149 1759.848 6166.14 43.36 100.81 5150.33 2972.49 -410.52 2944.19 1.03 5977761.31 586291.28 N 70 20 56.821 W 149 1758.017 6258.29 43.89 100.81 5217.03 3036.01 -422.44 3006.64 0.58 5977750.08 586353.85 N 702056.703 W 149 17 56.192 6351.72 45.15 100.70 5283.65 3101.48 -434.67 3071.00 1.35 5977738.57 586418.33 N 70 20 56.583 W 149 1754.312 6446.08 45.63 99.43 5349.91 3168.62 -446.40 3137.13 1.08 5977727.57 586484.59 N 702056.467 W 149 1752.379 6540.11 45.45 99.59 5415.77 3235.73 -457.49 3203.33 0.23 5977717.22 586550.89 N 702056.358 W 149 1750.445 6633.57 45.12 99.37 5481.53 3302.13 -468.43 3268.83 0.39 5977707.01 586616.51 N 70 20 56.250 W 149 1748.531 6727.89 44.74 100.00 5548.31 3368.73 -479.64 3334.50 0.62 5977696.54 586682.29 N 702056.139 W 149 1746.612 6821.53 44.17 100.52 5615.15 3434.29 -491.32 3399.03 0.72 5977685.58 586746.94 N 70 20 56.024 W 149 1744.727 6914.49 43.21 99.33 5682.37 3498.48 -502.39 3462.27 1.36 5977675.21 586810.30 N 702055.915 W 149 1742.878 7009.06 41.68 98.98 5752.15 3562.30 -512.55 3525.28 1.64 5977665.76 586873.41 N 702055.815 W 149 1741.037 '~ 7101.94 40.31 99.14 5822.25 3623.22 -522.14 3585.45 1.48 5977656.84 586933.68 N 70 20 55.720 W 149 1739.279 7194.12 39.62 99.71 5892.90 3682.42 -531.83 3643.86 0.85 5977647.79 586992.19 N 702055.624 W 149 1737.573 7287.33 39.21 99.53 5964.91 3741.59 -541.72 3702.21 0.46 5977638.55 587050.64 N 70 20 55.527 W 149 17 35.868 7381.00 38.61 98.92 6037.80 3800.42 -551.16 3760.28 0.76 5977629.77 587108.80 N 70 20 55.434 W 149 1734.171 7472.77 38.03 98.88 6109.80 3857.33 -559.96 3816.50 0.63 5977621.59 587165.11 N 70 20 55.347 W 149 1732.528 7566.80 36.72 99.47 6184.52 3914.40 -569.06 3872.84 1.44 5977613.12 587221.55 N 70 20 55.257 W 149 17 30.882 7659.81 35.64 99.00 6259.59 3969.30 -577.87 3927.04 1.20 5977604.91 587275.83 N 702055.170 W 149 1729.298 7753.68 34.25 99.39 6336.54 4023.06 -586.46 3980.11 1.50 5977596.91 587328.99 N 702055.086 W 149 1727.747 7848.37 33.07 99.90 6415.35 4075.54 -595.25 4031.85 1.28 5977588.70 587380.82 N 70 20 54.999 W 149 17 26.235 I Grid Coordinates I Geographic Coordinates I L-105 ASP Final Survey.xls Page 3 of 4 7/16/2002-2:32 PM Station ID MD Incl Azim TVD VSec NI-S EI-W DLS Northing Easting Latitude Longitude (1t) (°) (") (ft) (ft) (ft) (ft) (" /1 OOft) (ftUS) (ftUS) 7942.30 31.47 101.05 6494.77 4125.66 -604.35 4081.17 1.82 5977580.15 587430.23 N 702054.909 W 1491724.794 8035.64 31.26 102.28 6574.47 4174.17 -614.18 4128.74 0.72 5977570.86 587477.91 N 702054.812 W 149 1723.404 8129.88 31.15 102.05 6655.08 4222.90 -624.46 4176.47 0.17 5977561.10 587525.75 N 702054.711 W 149 1722.010 8223.26 31.22 101.25 6734.96 4271.18 -634.23 4223.83 0.45 5977551.86 587573.20 N 702054.614 W 149 1720.626 8276.11 31.13 101.04 6780.18 4298.51 -639.52 4250.67 0.27 5977546.87 587600.10 N 70 20 54.562 W 149 17 19.842 8360.00 31.13 101.04 6851.99 4341.84 -647.82 4293.24 0.00 5977539.04 587642.75 N 70 20 54.480 W 149 17 18.598 "--" .~ L-105 ASP Final Survey.xls Page 4 of 4 7/16/2002-2:32 PM Sc~.bePDer Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth "'- ' ...~- Well L-105 ~~-O5<l L-109 ð-oJ"aO) L-108 a~- In9 L-108 I L-108 J/ -..~ Job# Log Description 22343 CET/USIT 22341 USIT 22315 OH MWD GR 22315 MD VISION GR 22315 TVD VISION GR Date 07/16/02 06/14/02 06/27/02 06/27/02 06/27/02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered: RECEIVED AUG 20 2002 .AJaska O~ & Gé!ß Cone. Commiaion Anchorage 8/16/2002 NO. 2324 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Color Sepia BL CD 2 2 1 1 1 Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 A TTN: Beth Receiv~~J L Cbo1~ -~ ~ L-I Cf6 ~ <,~ Sc~.beI'Dep Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Beth Well L-105 ~~~O5 "tJ L-105 ...¡" L-109 ~()/-~() J L-108 ~Od." 109 L-109 ' L-110 L-111 L-112 L-113 L-114 v Job# Log Description Date 07/15/02 07/19/02 07/9&10/02 06/27/02 06/27/02 06/27/02 06/27/02 06/27/02 06/27/02 06/27/02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered: 22342 CET/USIT 22344 USIT 22340 USIT (2) & SCMT 22314 OH PEXlAIT/BHC 22314 PEX-AIT 22314 BHC 22314 PEX-NEUTRON/DENSITY 22314 PEX-QUAD COMBO 22314 PEX-SSTVD 22314 PEX-HCAL RECE\VED AUG 16 2002 Alaska O~ & Gas Coni. Gomt11issioo Anchorage 8/15/2002 NO. 2313 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Color Sepia CD BL 2 2 6 1 1 1 1 1 1 1 Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 A TTN: Beth Received by: ( f MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Ine. Dispatched To: Lisa Weepie Well No L-105i Date Dispatche O-Jan-OO Installation/Rig Nabors 9ES Dispatched By: Nate Rose Data No Of Prints No of Floppies Su rveys aæ-05'6 2 RECE VED JUL 2 ,; 2002 Alalka Oil" Gas Cons f\-^--' , AnchoragS VVI'"".On Received By: ~ b..fk Or' =:J Please sign and return to: James H. Johnson BP Exploration (Alaska) Inc. Petrotechnical Data Center (LR2-1) 900 E. Benson Blvd. Anchorage, Alaska 99508 Fax: 907-564-4005 e-mail address:johnsojh@bp.com LWD Log Delivery V1.1, Dec '97 ( ( ~!ìÆ\TurIÞ rml!ç cQ) U Lfû Lb ~W J í¡^\ t \, ¡ Ll \ ¡ F"""~ ; LiU TONY KNOWLES, GOVERNOR AI,ASIiA OIL AlQ) GAS CONSERVATION COMMISSION 333 W. ]TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Lowell Crane Senior Drilling Engineer BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage, ~ 99519-6612 Re: Prudhoe Bay Unit L-l05i BP Exploration (Alaska) Inc Permit No: 202-058 Sur. Loc. 2415' NSL, 3573' WEL, SEC 34, T12N, RIlE UM Btmhole Loc. 3514' SNL, 4221' WEL, SEC 35, T12N, RIlE, UM Dear Mr. Crane, Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits or approvals 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. A diverter waiver has been requested for Well L-l05i for drilling the shallow section to a depth of approximately -2570' TVDss. The L-Pad in the western portion of the Prudhoe Bay Unit is located over a thick accumulation of sub-permafrost methane hydrates that are underlain by a significant accumulation of free hydrocarbon gas. The shallow section in the well would include the interval containing the methane hydrates, but not the underlying free gas accumulation. At least fifteen wells have been drilled from L-Pad, which demonstrates the shallow section can be successfully drilled without a diverter by using specialized mud treatments and drilling procedures. Therefore, the diverter waiver for well PBU L-l05i is approved provided BPXA employs a high-resolution, early kick detection system in addition to the other hydrate mitigation procedures described in the permit to drill application for the subject well. Conlmission approval of the diverter waiver for PBU L-l05i does not guarantee approval of future diverter waiver requests on this or any other drill site. Diverter waiver applications will continue to be carefully considered on a case-by-case basis. Permit No. 202-058 June 25, 2002 Page 2 of2 f: The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Cd1 ~'~ camm~eChSli Taylor Chair BY ORDER OF THE COMMISSION DATED this~gt\ day of June, 2002 jj cÆnclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ALASKA ( STATE OF ALASKA AND GAS CONSERVATION COMM( PERMIT TO DRILL 20 AAC 25.005 JON \tJý^ '~, ((110"- Ær ~/~-od- Hole 42" 12-1/4" 8-3/4" Lenath 80' 2742' 8756' 0 Exploratory 0 Stratigraphic Test 0 Development Oil II Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Planned RKB = 75.5' Prudhoe Bay Field / Borealis 6. Property Designation Pool (Undefined) ADL 028238 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number I L -1 05i 9. Approximate spud date 03/30/02 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 8756' MD / 7040' TVD 0 17. Anticipated pressure {sye 20 MC 25.035 (e) (2)} 42 Maximum surface 2725 psig, At total depth (TVD) 6490' I 3374 psig Setting Depth Top Bottom Quantitv of Cement MD TVD MD TVD / (include staae data) Surface Surface 110' 110' / 260 sx Arctic Set (Approx.) Surface Surface 2742' 2578' 484 sx Articset Lite, 287 sx 'G' Surface Surface 8756' 7040' 208 sx Class 'G' 11. Type Bond (See 20 AAC 25.025) 1 a. Type of work II Drill 0 Redrill 0 Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2415' NSL, 3573' WEL, SEC. 34, T12N, R11 E, UM At top of productive interval 3460' SNL, 4652' WEL, SEC. 35, T12N, R11 E, UM At total depth 3514' SNL, 4221' WEL, SEC. 35, T12N, R11E, UM 12. Distance to nearest property line 13. Distance to nearest well ADL 028239, 1053' MD L.106 is 15' away at surface to 400' MD 16. To be completed for deviated wells Kick Off Depth 400' Maximum Hole Angle 18. Casin~ Program Specifications Size Casina Weiaht Grade Couplina 20" 91.5# H-40 WLD 9-5/8" 40# L-80 BTC 7" 26# L-80 BTC-m 1 b. Type of well Number 2S100302630-277 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical feet feet feet feet Junk (measured) Plugs (measured) Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented MD TVD RECEIVED FEB 2 0 2002 Perforation depth: measured Alaska Oil & Gas Cons, Commission Anchorage true vertical II Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer Name/Number: Neil Magee, 564-5119 Prepared By Name/Number: Sandra Stewman, 564-4750 21. I~::~Y c;:~::::e ;v;::rugrect to the~:eOf ;:n~;;~;~: Engin~~r Date ;2 - Z (J-az- "","'....,"\.:.'.,':",;..,;'.-'<:V.i.."..",",'.""i,:,'.,.,:'..c:::';'(:;::"::i:::Ç~ffl~i~i%>~~~,:Ç).,~~v.).:,.,.....},I¡;: " , \ " ' "," ,,' , , Permit Number API Number (Apq~ovat )~ef) See cover letter ..2. ð? - 0 S <;? 50- 0 .2. 7 - .2.. 0 0 '/ S lQ. J U 1\ for other requirements Conditions of Approval: Samples Required 0 Ves ~No Mud Log equired 0 Ves ~NO ~ \ DAD Hydrogen Sulfide Measures 0 Ves ftNO Directional Survey Required ;&ves 0 No 4lAA..J PS\ ~ Required Worki~jJ Pressure for BOPE D2K D3K D4K D5K D10K D15K 0 3.5K~i for CTU -\t:s.~ Other: \-{. \\~c..<2:""Cl.~<Q~'-'~ ~ S,,~~t"&\'<-~\~~\Cf)~~~cJ p~ 2-L? Aik. ~S.(J ~~ (h )ll..)_.Lhl.e~.þ:.v feel t4..Á )\..{..,~.~.tÞlÆ~CAJ~ V~ .. by order of ~ "':ì~'~ ~ Approved By I.Øf1gtñaI \)IQnéd BY" Commissioner the commission Date' [ì\ "'., ,l) u\ Form 10-401 Rev. 12-01-85 I.òaI1IIIIY 0eChSII1~ I ¡ Jmit I Triplicate 20. Attachments I Well Name: I L -1 05i Drill and Complete Plan Summary I Type of Well (service I producer I injector): I Single Injector Surface Location: As-Built Target'Location: Top Kuparuk Bottom Hole Location: x = 583,342.82' Y = 5,978,139.11' 2863'FNL (24151 FSL), 35731 FEL (1706' FWL), Sec. 34, T12N, R11 E X = 587,549.99' Y = 5,977,590.00' 3460 FNL (1818' FSL), 4652' FEL (626' FWL), Sec. 35, T12N, R11 E X = 587,982.38' Y = 5,977,541.64' 3514' FNL (1765' FSL), 4221' FEL (1058' FWL), Sec. 35, T12N, R11E I Rig: 1 Nabors 9ES // 1 Operating days to complete: 115.1 ./ I AFE Number: I Pending 1 Estimated Start Date: 13/30/2002 I I MD: 18756' I TVD: 17040' I I BF/MS: 130' I RKB: 175.5' I Well Design (conventional, slim hole, etc.): I Ultra Slimhole (Iongstring) I Objective: I Kuparuk Formation Mud Program: 12 %" Surface Hole (0-2742'): Fresh Water Surface Hole Mud Initial below Permafrost interval TD Densitv (ppg) 8.5 - 8.6 9.0 - 9.5 9.6 max ./ Viscosity (seconds) 300 200-250 200 Yield Point (lb/100ft") 50 - 70 30 - 45 30-45 APIFL (mls/30min) 15 - 20 <10 <10 PH 8.5- 9.5 8.5- 9.5 8.5-9.5 8 ¥4" Intermediate I Production Hole (2742' - 8756'): LSND Interval Density Tau 0 YP PV pH API HTHP (ppg) Filtrate Filtrate Upper 9.3 4-7 20-25 8-12 8.5-9.5 4-6 Interval / Top of HRZ 10.3 5-8 20-25 1 0-1 5 8.5-9.5 3-5 <10 by toTD HRZ L-105i Drilling Program (LSND) Page 2 Hydraulics: Surface Hole: 12-1/4" Interval Pump Drill AV Pump PSI ECD Motor Jet Nozzles TFA GPM Pipe (fpm) ppg-emw ("/32) (in2) 0-2,000 600 4" 17.5# 90 1800 9.7 N/A 18,18,18,13 .875 2,000'-2,742 650 4" 17.5# 110 2400 10.3 N/A 18,18,18,13 .875 Intermediate/Production Hole: 8 %" Interval Pump Drill Pipe AV Pump PSI ECD Motor Jet Nozzles TFA GPM (fpm) ppg-emw ("/32) (in2) 2742' - 8756' 575 4" 17.5# 200 3400 11.1 N/A 6x15 1.03 Di rectional: Ver. Anadrill P3 KOP: 400' Maximum Hole Angle: Close Approach Wells: Logging Program: Surface Hole Production Hole Formation Markers: Formation Tops MDbkb SV5 SV4 Base Permafrost SV3 SV2 SV1 UG4A UG3 UG1 Ma WS2 (N sands) WS1 (O sands) Obf Base L-105i Drilling Program (LSND) 42° at 2540' MD / All wells pass major risk criteria. L-106 - 15' offset to 400' /' L -1 04 - 43' offset at 400' IFR-MS corrected surveys will be used for survey validation. Gyro will be used for surface hole close approaches. Drilling: MWD / GR Open Hole: None Cased Hole: None Drilling: MWD / GR / Res / Den / Neu Open Hole: Cuttings Evaluation Cased Hole: US IT cement evaluation TVDss 1465' 1610' 1775' 1950' 2120' 2440' 2820' 3190' 3665' 3980' 4230' 4375' 4770' Estimated pore pressure, PPG Est. pore pressure 2000 psi, 9.1 ppg (Verify) ) Page 2 ( CM2 (Colville) CM1 (Colville) THRZ BHRZ (Kalubik) K-1 TKUP Kuparuk C LCU (Kuparuk B) Kuparuk A TMLV (Miluveach) TD Criteria 5110' 5745' 6230' 6380' 6407' 6480' 6490' Hydrocarbon Bearing, 3369 psi, 10.0 ppg EMW Hydrocarbon Bearíng, 3374 psi, 10.0 ppg EMW / 6850' 150' below Miluveach top Note: Kuparuk reservoir pressures to be re-verified prior to spud CasinglTubing Program: Hole Csgl WtlFt Grade Conn Length Top Btm Size Tb~ O.D. MDrrVD MDrrVD bkb 42" Insulated 20" 91.5# H-40 WLD 80' GL 110/110 12 %" 9 5/8" 40# L-80 BTC 2742' GL 2742'/2578' 8 3A" 711 26# L-80 BTC-m 8756' GL 8756'/7040' Tubing 411211 / 12.6# L-80 TC-II 7972' GL 7972'/6458' Integrity Testing: Test Point Depth Surface Casing Shoe 20' min from surface shoe Test Type LOT EMW 13.5 ppg EMW Target ~ Cement Calculations: Note: The following surface cement calculations are based upon a single stage job. A port collar will be utilized if hole conditions indicate that cement may not circulated to surface in a single stage. Casing Size 19-5/8" Surface I Basis: Lead: Based on 1766' of annulus in the permafrost @ 2500/0 excess and 116' of open hole from top of tail slur~ to base permafrost @ 30% excess. Lead TOG: To surface Tail: Based on 750' MD open hole volume + 300/0 excess + 80' shoe track volume. Tail TOG: At -1992' MD ",/ Total Cement Volume: Lead 382 bbl I 2143 ft;j 1)84 sks of Dowell ARTIGSET Lite at 10.7 ppg and 4.44 cf/sk. ./' Tail 60 bbl I 336 f~./ 287 sks of Dowell Premium 'G' at 15.8 ppg and 1 .17 cf/sk. L-105i Drilling Program (LSND) Page 3 ( Note: The production interval cementing design is a single stage slurry.utilizing 15.8 ppg G cement covering TD to 500' above the Kuparuk. Casinq Size 17" Production Longstring I Basis: Stage 1: Based on TOC 500' above top 1. Kuparuk formation + 30% excess + 80' shoe Cement Placement: From shoe to 7607 MD (estimated) / Total Cement Volume: Stage 1 43.0 bbls / 241 fy / 208 sks of Dowell Premium "G" at 15.8 ppg and 1.16cf/sk )- \>'N<l.r\qr-(è~ 0"'\C)1:'- ~~ , ~ tl{'ð~ ~ -\t>~t~ Well Control: C-c)'-t~,\tL~" Surface hole will be drilled with diverter. The intermediate hole, well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based on , the requirement for MI service up to 4000 psi the BOP equipment will be tested to 4000 / psi Diverter, BOPEand drilling fluid system schematics on file with the AOGCC. Production Interval... . Maximum anticipated BHP: 3374 psi @ 6490' TVDss - Kuparuk Sands . Maximum surface pressure: 2725 psi @ surface (based on BHP and a full column of gas from TO @ 0.10 psi/H) . Planned BOP test pressure: 4000 psi (The casing and tubing will be tested to 4000 psi.) / . Planned completion fluid: 8.8 ppg filtered seawater / 6.8 ppg Diesel Disposal: .,/' . No annular disposal in this well. . Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject 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. L-105i Drilling Program (LSND) Page 4 DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Rig Work: The 20" insulated conductor was installed November 2001. 1. Weld an FMC landing ring for the FMC Ultra slimhole wellhead on the conductor. 2. If necessary, level the pad and prepare location for rig move. 3. Ensure any required plugs and I or well shut-ins have been accomplished in nearby wells for rig move and close approach concerns. Rig Operations: / , ~~o.~~~~\)t.r\~r 1. MIRU Nabors 9ES on conductor L-105i well slot. / 2. Nipple up diverter spool and riser. A diverter waiver has been applied for. PU 4" DP as required and stand back in derrick. 3. MU 12 %" drilling assembly with MWD/GR and directionally drill surface hole to approximately 2742' MD I 2578' TVD. An intermediate wiperlbit trip to surface for a bit will be performed prior to exiting the Permafrost. The actual surf~ hole TD will be +1-100' TVD below the top of the SV1 sand. 4. Run and cement the 9-5/8", 40# surface casing back to surface. A Tam port collar may be run in the casing to allow for secondary cementing if hole conditions indicate that cement may not reach surface during primary cementing operations. / 5. ND diverter spool and NU casing I tubing head. NU BOPE and test to 4000 psi. ' 6. ' MU 8-3/4"drill~'assembly with MWD/GR/RES/DEN/NEU and RIH to float collar. Test the 9-5/8" casing to 3000 psi for 30 minutes. 7. Drill out shoe joints and displace well ~9.3 ppg LSND drilling fluid. Drill new formation to 20' below 9- 5/8" shoe and perform Leak Off Test. 8. Drill ahead and increase mu(j weight to 9.6 ppg prior to entering the Scþrader interval. 9. Drill to +1-100' above the HRZ, ensure mud is in condition to 10.3 ppg and perform short trip as needed. Ensure Pre-Reservoir meeting is held highlighting kick tolerance and detection prior to entering HRZ. 10. Drill ahead to -150' of rat hole into the Miluveach formation. Condition hole for running 7" 26# long- string. ./ 11. Run and cement the 7" production casing in a single stage. Displace the primary and secondary job job with 9.8 ppg filtered brine 12. Freeze protect the 7" x 9-5/8" annulus as required. Record formation breakdown pressure on Morning Report. / 13. Test the casing to 4000 psi. for 30 min. 14. Run USIT log to confirm cement integrity. / 15. Run the 4.,1/2", 12.6#,L-80 TC-II completion assembly. Set packer and test the tubing to 4000 psi and annulus to 4000 psi for 30 minutes on chart recorder. Shear RP valve and install TWC. Test below to 2700 psi. 16. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. Remove TWC. 17. Freeze protect the well by pumping diesel to the lowermost 4-1/2" GLM. Allow diesel to U-tube from the annulus to tubing. 18. Rig down and move off. L-105i Drilling Program (LSND) Page 5 L-105i Hazards and Contingencies Job 1: MIRU Hazards and Contingencies ).- L-Pad is not designated as an H2S site. Standard Operating Procedures for H2S precautions should be followed at all times. )0> The closest surface location is L-106,15 feet to the east. Surface shut-in will be required as this well is on production. If the well house is removed for rig access to L-105i, the SSSV on L-106 will need to be closed as well. ).- Check the landing ring height on L-105i. The BOP nipple up may need review for space out. ~ Based on pore pressure data and experienced gained on the first seven Borealis L-pad wells (and 2 previous L-pad Ivishak wells) the AOGCC has been asked for dispensation from the diverter / * requirement on the 12 %" surlace hole. -- "'- During the Surface Hole Planning Meeting and PJSM's the absence of a diverter on the '" surface hole on this well is to be discussed. Monitoring the hole, checking connections, \ importance of maintaining mud properties (including pre-treating with DrillTreat for Hydrates), focus on avoiding swabbing situations, importance of not loading up the hole (hole cleaning), evacuation drills, muster areas, etc. should be topics for discussion and action. The waiver has been justified based on extensive penetrations below "L" pad W:V'th no shallow gas problems and L-106 open hole surface logging. The absence of the ability to divert requires even greater diligence while drilling the surface hole. -........... / -- Reference RPs .:. IIDrilling/ Work over Close Proximity Surface and Subsurface Wells Procedure" Job 2: Drillina Surface Hole ).- There are two close approach issues in the surface hole. The closest existing well, L-106 is 15'/,' center-center at surface to -400' MD. L-104 43' offset at 400' MD. All wells pass major risk criteria. .ßyro survey tools will used while drilling the surface hole until clear of magnetic intereference. ' ).- Hydrates may be encountered near the base of permafrost to TD in the SV1 sand. Hydrates will be treated at surface with appropriate mud products and adjustment of drilling parameters. Refer to Baroid mud recommendation )0> Associated with the hydrates, is the danger of deeper gravel beds below the Permafrost that will tend to slough in when aerated gas cut hydrate mud is being circulated out. Maintain adequate viscosity. Reference RPs .:. "Prudhoe Bay Directional Guidelines" .:. IIWell Control Operations Station Bill" .:. IISuccessfully Drilling Surface Hole. (Attached) L-105i Drilling Program (LSND) Page 6 Job 3: Install Surface Casina Hazards and Contingencies ~ It is critical that cement is circulated to surface for well integrity. 2500/0 excess cement through the permafrost zone (and 30% excess below the permafrost) is planned. If hole conditions indicate that cement to surface may be an issue, a 9-5/8" port collar will be positioned at :t1 OOO'MD to allow secondary circulation. ~ "Annular Pumping Away" criteria for future permitting approval for annular injection. 1. Pipe reciprocation during cement displacement 2. Cement - Top of tail >500' TVD above shoe using 300/0 excess. 3. Casing Shoe Set approximately 100'TVD below SV-1 sand. Reference RPs .:. UCasing and Liner Running Procedure" .:. uSurface Casing and Cementing Guidelines~~ .:. uDowell Cement Program" .:. uSurface Casing Port Collar Procedure" Job 7: DrillinQ Production Hole Hazards and Contingencies ~\O? ~ 11 will cross a fault in the base of the Schrader at -4730' TVD (+/-100'). The estimated throw 0, e fault is approximately 100'. The well will be -420 when crossing the fault. Loss circulation is considered to be a risk. The second fault is at a depth of 6205' TVD (+/-100') near the base of the Colville. Loss circulation is considered to be a minimal risk. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures. ~ KICK TOLERANCE: The reservoir pressure of the Kuparuk is estimate to be 10.0 ppg,' Prior to spud the estimated formation pressure will be re*evaluated based on offset well data, In the worst case scencyto of 10.0 ppg pore pressure at the Kuparuk target depth, gaugeho!e, a fracture gradient of 13.2 ppg at the surface casing shoe, 10.3 ppg mud in the hole the kick tolerance is 25 bbls. LOT's of 13.5ppg (L-01), 15Appg (L-116), 15.6 ppg (L-114), 13.7ppg (L-l10) , 13.8ppg (L-107), 15.2 ppg (L 106), 13,2 ppg (L-115), 13.8 ppg (L-120) and 13.1 ppg on L-104 have been recorded in offset L-Pad wells. An accurate LOT will be required as well as heightened /' awareness for kick detection. Contact Drilling Superintendent if LOT is less than 13.2 ppg, ~ L-Pad development wells have had "kick tolerances" in the 35-45 bbl range. A heightened awareness of kick detection, pre-job planning and trip tank calibration will be essential while drilling/tripping the intermediate/production intervals. ~ There are no "close approach" issues with the production hole interval of L-105i. / ~ A LSND mud system will be used in the production interval. Experience suggests that the first wiper trip be made after approximately 1500' of new hole has been drilled. Flow rates should be maintained in the 575 gpm range particularily while drilling with higher ROP's (300'/hr) through the SV and Ugnu intervals. Note: Baroid will prepare hydraulic and hole cleaning models for these hole intervals prior to spud. Reference RPs .:. Standard Operating Procedure for Leak-off and Formation Integrity Tests L-105i Drilling Program (LSND) Page 7 ( .:. Prudhoe Bay Directional Guidelines .:. Lubricants for Torque and Drag Management. .:. uShale Drilling- Kingak & HrZ" - r-'.'''''''''''.~C''"'--,.''''''''n'.'...\''','.r:,'~-~' ~-.-r-""" .~~ Job 9: Case & Cement Production Hole Hazards and Contingencies >- The 7" casing will be cemented to 500' above the Kuparuk sands. if logs indicate that the ~ Schrader is oil bearing, an additional volume of cement will be pumped to cover the Schrader plus 500'. The top of the hydrocarbon interval will be verified with LWD resistivity log. >- If the Schrader has commercial oil, a 7" TAM port collar will be utilized in the production casing string. This will be positioned 400-500' below the Schrader formation to allow for a stage cement job utilizing 15.8 ppg G across the Schrader interval. The Kuparuk will be cemented in the first stage utilizing 15.8 ppg G from TO to 500' above the Kuparuk. >- Ensure the production cement has reached a compressive strength of 500 psi prior to freeze protecting. After freeze protecting the 7" x 9-5/8" casing outer annulus with 56 bbls of diesel (2000'), the hydrostatic pressure will be í 00 psi less than the Kuparuk formation pressure. Ensure a double-barrier at the surface on the annulus exists until the cement has set up for at least 12 hours. Trapped annulus pressure may be present after pumping the dead crude. The hydrostatic pressure of the mud and diesel will be 53 psi under-balance to the open hole (SV-1). (A second /' LOT will be required prior to displacing freeze protect. This to satisfy AOGCC for future annular pumping permits.) ~ A cement bond log (USIT) will be run to confirm cement quality and the TOC. This will be done ./ with the rig prior to perforating the well. >- Ensure a minimum hydrostatic equivalent of 10.0 ppg on the Kuparuk formation during pumping of cement pre flushes/chemical washes. Losses of hole integrity and packing off has resulted from a reduction in hydrostatic pressure while pumping spacers and flushes ,/ Reference RPs .:. Ulntermediate Casing and Cementing Guidelines" .:. uDowell Cement Program" Attached. .:. uFreeze Protecting an Outer Annulus" ,~,~,Y,o!fflo!ffl%o$,,>,,>,,,~ Job 12: Run Completion Hazards and Contingencies >- Watch hole fill closely and verify proper safety valves are on the rig floor while running this completion. The well will be underbalance if there is a casing integrity problem. Reference RPs .:. Completion Design and Running .:. Freeze Protection of Inner Annulus y'>>>>~>>Jo>>>Jo>>>m¡>>~"''<'"'hWhWh'''''''h>'"hW''' L-105i Drilling Program (LSND) Page 8 Job 13: ND/NU/Release RiQ Hazards and Contingencies ~ No hazards specific to this well have been identified for this phase of the well construction. Reference RPs .:. Freeze Protection of Inner Annulus Operational Specifics ../' . ND stack. NU tree and test to 250 and 5000 psi. with diesel. Test packott to 5000 psi. Pull TWC. . R/U hot oil truck and freeze protect well by reverse circulating diesel to the lowermost 4-1/2" GLM. Allow diesel to U-tube from annulus to tubing and equalize. Refer to RP: Freeze Protection of Inner Annulus. . Install BPV & test to 1000 psi from below. . Rig down and release the rig. ---.. L-105i Drilling Program (LSND) Page 9 L-105i Well Summary of Drillina Hazards POST THIS NOTICE IN THE DOGHOUSF ----- ? Surf e Hole Section: uring the Surface Hole Planning Meeting and PJSM's the absence of a diverter on the surface hole on this well is to be discussed. Monitoring the hole, checking connections, importance of maintaining mud properties (including pre-treating with DrillTreat for Hydrates), focus on avoiding swabbing situations, importance of not loading up the hole (hole cleaning), evacuation drills, muster areas, etc. should be topics for discussion and action. The waiver has been justified based on extensive penetrations below "L" pad with no shallow gas problems and L-106 open hole surface logging. The absence of the ability to di~rt requires ~r JlIlgence Wnl\drilling the surface hole. ~ . Gas hydrates may be encountered near the base of the Permafrost at 1876'MD and near the TD hole section as well. . Gravel beds below the Permafrost will tend to slough in when aerated (hydrate cut) mud is being circulated out. Ensure adequate mud viscosity is maintained to avoid stuck pipe situations. ~ Production Hole Section: . A majority of the L-Pad development wells will have "kick tolerances" in the 35-45 bbl. A heightened awareness of kick detection, pre-job planning and trip tank calibration will be essential while drilling/tripping the intermediate/production intervals. . The production section will be drilled with a recommended mud weight of 10.3 ppg to ensure shale stability in the HRZ shale and to cover the Kuparuk 10.0 pore pressure. . Tight hole, hole packing-off, and lost returns have been encountered in previous wells on this pad. Pipe sticking tendency is possible if the HRZ shale gives problems. Back reaming at connections and good hole cleaning practices will contribute to favorable hole conditions. . L-105i will cross a fault in the base of the Schrader at ....4730' TVD (+/-100'). The estimated throw of the fault is approximately 100'. Loss circulation is considered to be a risk. The second fault is at a depth of 6205' TVD (+/-100') near the base of the Colville. Loss circulation is considered to be a minimal risk. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures. HYDROGEN SULFIDE - H2S /" . This drill-site not designated as an H2S drill site. Recent wells test do not indicate the presence of H2S. As a precaution, Standard Operating Procedures for H2S precautions should be followed at all times. CONSULT THE L-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION Version 1.0 Rigsite Hazards and Contingencies L-105 Schlumbøpuøp Proposed Well Profile - Geodetic Report Report Date: February 14, 2002 Survey I DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 97.970° Field: Prudhoe Bay Unit - WOA (Drill Pads) nly Vertical Section Origin: N 0.000 ft, E 0.000 f1 Structure I Slot: L-Pad/L-105 feasibility study TVD Reference Datum: KB Well: L-105 TVD Reference Elevation: 78.8 ft relative to MSL Borehole: L -105 Sea Bed I Ground Level Elevation: 44.100 ft relative to MSL UWI/API#: 50029 Magnetic Declination: 26.070° Survey Name I Date: L -105 (P3) I February 14, 2002 Total Field Strength: 57472.427 nT Tort I AHD I DDII ERD ratio: 46.144° /4706.15 ft /5.432 10.66E Magnetic Dip: 80.763° .~ Grid Coordinate System: NAD27 Alaska State Planes, Zone 4, US Feel Declination Date: March 28, 2002 Location Lat/Long: N 70.35023990, W 149.32334852 Magnetic Declination Model: BGGM 2001 Location Grid N/E-YIX: N 5978139.020 ftUS, E 583342.980 ftUS North Reference: True North Grid Convergence Angle: +0.63725055° Total Corr Mag North -> True North: +26,070° Grid Scale Factor: 0.99990789 Local Coordinates Referenced To: Well Head Grid Coordinates Geographic Coordinates I Station ID MD Incl Azim TVD VSec N/.S I E/-W I DLS Northing Easting Latitude I Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) KBE 0.00 0.00 165.00 0.00 0.00 0.00 0.00 0.00 5978139.02 583342.98 N 70.35023990 W 149.32334852 KOP Bid 1/100 400.00 0.00 165.00 400.00 0.00 0.00 0.00 0.00 5978139.02 583342.98 N 70.35023990 W 149.32334852 500.00 1.00 165.00 499.99 0.34 -0.84 0.23 1.00 5978138.18 583343.22 N 70.35023761 W 149.32334666 600.00 2.00 165.00 599.96 1.36 -3.37 0.90 1.00 5978135.66 583343.92 N 70.35023069 W 149.32334122 700.00 3.00 165.00 699.86 3.06 -7.58 2.03 1.00 5978131.46 583345.09 N 70.35021919 W 149.32333205 Cry 1.5/100 800.00 4.00 165.00 799.68 5.45 -13.48 3.61 1.00 5978125.58 583346.74 N 70.35020308 W 149.32331922 900.00 5.04 151.09 899.37 9.44 -20.69 6.64 1.50 5978118.41 583349.85 N 70.35018338 W 149.32329462 1000.00 6.26 142.25 998.88 15.98 -28.85 12.10 1.50 5978110.31 583355.40 N 70.35016109 W 149.32325030 1100.00 7.59 136.39 1098.15 25.06 -37.94 19.99 1.50 5978101.31 583363.39 N 70.35013625 W 149.32318625 1200.00 8.97 132.29 1197.11 36.66 -47.96 30.31 1.50 5978091.40 583373.82 N 70.35010888 W 149.32310247 Cry 2/100 1273.35 10.00 130.00 1269.46 46.78 -55.90 39.41 1.50 5978083.57 583383.01 N 70.35008719 W 149.32302860 1300.00 10.27 127.40 1295.69 50.82 -58.83 43.07 2.00 5978080.68 583386.70 N 70.35007918 W 149.32299889 1400.00 11.46 118.86 1393.90 67.87 -69.05 58.86 2.00 5978070.64 583402.60 N 70.35005126 W 149.32287071 1500.00 12.86 112.02 1491.66 87.95 -78.02 77.88 2.00 5978061.88 583421.72 N 70.35002676 W 149.32271631 SV5 1553.57 13.66 108.95 1543.80 99.94 -82.30 89.39 2.00 5978057.73 583433.27 N 70.35001506 W 149.32262287 1600.00 14.39 106.56 1588.85 111.03 -85.73 100.11 2.00 5978054.42 583444.03 N 70.35000569 W 149.32253585 1700.00 16.02 102.16 1685.35 137.08 -92.18 125.51 2.00 5978048.25 583469.50 N 70.34998807 W 149.32232966 SV4 1703.59 16.08 102.01 1688.80 138.07 -92.38 126.48 2.00 5978048.06 583470.47 N 70.34998752 W 149.32232178 1800.00 17.73 98.56 1781.04 166.07 -97.35 154.06 2.00 5978043.40 583498.10 N 70.34997395 W 149.32209790 L-105 (P3) report. xis Page 1 of2 2/14/2002-1 :45 PM Grid Coordinates Geographic Coordinates I Station ID MD Incl Azim TVD VSec N/.S E/.W I DLS Northing Easting Latitude I Longitude (ft) (O) (O) (ft) (ft) (ft) (ft) (o/100ft) (ftUS) (ftUS) End Cry 1849.69 18.60 97.02 1828.25 181.56 -99.45 169.41 2.00 5978041.47 583513.47 N 70.34996821 W 149.32197329 Base Permafrost 1876.65 18.60 97.02 1853.80 190.16 -100.50 177.94 0.00 5978040.51 583522.01 N 70.34996534 W 149.32190404 Bid 2/100 1903.02 18.60 97.02 1878.80 198.57 -101.53 186.29 0.00 5978039.58 583530.37 N 70.34996252 W 149.32183626 2000.00 20.54 97.02 1970.17 231.05 -105.49 218.53 2.00 5978035.98 583562.65 N 70.34995170 W 149.32157454 Bid 4/100 2003.02 20.60 97.02 1973.00 232.11 -105.62 219.59 2.00 5978035.86 583563.71 N 70.34995135 W 149.32156594 8V3 2063.13 23.00 97.02 2028.80 254.43 -108.35 241.74 4.00 5978033.38 583585.89 N 70.34994389 W 149.32138613 2100.00 24.48 97.02 2062.55 269.27 -110.17 256.4 7 4.00 5978031.72 583600.64 N 70.34993892 W 149.32126656 2200.00 28.48 97.02 2152.04 313.84 -115.61 300.72 4.00 5978026.77 583644.94 N 70.34992405 W 149.32090735 8V2 2253.75 30.63 97.02 2198.80 340.35 -118.85 327.03 4.00 5978023.83 583671.28 N 70.34991519 W 149.32069377 ..-... 2300.00 32.48 97.02 2238.21 364.55 -121.81 351.05 4.00 5978021.13 583695.33 N 70.34990711 W 149.32049878 2400.00 36.48 97.02 2320.62 421.14 -128.73 407.22 4.00 5978014.84 583751.57 N 70.34988819 W 149.32004281 2500.00 40.48 97.02 2398.89 483.34 -136.33 468.97 4.00 5978007.93 583813.39 N 70.34986742 W 149.31954154 End Bid 2540.96 42.12 97.02 2429.66 510.37 -139.63 495.80 4.00 5978004.93 583840.26 N 70.34985840 W 149.31932374 SV1 2661.13 42.12 97.02 2518.80 590.95 -149.48 575.78 0.00 5977995.97 583920.33 N 70.34983148 W 149.31867449 9-5/8" Csg pt 2742.01 42.12 97.02 2578.80 645.19 -156.11 629.62 0.00 5977989.94 583974.24 N 70.34981335 W 149.31823744 UG4A 3173.41 42.12 97.02 2898.80 934.47 -191.47 916.77 0.00 5977957.78 584261.74 N 70.34971667 W 149.31590646 UG3 3672.22 42.12 97.02 3268.80 1268.94 -232.34 1248.79 0.00 5977920.60 584594.16 N 70.34960489 W 149.31321128 UG1 4312.58 42.12 97.02 3743.80 1698.34 -284.82 1675.03 0.00 5977872.87 585020.92 N 70.34946129 W 149.30975131 Ma 4737.23 42.12 97.02 4058.80 1983.10 -319.63 1957.69 0.00 5977841.21 585303.92 N 70.34936600 W 149.30745687 W82 5074.26 42.12 97.02 4308.80 2209.10 -347.25 2182.03 0.00 5977816.09 585528.53 N 70.34929038 W 149.30563584 W81 5269.74 42.12 97.02 4453.80 2340.18 -363.27 2312.14 0.00 5977801.52 585658.80 N 70.34924651 W 149.30457971 Obf Base 5802.25 42.12 97.02 4848.80 2697.25 -406.91 2666.59 0.00 5977761.83 586013.68 N 70.34912697 W 149.30170259 CM2 6260.61 42.12 97.02 5188.80 3004.61 -444.4 7 2971.69 0.00 5977727.67 586319.15 N 70.34902404 W 149.29922607 CM1 7116.67 42.12 97.02 5823.80 3578.65 -514.63 3541.50 0.00 5977663.85 586889.65 N 70.34883169 W 149.29460095 Top H RZ 7770.51 42.12 97.02 6308.80 4017.09 -568.21 3976.71 0.00 5977615.12 587325.39 N 70.34868472 W 149.29106844 ~, Base HRZ 7972.72 42.12 97.02 6458.80 4152.69 -584.78 4111.31 0.00 5977600.05 587460.15 N 70.34863926 W 149.28997593 K-1 8009.12 42.12 97.02 6485.80 4177.09 -587.77 4135.54 0.00 5977597.33 587484.41 N 70.34863105 W 149.28977926 Top Kuparuk / C 8107.52 42.12 97.02 6558.79 4243.08 -595.83 4201.04 0.00 5977590.00 587549.99 N 70.34860893 W 149.28924761 Target 8107.54 42.12 97.02 6558.80 4243.09 -595.83 4201.05 0.00 5977590.00 587550.00 N 70.34860893 W 149.28924753 Top Miluveach 8606.36 42.12 97.02 6928.81 4577.57 -636.71 4533.07 0.00 5977552.82 587882.42 N 70.34849672 W 149.28655265 TD / 7" Csg pt 8756.34 42.12 97.02 7040.07 4678.15 -649.00 4632.91 0.00 5977541.64 587982.38 N 70.34846298 W 149.28574229 Leaal Description: Northina (V) rftUSl Eastina (X) rftUSl Surface: 2415 FSL 3573 FEL S34 T12N R11E UM 5978139.02 583342.98 Target: 1818 F8L 4653 FEL 835 T12N R11E UM 5977590.00 587550.00 BHL: 1765 FSL 4222 FEL 835 T12N R11E UM 5977541.64 587982.38 L-105 (P3) report.xls Page 2 of 2 2/14/2002-1 :45 PM ( p . , ~.. ..~ i: .J .ø~,~~ VERTICAL SECTION VIEW Client: Well: Field: BP Exploration Alaska L-105 (P3) Structure: Prudhoe Bay Unit - WOA L-Pad Schlumberger Section At: 97.97 deg Date: February 14, 2002 0 -....,...6uu ............¡.._.... 0 KOP Bid 1/1Ò0400 MD 400 TVD 0.00' 165.0~' 02 0 departure 0 Crv 1.51100 aOO MD 800 TVD 4.00' 165,0~' az 5 departure 2000 -e-: i Crv 2/100 1?73 MD 1269 TVD 10.00' 139,00' az 47 departure End qrv 1850 MD 1828 TVD 18.60: 97,02'02 182departure -I - - - - ,,7'; f04iJ(J 044TvD- - - - -1- - - - - - Bid 2/1001903 MD 1879 TVD ¡ ! ! ~~~';~i'f~':~:~~~];~~:;;;'-=-£= - ~ ;:;~~:-.~~~,; ~. ~ ':,'::j :'~:~ ~ ~ ~ T ~ ~ ~ ~ ~ 9-5/8" Csg PI2742 MD 2579 TVD SV 1 260 1 ,VI!, "u,L, '" [; ! 42.12' 97,02' az 645 departure' ! I i ... , ::;C;/,Ä,u:;¡Ÿ'+r;u209i;';;Ó U I U I i U Iu ';;:;¡ï;Ú/r,u3Úïi-VDu I ~o~~n!JI~4~112° ~ ~ ~I~ ~ ~ ~ ~ ~ I ! ...--...L.--.--.-.....---......-.........---........_.l___...... , I , I I ........--.-.-----......---.- 1 000 _um,! ,..,...uu...u.u".,-_u,.u.uu__..,....,umu,.,-'_m-m__u..,u.._..--.---..---,....-----...,-..-------.,-..,.., - ..... Q) - ~~ g~ 0 Q) 3000-+ T""" > II ~ . £: C'O T"""q: _0 ..c~ --------- ~ ~ ¡':G~ 4:~L~.:',,1D 3"144 T\!D ~ ~ 4000 "u'Ut'¡¡;:;(3T,:öu,;çi:'0TVD CtS .. ' .2 1i5 ! WS2 ~o:: > > Q)~ :JW "- I- , i -! - -n - - - - -! .- ¡ I I I "jr¿;p¡oìR¿" 777"¡ ~, ..u_. _..- ..... .-- Ð30~ 7\/0 ¡ ; i I í I I um um, ...., uu.. mu ,... I u- I I ulu J ...m i u.. ,..m uu, ..... ...u u... ¡ um .~=f<-ij;02[M[:t~<ç0 TlÞ¡ = I I i I - - - - - -!- i '"'j''''.''' I I 2000 ¡ ,..i, i -I' i ¡ ¡ ...i- ...Iu.. ! -..I - i ...! . u-! ..... I "I- I ! ! .. ¡... I ,....I.. ".,,1 n ¡ I I ..I.. i ""I'" T' i I I ~ ~ ~ ~I~ ~ ~:~~,~,~:" ~ I...:;¡::':'''~ ~ ~ ~ ~_:~~::_:~=- ¡~~~:D I 4000 ''''1 V.j~f'1 ~'f;¿-"N": ;\.10 :¡-.t;64 "'(\t6"" ..... ...., ...., ...., ...., pbf 8~S0 SB02 MD 5000 -.., pn ¡,jÖ -~ -, ~,-- .~" .,... pM1 'r~'rl MD .~.- ~ ..- .-, ",- ~-~. -- .._~ 6000 _.... I 0 I 1000 I ,..., --I - mu ..,.. ..:::i :-... ...- um '..u 'Uu' ..... -I ,.m 1 ----_J- .....m'I''''' ! I 3000 ::¡ ø~€ ¡-.H'.{1.: f;~Yr3:MD :t:':.-ì;5f.Ff-V¡/::: , , . ---- _. .-. -. ".-'" -. ---- - ¡ r op ¡<upm;j;-~ ; G 81 G8 MD 8~;5D '~VD 7000 ...:.... , , , , , , , , ~ - - - - - - -. ~ ...¡J:~;:¡?,M.~:,~J~Æi~,~:j:...rlG9JLM.~?,..,~~j~.~;J..:¡:Y.j:?,.....".. Vertical Section Departure at97.97 deg from (0.0, 0.0). (1 in = 1000 feet) PLAN VIEW Client: Well: Field: BP Exploration Alaska L-I05 (P3) Prudhoe Bay Unit - WOA Schlumbøruør -1000 2000 . 5000 I 6000 I 'f" I . t. .. ~- nth Structure: Scale: L-Pad 1 in = 1000 ft 14-Feb-2002 4000 , 0 1000 , . I i 2000 ---~-~--~---t~--~-----f--<~-~--~-_w_~~------~c-~--f-----------t---------, True North ^ ^ ^ I I- a: 0 z 1000 - o-~, I I- ::> 0 (f) V V V -1000--, -2000 -- Date: 3000 , Bid 2I1Jo Bid 41100 I 1903 ~9 18~9 TVD ~~~:0~D97.~~~3a:vr 18.60 197,02 az 106 S 220 E I 9-5/S" Csg PI ~i~;;~jí~~;.::~~ ~.::~:': II ~. i Cry 21100 i \ i ~~~~0~~3~~0~::D E~d Cry End Bid I 56 S 39 E 1~50 MD 1828 TVD 2541 MD 2t30 TVD 1~,60' 97.02' az 42,12' 97,0~' az 9~ S 169 E 140 S 496 i¥ i ....t.... HOld Az' i Ifnuth 97.02° ....{..... T ¡ .....:..... 'n ton. I .....¡..... -1000 ¡ í I 0 I I I I I I 1000 2000 3000 4000 5000 6000 «< WEST EAST »> ,) - 2000 Tot Carr ( E 26.07° ) Mag Dee ( E 26.07° ) - 1000 -t.. -0 ----.,~; I ;:L~V .. ~:::=J 8108 MD 6550/ TVD 8756 MD 7040 TVD 42.12' 97.02"¡az 42,12' 97.02r az 596 S 4201 E¡ 649 S 4633 ~ ~+, - -1000 ~, .....:..... ....,¡..... ...¡.. - -2000 Company: Field: Reference Site: Reference Well: Reference Wëllpath: BP Arnoco Prudhoe Bay PB L Pad L~105 Plan L-105 Schlumberger Anticollision Report NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 50.00 ft Depth Range: 28.50 to 8756.34 ft Maximum Radius: 2000.00 ft Survey Program for Definitive Wellpath Date: 12/21/2000 Validated: No Planned From To Survey ft ft 28.50 500.00 500.00 8756.34 Casing Points Summary TVD ft 2578.80 7039.87 Planned: Plan #3 V1 Planned: Plan #3 V1 Diameter in 9.625 7.625 Date: 2114/2002 Time: 13:08:50 Page: Co-ordinate(NE) Reference: Vertical (TVD) Reference: Well: L-105, True North L-:105 plan 78.8 Reference: Error Model: Scan Method: Error Surface: Db: Sybase Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Version: Toolcode 6 Tool Name CB-GYRO-SS MWD+IFR+MS Camera based gyro single shots MWD + IFR + Multi Station 12.250 8.750 ~';Offs~tWënpath~~~~~~-:.....;.~ Wën . Wëllpatli EX NWE#1 EX NWE#1 EX NWE#1 PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad NWE1-01 NWE1-01 NWE 1-02 L-01 L-102 L-104 L-106 L-110 L-111 L-114 L-115 L-116 L-117 L-120 95/8" 7 5/8" Rderëncë Offset Ctr;.Ctr' Nó;'Go. Allowablë MD MD DiStance '.,Mea Dëviation Warning ft ft ft ft ft 299.99 300.00 432.49 6.40 426.09 Pass: Major Risk 299.99 300.00 432.49 6.40 426.09 Pass: Major Risk 919.65 950.00 356.78 16.42 340.36 Pass: Major Risk 849.38 850.00 88.41 13.84 74.57 Pass: Major Risk 399.99 400.00 75.78 10.02 65.76 Pass: Major Risk 399.99 400.00 43.42 7.98 35.45 Pass: Major Risk 399.93 400.00 14.42 7.82 6.62 Pass: Major Risk 499.92 500.00 206.30 10.13 196.17 Pass: Major Risk 350.00 350.00 310.79 7.54 303.26 Pass: Major Risk 798.36 800.00 279.73 12.83 266.93 Pass: Major Risk 739.43 750.00 252.22 12.61 239.63 Pass: Major Risk 797.83 800.00 177 .33 12.87 164.53 Pass: Major Risk 448.44 450.00 252.93 8.42 244.51 Pass: Major Risk 299.98 300.00 197.27 6.34 190.94 Pass: Major Risk NWE1-01 V3 NWE1-01A VO NWE1-02 V2 L-01 V14 Plan L-102 V5 Plan: PI L-104 V7 L-106 V14 L-110V11 Plan L-111 V19 Plan: P L-114 V14 L-115V7 L-116V10 L-117 V11 L-120 V8 Polygon 1 2 3 4 Site: PB L Pad .l Drilling Target Conf.: 99o/~. Centre Location: Map Northing: 5977590.00 ft Map Easting : 587550.00 ft Latitude: 70020'54.992N +N/-S ft 404.44 395.58 -404.44 -395.58 Target: L-I05 Tgt +E/-W ft -395.58 404.44 395.58 -404.44 . "7ell: L-105 ( sed on: Planned Program vertical Depth: 6480.00 ft below Mean Sea Level Local +N/-S: -595.64 ft Local +E/-W: 4201.07 ft Longitude: 149°17'21.291 W Northing ft 5977990.00 5977990.00 5977190.00 5977190.00 Easting ft 587150.00 587950.00 587950.00 587150.00 0 -200 -4-00 -500 -800 -1000 -1200 0 0 0 0 0 CJ CJ 0 CJ CJ 0 CJ CJ CJ CD CJ N .J- LO CD CJ (I) .J- .J- .J- .J- -=t- Ln ~ % -( -, Borealis L-105i: Proposed Completion . TREE: 4-1/16" - 5M CIW Carbon WELLHEAD: 11" - 5M FMC G5 Cellar Elevation = :t47' RKB-MSL = ~77' I . 4-1/2" 'X' Landing Nipple with 3.813" seal bore. I 2200' I 9-5/8",40 #/ft, L-80, BTC j ~ 2742' 4-1/2" x 1" Gas Lift Mandrels with handling pups installed. GAS LIFT MANDRELS MD Size # 1 2 Valve Type TBD TBD 4-1/2" KBG-2 4-1/2" KBG-2 RP DV L ~ 4-112" 12.6# L-80, TC-II Tubing ,/ L 1r 4-1/2" 'X' Landing Nipple with 3.813" seal bore. 7" x 4-1/2" Baker 'Premium' Packer +/-200' above Kuparuk 4-1/2" 'X' Landing Nipple with 3.813" seal bore. 4-1/2" 'X' Landing Nipple with 3.813" seal bore. 4-1/2" WireLine Entry Guide set at +/-130' above the Kuparuk Formation Plug Back Depth I 7", 26 #/ft, L-80, BTC-Mod ~. I 8674' ..;~ 87561 Date 2-14-02 Rev By NM Comments Borealis /'/ WELL: L-105i API NO: 50-029-????? Proposed Completion (P3) BP Alaska - .,. bp ,\1'.'". -...,~ ~...- ~..- ~..-- *.~ ~...... .'jk~'\. ". ./ To: Tom MaunderIWinton Aubert, AOGCC Date: February 19, 2002 From: Neil Magee Subject: Dispensation for 20 AAC 25.035 (c) on L-I05i ,/ BP Alaska Drilling and Wells requests your consideration of a waiver of the diverter system identified in 20 AAC 25.035 (c) "Secondary Well Control for Primary Drilling and Completion: Blowout Prevention Equipment and Diverter Requirements". Experience and data gathered, summarized herein, support the rationale for the request. To date, none of the 10 BorealislIvishak wells at L-pad, nor the two NWE wells 1-01 and 1-02 drilled in 1998 experienced pressure control or shallow gas problems above the surface casing depth, apart from minor and inconsequential hydrate shows. All six of the / surface holes for the Borealis Development (L-116, L-II0, L-114, L-115, L-I06, L-I04, L-120 and L-I07) and the first Ivishak well (L-O 1) were drilled to the shale underlying the SV -1 sands. The shale underlying the SVl is the deepest planned surface casing setting depth for future pad development wells. This casing point' is:t300' TVD above the U gnu horizon. RFT's from NWE 1-02 recorded pore pressures of 1,275 psi at 2782' TVDss (8.8 ppg EMW) and 1387 psi at 3059' TVDss (8.7 ppg EMW) in the Ugnu. L-I05i is planned to reach a 9.5 ppg mud weight before TD at 2,676' TVDss. This request is being made based on L-Pad data submitted regarding mud weight, gas monitoring, recent open hole surface logging of L-I06 (PEX/Dipole sonic) and the meeting between Jack Hartz, Robert Crandall, Steve Davies, Bob Dawson (BP), Ray Eastwood (BP) and Kip Cerveny (BP). Your consideration of the waiver is appreciated. Sincerely, Neil Magee BP Drilling Engineer 564-5119 8 0 Borealis Suñace Hole Mud Weight MW (ppg) 9 8.5 9.5 10 ~ . I v' 500 1000 .-. .c ~ 1500 I c > I- ......... i 2000 I cu c 2500 . 3000 3500 . L-01 . L-116 ):( Pore Pressure . L-107 - --. L-104 L-120 ¿ L-110<Zs.~.'\ . L-114 ¥,~-<\.~.<;S . L-106 ~~..,.) ¡ L-115 ~'<O - ~,<ø Borealis Mud Plots 2/4/02 Further L Pad Operations ( (' Subject: Further L Pad Operations Date: Tue, 02 Apr 2002 12:59:30 -0900 From: Tom Maunder <tom - maunder@admin.state.ak.us> To: Robert Odenthal <OdenthRS@BP.com>, Lowell Crane <cranelr@bp.com> CC: Jody J Colombie <jody - colombie@admin.state.ak.us>, Cammy Oechsli <Cammy - Oechsli@admin.state.ak.us>, Daniel T Seamount JR <dan - seamount@admin.state.ak.us>, Bob Crandall <bob - crandall@admin.state.ak.us>, Steve Davies <steve_davies@admin.state.ak.us>, Winton G Aubert <winton - aubert@admin.state.ak.us> Robert and Lowell, The rig is presently drilling on L-119i and I understand that it will then move to V pad to do three wells (V-IOI--PTD 202-056, V-I06--to be permitted and V-I02--202-033). This schedule change has been done to relieve some of the concerns with the simultaneous operations on L pad. When the rig returns to L pad, present plans are to drill L-I09i and then maybe L-I05i. I talked with Robert last week and indicated we would like to have updated information regarding the most recently drilled surface hole. You have previously provided a mud weight plot and some comments on any gas or absence thereof. On receipt of that information, we will then issue the next permit. Please call with any questions. Tom Maunder, PE AOGCC L._-~------"~-------~-"--,----,--~----~--,~,_._----,-' Tom Maunder <tom maunder@admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 1 of 1 4/5/02 1:03 PM ~, ~ ( .. ~ Prudhoe Bay Unit L-Pad Diverter Waiver Notes to File March 22, 2002 The intent of a diverter system on a drill rig is to allow an uncontrolled well flow to be directed away from the rig floor, thereby enhancing the safety of a drilling crew by pennitting them additional escape time. Regulation 20 AAC 25.035 (c) provides specific requirements for a diverter system. Regulation 20 AAC 25.035 (h) pennits the Commission to waive diverter requirements in certain circumstances. Variances may be granted if the operator provides an equally effective means of diverting flow away from the drill rig, or if drilling experience in the near vicinity indicates that a diverter system is not necessary. BP is currently seeking a variance from diverter requirements for further drilling on the Prudhoe Bay Unit L-Pad. Their argument is that a diverter should not be required based on past drilling experience on L- Pad. To date, 13 wells have been drilled from the pad without incident, which argues in favor of a diverter waiver. However, a confidential map provided by Robert Hunter ofBP (dated Oct. 15, 2001) shows that L-Pad is situated near the middle of a world-class gas hydrate accumulation, and within an area interpreted by BP to contain free gas associated with the hydrate deposits. Hunter's infonnation augments USGS and drilling experience that the immediate area is known to contain, hydrates. The Commission's principle concern at L-Pad is free-gas possibly associated with the gas hydrate deposits. In fact, wireline logs from well L-I06 indicate approximately 25' of free gas reservoir at the base of a thick gas hydrate zone. Free gas may constitute a drilling hazard when improper operating practices allow such gas to flow into the well bore. At present, the area and vertical distribution of this free-gas beneath the hydrate zone and its occurrence within the hydrate zone is poorly understood by the Commission and by industry. Gas hydrates are the topic of current research by the USGS and at least two industry teams: one headed by BP, and another involving Anadarko. BPhas designed and constructed L-Pad as a small;..footprint operation with closely spaced wells and tightly packed equipment. Many of the facilities and flow lines are currently in place. In its present configuration, use of a standard diverter line is not possible. In many places on the pad, a diverter of required length and configuration (75', as straight as possible) simply will not fit between the rig and the piping/facilities already in place. Where it will fit, the diverter will point toward the centerline of the pad, and it will be aimed directly at existing or planned piping and/or facilities. There are no other rigs available today on the North Slope that will pennit the diverter line to be aimed in any other, less hazardous direction. If the Commission were to require a diverter line, it must be lifted over, threaded through, and built around existing, active, above-ground piping, greatly increasing the potential of construction-related accident arid spill. Modification of the diverter line to include curves or targeted- T intersections could impair its effectiveness and would likely not ease its construction. II} In such a drilling situation where shallow-hazard uncertainty exists, the Commission would normally require a diverter. However, because of the design and existing infrastructure on L- Pad, the Commission is now forced to choose the lesser of two evils. While the hydrates and potentially associated free-gas are still sources of uncertainty, drilling standards and practices have been developed and implemented that have allowed BP to drill 13 wells from L-Pad without incident. Although the existence of hydrates in the intended drilling path is known and successful mitigation strategies have been employed in the drilling plans, there is still some potential for a drilling accident caused by free gas associated with the hydrates. The probability of that occurrence is very low. In contrast, a construction-related accident or spill caused by placement and assembly of the diverter line near existing infrastructure is considered by the Commission to be a greater risk. Therefore, a diverter waiver should be granted. To offset the lack of a diverter system, and to increase the safety of the drilling crew, the Commission should require a high-resolution system capable of quickly detecting any influx of gas or fluid into the mud system on all future wells drilled from Prudhoe Bay Unit L-Pad. In addition, a full suite of well logs should be required from surface to total depth on the well that reaches furthest from L-106 (which currently has a complete suite of well logs). The purpose of this additional logging is to provide the Commission with more data that will increase our confidence that no significant zones of free gas or other shallow drilling hazards exist above 2580 feet TVD in the L- Pad area. ,-~~', "3--:2Z.0l..-- L.,.J06 Surtà.c.e Hole Log/Free Gas ( Subject: L-I06 Surface Hole Log/Free Gas Date: Thu, 21 Mar 2002 19:13:34 -0600 From: "Crane, Lowell R" <CraneLR@BP.com> To: "Winton Aubert (E-mail)..<winton_aubert@admin.state.ak.us> CC: "Cerveny, Phillip F" <CervenPF@BP.com>, "Tom Maunder (E-mail)..<tom_maunder@admin.state.ak.us>. "Paskvan, Frank A" <PaskvaFA@BP.com>, "Odenthal, Robert S" <OdenthRS@BP.com>, "Magee, D Neil" <MageeDN@BP.com> Winton, Attached is Kip Cerveny's statement concerning interpretation of the L-I06 surface hole logs and the presence of free gas. I will add that well behavior during drilling and cementing operations in this hole section on all L Pad wells to date are consistent with Kip's conclusion concerning the presence of free gas. If additional information is required, please call. Plans currently call for the rig moving to L-119i on Monday or Tuesday of next week. Thanks, Lowell . " < Name: stategasletter.doc , : Dstategasletter.doc: T)'pe: WINWORD File (application/msword) Encoding: base64 LA-M,- ~lt l VJ. I, ¡¿ ,') r \.) r (;. l í) d ' ~ / ". , ' \ I i'", ~'Y'~..( ~{, t (LE ~ {f r" . I J . ~-f~''''~' ! ., ~ \1.., .~.,: ~~_. 1 of 1 ,- 0..,:..- tþ ^' 3/22/2002 6:08 AM (' ( Upon thorough examination of the open hole log data from the L-1 06 well, it is my professional opinion that there is no free gas in the interval between the base of permafrost and the surface casing point just below the SV -1 sand at -2570 ft TVDSS. Gas hydrates, however, are prevalent throughout this interval. This is confirmed by the NW Eileen #2 well, located approximately 1.5 miles to the northwest, which also shows the presence of gas hydrates within the same interval, but does not show evidence of free gas. Sincerely, Philip F. Cerveny Senior Geologist BP Exploration Alaska State of Alaska Certified Geologist #488 f ( TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LEITERlPARAGRAPHS TO BE INCLUDED IN TRANSMUTTALLETTER WELL NAME f>A 4 L- /ðS-/ ~ CHECK 1 STANDARD LETTER DEVELOPMENT DEVELOPMENT REDRlLL EXPLORATION INJECTION WELL v INJECTION WELL REDRlLL CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) ANNULAJ}. D~POSAL (..k:::)NO ANNULAR DISPOSAL L-J YES ANNULAR DISPOSAL THIS WELL "CLUE" The permit is for a new wellbore segment of existing weD ~ Permit No, ,API No. ., Production should continue to be reported as a function of the original API number stated above. . In accordance with 20 AAC 25.005(1), all records, data and logs acquired for. the pUothole must be clearly differentiated in both name (name, on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (na.me on permit). , Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated. '. . ANNULUS L-J YES + SPACING EXCEPTION ¡J ívl::r~~ ~A.. I\V~ ,. Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill tbe above referenced well. The permit is approved .sùbject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuan'ce of a conservation order approving a spacing exception. {Company Name) will assume the liability of any protest to the spacing exception that may occur. H 204444 DATE 01/17/02 CHEeK NO. 00204444 DATE INVOICE / eREDIT MEMO DESCRIPTION GROSS 100.00 VENDOR DISCOUNT ALASKAOILA NET 100.00 00 011602 CKOli602K PYMT COMMENTS: HANDLING INST: Permit to Drill Fee StH - Terrie HubJle X4628 RECEIVED L -\OS ; FEB 2 0 2002 Alaska Oil & Gas :005. Commission Ancrorage THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ 100.00 100.00 BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 FIRST NATIONAL BANK OF ASHLAND ANAFFJUATE OF NATIONAL CITY BANK CLEVELAND. OHIO No.H 2044 44 CONSOLIDATED COMMERCIAL ACCOUNT 56-389 412 00204444 PAY \. ONE HUISIDRED 8< 00/100************************************* US DOLLAR ALASKA OILAISiDGAS CDNSERVêTIQNCOMMISSION 333 <WEST ,7TH AVENUE ' SUITE 100 ANCHORAGE DATE /17/02 AMOUNT $100,,00 Tn The ORDER Of NOTNALlD AFTER 120 DAYS AK Ç¿iJJ~~t(~ III 2 0 ... a. ... ... III I: 0... ~ 2 0 j 8 c¡ 5 I: 0 0 8 a.... ~ c¡ III WELL PERMIT CHECKLIST COMPANY /3/J ~ WELL NAME f/~ 4' /-. - /1")<. ç"" FIELD & POOL 15" 7'6/J0 INIT CLASS I-GV/;'~T ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . 3. Unique well name and number. .. . . . . . . . . . . . . . . . 4. Wellloeated in a defined pool.. . . . . . . . . . . . . . . . . 5. Wellloeated proper distance from drilling unit boundary. . . . 6. Well located proper distance from other wells.. . . . . . . . . 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . 9. Operator only affected party.. . . . . . . . . . . . . . . . . . 10. Operator has appropriate bond in force.. . . . . . . . . . . . 11. Permit can be issued without conservation order. . . . . . . . Ajj;>R ,=,O.t.T~ 12. Permit can be issued without administrative approval.. . . . . 4'L./ <{'7/c>~ 13. Can permit be approved before 15-day wait.. . . . . . . . . . ENGINEERING 14. Conductor string provided. . . . . . . . . . . . . . . . . . . 15. Surface casing protects all known USDWs. . . . . . . . . . . 16. CMT vol adequate to circulate on conductor & surf csg. . . . . 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . 18. CMT will eover all known productive horizons. . . . . . . . . . 19. Casing designs adequate for C, T, B & permafrost. . . . . . . 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . 21. If a re-drill, has a 10-403 for abandonment been approved. . . 22. Adequate wellbore separation proposed.. . . . . . . . . . . . 23. If diverter required, does it meet regulations. . .. . . . . . . 24. Drilling fluid program schematic & equip list adequate. . . . . 25. BOPEs, do they meet regulation. . . . .¡j . . . . . . . . . . 26. BOPE press rating appropriate; test to '000 psig. 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . 28. Work will occur without operation shutdown. . . . . . . . . . . 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . 30. Permit can be issued w/o hydrogen sulfide measures. . . . . 31. Data presented on potential overpressure zones. . . . . . . 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . AP-PR ...P~ TJZ 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . M". ,,?,T ð7 - 34. Contact name/phone for weekly progress reports [exploratory ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. .. to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular: COMMISSION: RP~ TEM ~ COT SFD- WGA liJ6~ DTS03/27/0 2... JMH ~P'f~ DAT{E ~ j/U '0'1- lit ""^- "'(:Io-ad GEOLOGY APPR DATE G:\geology\templates\checklist.doc PROGRAM: Exp - Dev - Redrll - Serv XWellbore seg - Ann. disposal para req - GEOL AREA 'f'7ð UNIT# 1/ b C ~ ON/OFF SHORE oJ'iJ ~iN /- /--. ¡;- .. .... 4. (J¿ c..- / G> _I ) / ~ c,., / VI r:- ð2 ~ /e/ dr;'JIe~ ~ ~ ({dV¡'O/r--Ä< CÁ~f N N N (!) N f ~ N <i.t @ 1/0 T\Í!) . @ ~ 41"....1< fUCRS ~ Ct.M L Y@ It ~ ~,Ja-b o. s C{ GS ~êJ~¡¿d ~/twd- " IS-'@ ¥po' 1ÆD, ~\tth. h'a.,,:J * Y N D ì \{ ~te-; fl.jcvi \(fl.-,/ v<e.6 £us. teÄ ' "\ ~,~ iý) N J./t S P .:: Z ë '25 p~. ¡.If ~S CscJ t-s t:: l/CJoo f ~'. ~~ Y@ Y N Y N /~tI ¿jp// ;/;?/ C4/Î ,ç"""~J~ 3S //¿A.) /? /)rÇ ..r4¡. ;,/.dr~ .y~.I~ '7 £. ~ ) ) ~ ~ No GM..~U("" J..¿~~><J V""t'iOSfeJ . w~~~r Comments/Instructions: