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Home My WebLink About206-172MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, February 10, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC S-33A MILNE PT UNIT S-33A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 02/10/2025 S-33A 50-029-23123-01-00 206-172-0 W SPT 4084 2061720 1500 818 822 821 819 269 410 408 404 4YRTST P Adam Earl 1/5/2025 MIT-IA Dual String injector. Tubing Gauge on Long String 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:MILNE PT UNIT S-33A Inspection Date: Tubing OA Packer Depth 447 1798 1736 1722IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE250107080344 BBL Pumped:0.8 BBL Returned:0.8 Monday, February 10, 2025 Page 1 of 1 9 9 9 9 999 99 99 99 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.02.10 14:35:47 -09'00' From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Operable: MPS-33A (PTD# 2061720) Return to Injection Date:Tuesday, November 12, 2024 4:50:56 PM From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Tuesday, November 12, 2024 4:03 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com> Subject: Operable: MPS-33A (PTD# 2061720) Return to Injection Mr. Wallace, PWI well MPS-33A (PTD# 2061720) was made Not Operable in April of 2023 as the well was presumed to be offline for its 4 year MIT-IA. We will be bringing this well back on injection. The well will now be re-classified as OPERABLE and an AOGCC witnessed MIT-IA will be scheduled once on stable injection. Please respond with any questions. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Tuesday, September 19, 2023 2:06 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: David Haakinson <dhaakinson@hilcorp.com> Subject: RE: [EXTERNAL] RE: NOT OPERABLE: MPS-33 (PTD# 2061720) PWI Injection without current MIT-IA Mr. Wallace, MPS-33 will remain shut in due to reservoir management and will remain NOT OPERABLE. Hilcorp will notify the AOGCC prior to placing the well back on injection and proceed with an AOGCC witnessed MIT-IA once on stabilized injection. David Haakinson will be providing the AOGCC with an incident investigation report. Please respond with any questions, Thank you, CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Ryan Thompson Milne / Islands Well Integrity Engineer 907-564-5005 From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Monday, September 18, 2023 4:50 PM To: Ryan Thompson <Ryan.Thompson@hilcorp.com>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: David Haakinson <dhaakinson@hilcorp.com> Subject: [EXTERNAL] RE: NOT OPERABLE: MPS-33 (PTD# 2061720) PWI Injection without current MIT-IA Ryan, You are authorized to return the well to injection and, once stabilized, complete the state witnessed MIT-IA. AOGCC will open up an investigation docket and depending on timing, will issue either an investigation notice or move directly to a Notice Of Violation. It may behoove Hilcorp to review recent AOGCC issued enforcements for corrective actions which generally include a requirement for the operator to complete a root cause into the violation, and complete a review of wells to ensure there are no others with this similar condition (injecting with an overdue MIT). 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: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Monday, September 18, 2023 4:06 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: David Haakinson <dhaakinson@hilcorp.com> Subject: RE: NOT OPERABLE: MPS-33 (PTD# 2061720) PWI Injection without current MIT-IA Mr. Wallace, Attached is a 90 day TIO plot and the Wellbore Schematic. MPS-33 is a dual string PWI injector. Water injection was only active down the long string. 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. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. The last passing MIT-IA was on 3/16/2019. The well has no current integrity issues identified. Please respond with any questions. Thank you, Ryan Thompson Milne / Islands Well Integrity Engineer 907-564-5005 From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Monday, September 18, 2023 9:32 AM To: Ryan Thompson <Ryan.Thompson@hilcorp.com>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: David Haakinson <dhaakinson@hilcorp.com> Subject: [EXTERNAL] RE: NOT OPERABLE: MPS-33 (PTD# 2061720) PWI Injection without current MIT-IA Ryan, Thank you for the email. Please send a 90 day TIO plot, and confirm that the well has no known integrity issues or reasons we should keep this well shut-in. 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: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Saturday, September 16, 2023 5:32 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: David Haakinson <dhaakinson@hilcorp.com> Subject: NOT OPERABLE: MPS-33 (PTD# 2061720) PWI Injection without current MIT-IA Mr. Wallace, Hilcorp Alaska, LLC is self-reporting water injection into not operable well MPS-33 (PTD# 2061720) since March of 2023. MPS-33 did not receive the required passing MIT-IA in March and was made not operable due to the SCADA system incorrectly labeling the well as offline. This error was discovered today (09/16/2023) and the well was immediately shut-in. Hilcorp will investigate this incident and leave the well shut-in until AOGCC approval is received to return the well to injection and conduct an MIT-IA. Please respond with any comments or concerns. Thank you, Ryan Thompson Milne / Islands Well Integrity Engineer 907-564-5005 From: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Sent: Sunday, April 2, 2023 2:40 PM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov>; Regg, James B (CED) <jim.regg@alaska.gov> Cc: David Haakinson <dhaakinson@hilcorp.com> Subject: NOT OPERABLE: MPS-33 (PTD# 206-172) Missed AOGCC Witness MIT-IA Mr. Wallace, WAG Injector MPS-33 (PTD# 206-172) is currently shut in and will not be brought online for its scheduled MIT-IA. The well is now classified as NOT OPERABLE and will remain shut in. A witnessed MIT-IA will be scheduled once the well is returned to injection. Please respond with any comments or concerns. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: 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: NOT OPERABLE: MPS-33 (PTD# 2061720) PWI Injection without current MIT-IA Date:Tuesday, September 19, 2023 2:10:50 PM From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Tuesday, September 19, 2023 2:06 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: David Haakinson <dhaakinson@hilcorp.com> Subject: RE: [EXTERNAL] RE: NOT OPERABLE: MPS-33 (PTD# 2061720) PWI Injection without current MIT-IA Mr. Wallace, MPS-33 will remain shut in due to reservoir management and will remain NOT OPERABLE. Hilcorp will notify the AOGCC prior to placing the well back on injection and proceed with an AOGCC witnessed MIT-IA once on stabilized injection. David Haakinson will be providing the AOGCC with an incident investigation report. Please respond with any questions, Thank you, Ryan Thompson Milne / Islands Well Integrity Engineer 907-564-5005 From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Monday, September 18, 2023 4:50 PM To: Ryan Thompson <Ryan.Thompson@hilcorp.com>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: David Haakinson <dhaakinson@hilcorp.com> Subject: [EXTERNAL] RE: NOT OPERABLE: MPS-33 (PTD# 2061720) PWI Injection without current MIT-IA Ryan, You are authorized to return the well to injection and, once stabilized, complete the state witnessed MIT-IA. AOGCC will open up an investigation docket and depending on timing, will issue either an investigation notice or move directly to a Notice Of Violation. It may behoove Hilcorp to review recent AOGCC issued enforcements for corrective actions which CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. generally include a requirement for the operator to complete a root cause into the violation, and complete a review of wells to ensure there are no others with this similar condition (injecting with an overdue MIT). 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: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Monday, September 18, 2023 4:06 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: David Haakinson <dhaakinson@hilcorp.com> Subject: RE: NOT OPERABLE: MPS-33 (PTD# 2061720) PWI Injection without current MIT-IA Mr. Wallace, Attached is a 90 day TIO plot and the Wellbore Schematic. MPS-33 is a dual string PWI injector. Water injection was only active down the long string. The last passing MIT-IA was on 3/16/2019. The well has no current integrity issues identified. Please respond with any questions. Thank you, Ryan Thompson Milne / Islands Well Integrity Engineer 907-564-5005 From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Monday, September 18, 2023 9:32 AM To: Ryan Thompson <Ryan.Thompson@hilcorp.com>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: David Haakinson <dhaakinson@hilcorp.com> Subject: [EXTERNAL] RE: NOT OPERABLE: MPS-33 (PTD# 2061720) PWI Injection without current MIT-IA Ryan, 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. Thank you for the email. Please send a 90 day TIO plot, and confirm that the well has no known integrity issues or reasons we should keep this well shut-in. 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: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Saturday, September 16, 2023 5:32 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: David Haakinson <dhaakinson@hilcorp.com> Subject: NOT OPERABLE: MPS-33 (PTD# 2061720) PWI Injection without current MIT-IA Mr. Wallace, Hilcorp Alaska, LLC is self-reporting water injection into not operable well MPS-33 (PTD# 2061720) since March of 2023. MPS-33 did not receive the required passing MIT-IA in March and was made not operable due to the SCADA system incorrectly labeling the well as offline. This error was discovered today (09/16/2023) and the well was immediately shut-in. Hilcorp will investigate this incident and leave the well shut-in until AOGCC approval is received to return the well to injection and conduct an MIT-IA. Please respond with any comments or concerns. Thank you, Ryan Thompson Milne / Islands Well Integrity Engineer 907-564-5005 From: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Sent: Sunday, April 2, 2023 2:40 PM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov>; Regg, James B (CED) <jim.regg@alaska.gov> Cc: David Haakinson <dhaakinson@hilcorp.com> Subject: NOT OPERABLE: MPS-33 (PTD# 206-172) Missed AOGCC Witness MIT-IA Mr. Wallace, WAG Injector MPS-33 (PTD# 206-172) is currently shut in and will not be brought online for its scheduled MIT-IA. The well is now classified as NOT OPERABLE and will remain shut in. A witnessed MIT-IA will be scheduled once the well is returned to injection. Please respond with any comments or concerns. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: MPS-33 (PTD# 2061720) PWI Injection without current MIT-IA Date:Monday, September 18, 2023 10:34:15 AM From: Wallace, Chris D (OGC) Sent: Monday, September 18, 2023 9:32 AM To: Ryan Thompson <Ryan.Thompson@hilcorp.com>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: David Haakinson <dhaakinson@hilcorp.com> Subject: RE: NOT OPERABLE: MPS-33 (PTD# 2061720) PWI Injection without current MIT-IA Ryan, Thank you for the email. Please send a 90 day TIO plot, and confirm that the well has no known integrity issues or reasons we should keep this well shut-in. 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: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Saturday, September 16, 2023 5:32 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: David Haakinson <dhaakinson@hilcorp.com> Subject: NOT OPERABLE: MPS-33 (PTD# 2061720) PWI Injection without current MIT-IA Mr. Wallace, Hilcorp Alaska, LLC is self-reporting water injection into not operable well MPS-33 (PTD# 2061720) since March of 2023. MPS-33 did not receive the required passing MIT-IA in March and was made not operable due to the SCADA system incorrectly labeling the well as offline. This error was discovered today (09/16/2023) and the well was immediately shut-in. Hilcorp will investigate this incident and leave the well shut-in until AOGCC approval is received to return the well to injection and conduct an MIT-IA. Please respond with any comments or concerns. Thank you, Ryan Thompson Milne / Islands Well Integrity Engineer 907-564-5005 From: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Sent: Sunday, April 2, 2023 2:40 PM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov>; Regg, James B (CED) <jim.regg@alaska.gov> Cc: David Haakinson <dhaakinson@hilcorp.com> Subject: NOT OPERABLE: MPS-33 (PTD# 206-172) Missed AOGCC Witness MIT-IA Mr. Wallace, WAG Injector MPS-33 (PTD# 206-172) is currently shut in and will not be brought online for its scheduled MIT-IA. The well is now classified as NOT OPERABLE and will remain shut in. A witnessed MIT-IA will be scheduled once the well is returned to injection. Please respond with any comments or concerns. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: MPS-33 (PTD# 206-172) Missed AOGCC Witness MIT-IA Date:Tuesday, April 4, 2023 9:07:30 AM From: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Sent: Sunday, April 2, 2023 2:40 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: David Haakinson <dhaakinson@hilcorp.com> Subject: NOT OPERABLE: MPS-33 (PTD# 206-172) Missed AOGCC Witness MIT-IA Mr. Wallace, WAG Injector MPS-33 (PTD# 206-172) is currently shut in and will not be brought online for its scheduled MIT-IA. The well is now classified as NOT OPERABLE and will remain shut in. A witnessed MIT-IA will be scheduled once the well is returned to injection. Please respond with any comments or concerns. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, March 22, 2019 TO: Jim Regg P.I. Supervisor �i<7 3lzf"Ir�' SUBJECT: Mechanical Integrity Tests [ HILCORP ALASKA LLC S -33A FROM: Lou Laubenstein MILNE PT UNIT S -33A Petroleum Inspector Sre: Inspector Reviewed By: P.L Supry J76�— NON -CONFIDENTIAL Comm Well Name MILNE PT UNITS -33A API Well Number 50-029-23123-01-00 Inspector Name: Lou Laubenstein Permit Number: 206-172-0 Inspection Date: 3/16/2019 Insp Num: mi[LOLI90316161058 Rel Insp Num: Packer �Deptb Pretest Initial 15 Min 30 Min 45 Min 60 Min — — -- Well s 33A - Type InJ w' TVD 1 4084 Tubing 1081 1081 1080 1019 - PTD 2061720 Type Testi SPT Test psi 1500 IA 436 1726 670 - 648 BBL Pumped:- 09 -rBBLReturned: 0.9 OA 245 1392 178 sea Interval 4YRTST Notes: Friday, March 22, 2019 Page I of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim jtegg DATE: Tuesday,March 17,2015 P.I.Supervisor`` L( I( 7(2.6115 SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC S-33A FROM: Bob Noble MILNE PT UNIT SB S-33A Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv.'— NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT SB S-33A API Well Number 50-029-23123-01-00 Inspector Name: Bob Noble Permit Number: 206-172-0 Inspection Date: 3/12/2015 Insp Num: mitRCN150312155826 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well s-33A —rType Inj T W TVD 4084 Tubing 1164 T 1161 - 1156 - T 1157 1 PTD 2061720 Type Te tsPT Test psi 1500 1 IA ]5 1912 - 1874 - 1 1865 - Interval 'I4YRTST - P/F--I-- P OA I 60 I 271 - 271 1 266 - -- — Notes: l Tuesday,March 17,2015 Page 1 of 1 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. ~Q ~ - ~ ~ ~~.. Well History File Identifier Organizing (done) ^ Two-sided III II~IIIIIIII II III ^ Rescan Needed III II~IIIII II III III R CAN DIG TAL DATA OVERSIZED (Scannable) Color Items: Diskettes, No. ~ ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~ /s/ ProjectProofing IIIIIIIIIIIIII VIII BY: Maria Date: /s/ Scanning Preparation I x 30 = ~ ~ + ` =TOTAL PAGES__~.~~ l (Count does not include cover sheet) BY: Maria Dater / ~ ~ ~ /s/ P,~d~«,a~s~.~ , "' IIIIIIIIIIIIVIIII Stage 1 Page Count from Scanned File: (Count does include cover sheet) Pa e Count Matches Number in Scanning Preparation: V YES NO BY: Maria Date: ~~ ~ ~ /s/ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanningrs complete at this point unless rescanning is required. II I II'I II I II II I I III Rescanned II I II ~I II I I III I I III BY: Maria Date: /s/ Comments about this file: o~a ~,~~e~,~a IIIIIIIIIIIIIIIIIiI 10/6/2005 Well History File Cover Page.doc ' w %,�\OF Tit \�%%.s� THE STATE Alaska Gas -_..04111,1 ®1 L ASKA Conservation Commission r�. GOVERNOR SEAN PARNELL 333 West Seventh Avenue Off; Q. Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1433 SCANNED k J\` Fax: 907.276.7542 Alicia Wood Pad Engineer BP Exploration(Alaska), Inc. a0 P.O. Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Field, Schrader Bluff Oil Pool, SBL MPS-33ALS Sundry Number: 313-509 Dear Mr. Wood: 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, /99aLt4ii Cathy P. oerster Chair, Commissioner DATED this day of September, 2013. Encl. • f Es..w # • 4 P 232 • STATE OF ALASKA iV� S ALASKA OIL AND GAS CONSERVATION COMMISSION A G (3 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 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: MBE Treatment • Ill 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. BP Exploration(Alaska),Inc. Exploratory ❑ Development ❑ 206-172-0 • 3.Address: 6.API Number. Stratigraphic ❑ Service Q• Grp-0 Z9- a3/a3-01.-() P.O.Box 196612,Anchorage,AK 99519-6612 50-029-234H-824V )j3 7.If perforating: 8.Well Name and Number. eflAh I4l2' What Regulation or Conservation Order governs well spacing in this pool? SBL MPS-33ALS Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0380109 ' MILNE POINT,SCHRADER BLFF 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): 5500 4432• 5410• 4352 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 82 20"X 34"215.5#A53 30-112 30-112 Surface 2172 - 9-5/8"40#L-80 28-2200 28-2093.06 5750 3090 Intermediate None None None None None None Production 5470 7"26#L-80 26-5496 26-4428.53 7240 5410 Liner None None None None None None Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 5130-5160 . 4106.56-4132.03 2-3/8"4.7#L-80 L-80 25-5185 / Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD(ft)and TVD(ft): See Attachment for Packer Depths�/ No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program El • BOP Sketch ❑ Exploratory ❑ Development ❑ Service 0- 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ 12' GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Alecia Wood Email Aleda.Wood@BP.Com Printed Name Alecia Wood Title Pad Engineer Signatur / Phone 564-5492 Date Prepared by Garry Catron 564-4424 ll COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number J l -S0 Q Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other F Br MS OCT 1 0 2 Spacing Exception Required? Yes ❑ No Subsequent Form Required: /a — 404— APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: ol)_ /3 vt,„r f��/j�tc Form 10-403 Revised 10/2012 Approved application is valid for 12 months from the date of approval. Submit Form and Attachments i�plicaT • • Packers and SSV's Attachment ADL0380109 Well Facility Type MD Top Description TVD Top MPS-33ALS PACKER 5102 2-3/8" Baker GT Dual Packer 4083 MPS-33ALS PACKER 5170 7"x 2-3/8" Baker FH Ret Packer 4141 • • by To: Mark O'Malley/Rob Handy Date: September 18, 2013 MPU Ops Team Leaders From: Alecia Wood, MPU Schrader Pad Engineer 907-564-5492 Subject: MPS-33ALS Preventative MBE Treatment Step Unit Operation 1 F Shut in all offset producers. Bullhead water into MPS-33ALS. 2 F Bullhead treatment down MPS-33ALS (OB sand). Keep well and offset producers and injectors shut in for the duration of the treatment and flow producers to a tank before returning to production if necessary. OBJECTIVE On average, cement and polymer MBE treatments break down after -6 months. This treatment has been holding for one year. The objective of this polymer job is to extend the life of the successful 2012 MBE treatment by pumping a preventative polymer job. Measure of success 1. Treatments are displaced into formation. 2. Post injection is adequate to achieve injection rate target at below target pressure. 3. Decrease of watercut over time in offset producers is observed. CRITICAL ISSUES • Ensure pumping pressure is not above the fracture gradient. • Ensure cleanliness of pump equipment and hard line (pre and post job) & properly dispose of remnant fluid per guidance from the Environmental Team. Background MPS-33 was drilled and completed as an OA/OB dual string injector in the Schrader Bluff in 2002. MPS-33 supports producers MPS-17 (-400 bopd), MPS-23 (-300 bopd), and MPS-25 (-900 bopd). After nine months of injection the first MBE developed in the OA (short string) to MPS-23. Additional MBE's followed in 2004 and 2005 in the OB (long string) to both MPS-23 and MPS-25. MBE treatments were attempted in 2005 in both the short string and the long string with zero success. A second round of treatments in 2006 had very limited success, lasting less than 2 months. MPS-33 was sidetracked 500 feet away to MPS-33A in 2007. MPS-33A was also completed as a dual string injector in the Schrader Bluff OA/OB. An MBE broke through in the OA (short string) of the newly drilled MPS-33A in only 40 days to MPS-23. The long string was more successful lasting -3 years before breaking though in the OB (long string) to MPS-25. An MBE treatment was performed in the long string (OB) in 2010 lasting 151 days. Currently MPS-23 is online, however MPS-25 is shut in and MPS-17 is choked back due to a lack of injection support in HU 10. Cumulative injection totals combined between MPS-33 and MPS-33A are as follows: OA - 0.656 MMBBL, OB - 1.672 MM BBL. In September of 2012 a Thermatek and H2Zero MBE treatment was pumped that was successful in reducing injectivity of S-33ALS and reducing the WC of S-25. • • PROCEDURE Stage 1. Injection Test 1. RU, hold pre-job safety meeting, PT surface lines 2. Ensure offset producers are SI. 3. Spear in with Methanol, followed by produced water. Attempt to hold injection rate constant while 9p adjustin pressure as needed. 4. Contact Engineering to discuss the injection pressure/rate trends. Once consensus is achieved that the fluid can be successfully placed into formation at acceptable rate/pressure continue with remainder of program. Stage 2. Treatment 5. Ensure offset producers are offline 6. Pump produced water pre-flush followed by high volume gel treatment and diesel over flush. 7. Capture a gel sample at surface and suspend in a warm water bath (to simulate downhole conditions) to monitor actual setting time. 8. Rig down all equipment and hold post-job assessment meeting to capture learnings to be incorporated into future jobs. 9. Forward all post job assessments (w/all rheology test summary) and continuous pressure and rate data from job to Pad Engineer. • • flee:CM 2 1tir 5AI Dual string Wet leakt11'x 2 3i'8*SM FA4C*Jai string MPS-33Ai Orig.KB Elev.=65.70 Hanger thread 2 316TEUE top and 1ST tortorn — - Ong.01..Elev.=38.20 T CIW-H Spy prollie 20"x 34'incLiated.215 At A-53 11 *-NOTE"" SHORT STRING IS THE LOWER VALVE LONG STRING IS THE HIGHER VALVE ON TNE TREE ON THE TREE Short Straw I ong String 30:1 1"-la: cple •1-'31 pkg.sore LJ 2-363-PIES X-Nisole 01175'pkg.borei 3003' KCIP 700' Max_hale angle=45 deg 3850' Hole senile anvil perks=35 deg :NO 9 5?5*HOWCO Float Shoe S5 40#L-90 STC Casing Itirlit Ill-5.679,cap.-.0292 Inpn 7'2541,L-90,BTC Casing :Olt -6.151,cap.-.1393 tort 2-341-,4.7#It L-90,Hydrt 553 lobing l'aint -1,901,043.-00397 nor 2-19"NES X-tibple,• 1"1"pkg.Dore 5:5,5 5155' 2-19-NES 175'pkg.Pore 7"x 2-3.tr Baiter G Ret cu 31 plo 5.:- 945'! 5112. 2-349°HES XN-Nopie pig.Intret No-Go 1.791' 5123' Tubing CV I WILEG Perforation Sionmary 2..712-311ria Elater-fif Rat rar. 5170' Size Spf Interval 2-105-HES XlMernie(1815'pg.bore} 5171 LEAN= NoGo 1191" 33!5' 4 5130'-51E0' 4/06'-4112' 09 sands eater E'Hydro TM.Ste) 3 341" 4 va -5218' 411 -415.. 1191 sin nudes**idlp p.orr pkg.bare) Hydro Trip Sub ELM D 35 1.71*Derlr Eat, 5411 r HES Float Collar PBTD 0 5499 r NES float Shoe CATE REV.BY COMMENTS MILNE POINT UNIT 11;13.112 J Jones Dyan!by Cased Down 141 WELL No.:S-33iA 1211 7?02 -ee Holm* CompleSon Rig 4ES API 50-029-23123-01-04) 233107 Mi.V Rosa Side Tract It Cornplellon Doyom 14 BP EXPLORATION (AK) RECEIVED STATE OF ALASKA JAN 3 0 2013 • AKA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS A0000 1. Operations Abandon U Repair Well U Plug Perforations U Perforate Lf Other U MBE Treatment Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended Well❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development Exploratory ❑ 206 -172 -0 3. Address: P.O. Box 196612 Stratigraphic❑ Service 0 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 23123 -82 -00 7. Property Designation (Lease Number): 8. Well Name and Number ADL0380109 SBL MPS -33ALS 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): I To Be Submitted MILNE POINT, SCHRADER BLFF OIL 11. Present Well Condition Summary: Total Depth measured 5500 feet Plugs measured None feet true vertical 4432.09 feet Junk measured None feet Effective Depth measured 5410 feet Packer measured See Attachment feet true vertical 4352.04 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 82 20" X 34" 215.5# A53 30 - 112 30 - 112 0 0 Surface 2172 9 -5/8" 40# L -80 28 - 2200 28 - 2093.06 5750 3090 Intermediate None None None None None None Production 5470 7" 26# L -80 26 - 5496 26 - 4428.53 7240 5410 Liner None None None None None None Perforation depth Measured depth 5130 - 5160 feet 5188 - 5218 feet SCANNED APR 2 4 2013 True Vertical depth 4106.56 - 4132.03 feet 4156.15 - 4182.22 feet Tubing (size, grade, measured and true vertical depth) 2 -3/8" 4.7# L -80 25 - 5185 25 - 4153.55 Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 - 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development ❑ Service 0 Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas ❑ WDSPLU GSTOR ❑ WINJ 0 WAG ❑ GINJ ❑ SUSP ❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 312 -279 Contact Nita Summerhays Email Nita.Summerh Printed Name Nita Summerhays Title Petrotechnical Data Technician ' �,/j/�% //% j",,,_ - Phone 564 -4035 Date 1/30/2013 I Vi RBDMS JAN 31 10' .' 4/i / Form 10 -404 Revised 10/2012 X K /‘71_,,3 Submit Original Only • • Daily Report of Well Operations ADL0380109 Hes Thermatek Treatmen: ong ring ; on rom rY 9/16/12 ... PT all treating lines to 250 / 4000 psig - passed. Attempt to inject into well. Work surface pressure in cycles up to 3500 psig WHP. Unable to establish injection..... Job Complete 9/17/2012 ** *WELL S/I ON ARRIVAL ** *(drift &tag) D &T W/ 1.71" CENT & 1.50" S.BAILER, T/S STARTED SETTING DOWN @ 4300' SLM, STOPPED FALLING COMPLETELY @ 4504' SLM, RECOVERED FULL BAILER OF THERMATEK ** *WELL S/I ON 12/12/2012 DEPARTURE * ** CTU #8 w/ 1.5" CT ( CTV =29.8) Objective- restore injectivity by removing Thermatek and K -Max gel from tubing long string (FCO) MIRU from 6 -22. Function test BOP's. RIH w/ 1.75" nozzle assy taking returns to OTT to 4578'. Pooh. MU and RIH w/ BHA; 1.5" ctc, 1.69" dfcv, disco, 1.55" ported crossover, 1.69" PDS memeory GR,CCL (oal= 12.78') stop at 4500' log 40 fpm to 4000' PUH to 3200 and log 40 fpm across the "X" nipple to 12/30/2012 2800' start Pooh. * *job continued on WSR 12- 31 -12 ** Continued from WSR 12- 30 -12. CTU 8 w/ 1.5" CT. Scope; restore injectivity by removing Thermatek and K -Max gel from tubing long string Continue pooh w /BHA; 1.5" ctc, 1.69" dfcv, disco, 1.55" ported crossover, 1.69" PDS memeory GR,CCL (oal= 12.78'). Good data indicating +13' correction. MU and RIH w/ BHA #3; 1.5' ctc, 1.7" dfcv, 1.69" jars, disco,circ sub, motor,1.73" bear paw mill (oal= 18.69'). Cleanout cautiously and easily w/ no MW or weight loss to 5035'. Got into assumed set- up gel which partially plugged choke, but milled easily w/ -200 psi MW and lite wt ( <0.5k wob) to a stall at 5127'. Then, progress became increasingly slower and took 2 -3k wob w/ 300- 400 psi diff to mill at -1'/10 min. Milled to 5156' while circ two 10 bbl biozan sweeps and progress became too slow. POH to change motor. Changed out motor, reran mill. RIH to 5156. Mill 12/31/2012 to 5164'. pooh. * *job continued on WSR 01- 01 -13 ** Continued from WSR 12- 31 -12; CTU 8 w/ 1.5" CT. Scope; restore injectivity by removing Thermatek and K -Max gel from tubing long string Finish Pooh. All outside cutting buttons (5 -1/2) were broken off of mill. Inner buttons were intact and Thermatek was still visible on the nose (see pics). MU and RIH w/ BHA #3; 1.5' ctc, 1.7" dfcv, 1.69" jars, disco,circ sub, motor,1.73" 3 blade junk mill (oal= 18.69'). saw MW @ 5160, could not mill pass 5163. Pooh. The outer 1/3 of mill face was very worn, but the inner 2/3 had no wear. Mill also had circumferential scarring. Perform weekly BOPE test w/ no failures. Run PDS caliper from tag to -2500'. Determine tag was at 5170' which is near the lower packer and 15' from the EOT. No abnormal restrictions were seen. RIH w/ BHA; 1.5" ctc, 1.69" dfcv, jars, disco, circ sub, venruri (oal= 16.25') to 5164' work venturi up /down several 1/1/2013 times. pooh. * *job continued on WSR 01- 02 -13 ** • • Daily Report of Well Operations ADL0380109 Continued from WSR 01- 01 -13. CTU 8 w/ 1.5" CT. Scope; restore injectivity by removing Thermatek and K -Max gel from tubing long string. Finish pooh with venturi. Venturi was empty. MU and RIH w/ BHA; 1.5' ctc, 1.7" dfcv, 1.69" jars, disco,circ sub, motor,1.75" DS mill (oal= 18.67') to 5164' mill to target depth at 5233' CTM. Perform injectivity test w/ KCI at 1.0 bpm /1050 psi. FP w/ 10 bbls McOH. RDMO to MPC -05 Job 1/2/2013 complete HES H2Zero polymer job. Unit work permit opened up. Dig out from blow for 2 days. Stage in equipment. PJSM, Barriers = SSV and Swab valve. Pump as per job schedule listed in log - 5 bbls 60/40 meth, 116 bbls PW (stayed on PW while thawing cross linker equipment), pumped 400 bbls H2Zero w/ pH = 11 at 1.22 bpm, 25 bbls PW and 10 bbls 60/40 meth to displace into formation. SD, secure well, blow down lines and release transports. Hold off on RD equipment until next day due to - 1/17/2013 65degF windchill. Job complete FLUIDS PUMPED BBLS 157 METH 663 1 %KCL 21 BIOZAN 55 60/40 METH 240 2% SLICK KCL 316 TOTAL • • Packers and SSV's Attachment ADL0380109 SW Name Type MD TVD Depscription MPS -33ALS PACKER 5102 4011.2 2 -3/8" Baker GT Dual Packer MPS -33ALS PACKER 5170 4068.61 7" x 2 -3/8" Baker FH Ret Packer Tree: CIW 2 1/16" 5M Dual sip KB Elev. = 65.70' Wellhead:11" x 2 3/8" 5M FMC dual string MPS -33Ai Orig. Hanger thread 2 3/8" EUE top and IBT bottom Orig. GL Elev. = 38.20' 2" CIW -H BPV profile 20" x 34" insulated, 215 #/ft A -53 112' ** *NOTE * ** ** *NOTE * ** SHORT STRING IS THE LOWER VALVE LONG STRING IS THE HIGHER VALVE ON THE TREE ON THE TREE Short String Long String 3001' 2 -3/8" HES X- Nipple (1.875" pkg. bore) 2 -3/8" HES X- Nipple (1.875" pkg. bore)I 3003' KOP @ 700' Max. hole angle = 45 deg @ 3850' Hole angle thru perfs = 35 deg 2200' 9 5/8" HOWCO Float Shoe 9 5/8" 40# L -80 BTC Casing (drift id = 8.679, cap. = .0282 bpf) 7" 26#, L -80, BTC Casing (drift id = 6.151, cap.= .0383 bpf) 2 -3/8 ", 4.7 #/ft L -80, Hydril 563 tubing (drift id = 1.901, cap. = .00387 bpf) 2 -3/8" HES X- Nipple (1.875" pkg. bore) 5056' I 5056' 2 -3/8" HES X- Nipple (1.875" pkg. bore) ■ 7" x 2 -3/8" Baker "GT" Ret. dual pkr. 1 5102' 1.945" ID. 5112' 2 -3/8" HES XN- Nipple (1.875" pkg. bore) XN No -Go 1.791" ■ I 5123' I Tubing tail / WLEG I I Perforation Summary 7 x 2 -3/8" Baker "FH" Ret. pkr. I 5170' I b40, BM,07 2.41" ID. Size Spf Interval (TVD) (7A sands XN 2 -3/8" HES XN- Nipple (1.875" pkg. bore) I 5178' No -Go 1.791" 3 3/8" 4 5130' - 5160' 4106' - 4132' OB sands 2 -3/8" Baker 'E' Hydro Trip Sub 3 3/8" 4 5188' - 5218' 4156' - 4182' 5182' w/ muleshoe pup (2.00" pkg. bore) I Hydro Trip Sub ELMD I 5185' I 1.75" Delrin Ball. I 5411' 5496' I Collar PBTD 7" HES Float Sho /// % • DATE REV. BY COMMENTS 11/13/02 J. Jones MILNE POINT UNIT Drilled by Cased Doyon 141 WELL No.: S-33iA 12/17/02 Lee Hulme Completion Rig 4ES API : 50 -029- 23123 -01 -00 2/3/07 Mr. M. Ross Side Track & Completion Doyon 14 BP EXPLORATION (AK) I // THE STATE Alaska Oil and Gas LASKA A Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501 -3572 � ALAS�� Main: 907.279.1433 ��® `n" 16 2,3413 Fax: 907.276.7542 Alecia Wood MPU Schrader Pad Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Milne Point Field, Schrader Bluff Oil Pool, SBL MPS -33ALS Sundry Number: 312 -392 Dear Ms. Wood: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy Foerster Chair DATED this / 7 day of October, 2012. Encl. • 06,0 , / ECEIVED b STATE OF ALASKA WI &''S T 10 20 +� ALASKA OIL AND GAS CONSERVATION COMMISSION (01 (G i z. APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations❑ Perforate ❑ Pult Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. WeII❑ Stimulate El ' Alter Casing ❑ Other. ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 206-172-0 • 3. Address: Stratigraphic ❑ Service El • 6. API Number. P.O. Box 196612, Anchorage, AK 99519 - 6612 50-029- 23123 -82 -00 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order govems well spacing in this pool? SBL MPS -33ALS . Will planned perforations require a spacing exception? Yes ❑ No ❑ 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL0380109 ` MILNE POINT, SCHRADER BLFF OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): � ugs (measured): Junk (measured): 5500 1 4432 ' 5410 4352 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 82 20 "X34" 215.5# A53 30 -112 30 -112 Surface 2172 9 -5/8" 40# L -80 28 - 2200 28 - 2093.06 5750 3090 Intermediate None None None None None None Production 5470 7" 26# L -80 26 - 5496 26 - 4428.53 7240 5410 Liner None None None None None None Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5130 - 5160 4106.56 - 4132.03 2 -3/8" 4.7# L -80 L-80 25 - 5185 Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD (ft) and TVD (ft): See Attachment for Packer Depths No SSSV Installed No SSSV Installed 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program Q BOP Sketch ❑ Exploratory ❑ Development ❑ Service 0 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: Oil ❑ , Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ 8 GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Alecia Wood Email Alecia.Woode8P.Com Printed Name Alecia Wood Title MPU Schrader Pad Engineer Signature Phone 564 -5492 Date &WO) U.\ ►1iIt IIa COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 5\ Z. 2.. Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No ❑ Subsequent Form Required: /0 — '/0 y APPROVED BY Approved by:� i / ?dx COMMISSIONER THE COMMISSION Date: /0 — J Z �/ oRt6ft Ai412010 p ov4dpplklrtiortis`irall the date of approval. !/ / Submit in Duplicate 3 • • Packers and SSV's Attachment ADL0380109 Well Facility Type MD Top Description TVD Top MPS -33ALS PACKER 5102 2 -3/8" Baker GT Dual Packer 4083 MPS -33ALS PACKER 5170 7" x 2 -3/8" Baker FH Ret Packer 4141 . . bp To: Mark O'Malley /Rob Handy Date: October 09, 2012 MPU Well Operations Supervisor From: Alecia Wood, MPU Schrader Pad Engineer 907 - 564 -5492 Subject: MPS -33ALS Coil Cleanout, Acidize Step Unit Operation 1 C Conduct coil cleanout of wellbore 2 C Acidize as necessary OBJECTIVE 1. Cleanout wellbore with coil tubing post MBE treatment. Acidize as necessary to regain - injectivity. PROCEDURE Cleanout 1. RU, hold pre job safety meeting, PT 2. RIH and cleanout wellbore with coil tubing to bottom perf (5218'MD) • 3. Perform injectivity test with produced water. Contingency if injectivity is not regained 4. Spot 2.5bbls of HCI and soak tubing /Liner. (WBV from bottom perf to Tubing Tail is 1.38bbls, do not want to acidize the thermatek in the matrix and compromise the treatment). 5. Perform injectivity test with produced water raising injection pressure to a max of 4000 psig if necessary. S 0 A ` Tree: 2 aes s satin op ring MPS -33Ai Orig. KB Elev. = 85.70' Hanger thread 2 6B EUE top and MT Do tom 1 - — Ong_ GL Elev. = 3$.20` 2' CM 6PV profile 20' x 34' inwdaaed, 215 AM A I 112 — NOTE — " NOTE "• SHORT STRING IS THE LOWER VALVE LONG STRING IS THE HIGHER VALVE ON THE TREE ON THE TREE Short String j nng String 1 30;11' I2 -346' H :G X- Nipple r' e 7E' pkg. pare; El -1Q_ X- Nipale f 1 5- 575 pkg. core;I 30 v' ICOP a 700' Max. hole angle = 45 deg a 3850' Fide angle ttnu pert = 35 deg 1 2200' I 9 516' HOWCO Float Shoe , 4 Ur 40N L-60 OTC Caking IdrIIt Id - 6.67, cap. - .02712 bprl r 26e, L-50, OTC Casing dr1R Id - 6.151, cap. .8382 tor) 2 -113 ", 4.7 tM9 L -89, Hydni 5€3 tutNrrg tanl' I d 1.901, cap.-.0O317 for 1 5456' 12 -3,6' HES X phe (t 975' pkg. Dare 2-346' 'lES X-N pp* 11175' Pkg. bore; 1 5956' I x 2 - 2 r Baker *GT' Net aunt pkr 15' 72 I * ;45' ID I St 12' I2-66' HES X 1- Nlppie 1l.87 peg Ocrei No-Go 1.791' I 5'23. I Tubing tat . W!_EG Perforation Summary 7' k 2 -3+59' Daker'FFr Ret. pkr. I o' D I - 2.11' ID. Size Spf Interval I ND _Cala= ® 2 HES XN Nipple ;l. No - Go 7 tg. bore) 1 517@' I 3 3'5 4 5130' - 5160' 4196' - 4122' 08 aana 2 Eater rtydrd Trip Sub ? 3.'11' 4 5166' - 5216' 41.e6 - 4162 I 182 - °I rn rie tr pxrP i2.o r pig. b I . Hydro Trip Sub ELMD 1 5.35 I 1 5_11 I T HE Float Cohar?6TD 0 1.75' Deirin 6ali. I E49E' I 7' M ES float Shoe DATE E REV. 6Y COMMENTS MILNE POINT UNIT Drilled by Caned Ca3nn 141 WELL No.: S 12'17 +C12 fee Hulmt Completion Rig 4E5 API ' 50 - 029 - 23123 - 0 1 - 00 23;07 414. 4r. Ross Side Trac & Garnpletlon Doyen 1s BP EXPLORATION (AK) STATE OF ALASKA _ 1 . ALIIIL OIL AND GAS CONSERVATION COMMI N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well U Plug Perforations U Perforate U Other[✓ MBE Treatment Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended WOG 1 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development Exploratory ❑ 206 -172 -0 3. Address: P.O. Box 196612 Stratigraphic0 Service el 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 23123 -82 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0380109 SBL MPS -33ALS 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): To Be Submitted MILNE POINT, SCHRADER BLFF OIL 11. Present Well Condition Summary: Total Depth measured 5500 feet Plugs measured None feet true vertical 4432.09 feet Junk measured None feet Effective Depth measured 5410 feet Packer measured See Attachment feet true vertical 4352.04 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 82 20" X 34" 215.5# A53 30 - 112 30 - 112 0 0 Surface 2172 9 -5/8" 40# L -80 28 - 2200 28 - 2093.06 5750 3090 Intermediate None None None None None None Production 5470 7" 26# L -80 26 - 5496 26 - 4428.53 7240 5410 Liner None None None None None None Perforation depth Measured depth 5130 - 5160 feet 5188 - 5218 feet RECEIVED True Vertical depth 4106.56 - 4132.03 feet 4156.15 - 4182.22 feet OCT 1 Q 2012 Tubing (size, grade, measured and true vertical depth) 2 -3/8" 4.7# L -80 25 - 5185 25 - 4153.55 AOGCC Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): 5188' - 5218' (� 1 j Treatment descriptions including volumes used and final pressure: ANNED JAN 1 V L013 18.7 bbls of T -max, 6 bbls K -max, 10.3 bbls Thermatek, 19 bbls Diesel SCANNED 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development ❑ Service 0 Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas ❑ WDSPLU GSTOR ❑ WINJ 0 WAG ❑ GINJ ❑ SUSP ❑ SPLUG0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt 312 -279 Contact Nita Summerhays Email Nita.Summ erhaysCcDbp.co m Printed Name Nita Summerhays Title Petrotechnical Data Technician Signatu �� / �� . _ Phone 564 -4035 Date 10/9/2012 RE)MS OCT 112012.E ./14 1 I2 0 1 1/ i dt*z . Form 10-404 Revised 10/2012 Submit Original Only • • Daily Report of Well Operations ADL0380109 ACTIVITYDATE SUMMARY • 9/17/2012 'es erma e rea men ong ring ; on rom TY 9/16/12 ... PT all treating lines to 250 / 4000 psig - passed. Attempt to inject into well. Work surface pressure in cycles up to 3500 psig WHP. Unable to establish injection..... Job Complete FLUIDS PUMPED BBLS 19 DIESEL 18.7 T -MAX 6 K -MAX 10.3 THERMATEK 54 TOTAL • • Packers and SSV's Attachment ADL0380109 SW Name Type MD TVD Depscription MPS -33ALS PACKER 5102 4011.2 2 -3/8" Baker GT Dual Packer MPS -33ALS PACKER 5170 4068.61 7" x 2 -3/8" Baker FH Ret Packer t ` Tree: CIW 2 1/16" 5M Dual sta Wellhead:11" x 2 3/8" 5M FMC dual string MPS -33Ai Orig. KB Elev. = 65.70' Hanger thread 2 3/8" EUE top and IBT bottom Orig. GL Elev. = 38.20' 2" CIW -H BPV profile 20" x 34" insulated, 215 #/ft A -53 I 112' I ** *NOTE * ** ** *NOTE * ** SHORT STRING IS THE LOWER VALVE LONG STRING IS THE HIGHER VALVE ON THE TREE ON THE TREE Short String Long String 1 3001' 12 -3/8" HES X- Nipple (1.875" pkg. bore) rq 2 -3/8" HES X- Nipple (1.875" pkg. bore)I 3003' I KOP @ 700' Max. hole angle = 45 deg @ 3850' Hole angle thru perfs = 35 deg 2200' I 9 5/8" HOWCO Float Shoe I I 9 5/8" 40# L -80 BTC Casing (drift id = 8.679, cap. = .0282 bpf) 7" 26#, L -80, BTC Casing (drift id = 6.151, cap.= .0383 bpf) 2 -3/8 ", 4.7 #/ft L -80, Hydril 563 tubing (drift id = 1.901, cap.= .00387 bpf) 5056' 2 -3/8" HES X- Nipple (1.875" pkg. bore) 2-3/8" HES X- Nipple (1.875" pkg. bore) 1 5056' 7" x 2 -3/8" Baker "GT" Ret. dual pkr. 1 5102' 1 1.945" ID. I 5112' 12-3/8" HES XN- Nipple (1.875" pkg. bore) XN No -Go 1.791" 5123' I Tubing tail / WLEG C P Perforation Summary 7" x 2 -3/8" Baker "FH" Ret. pkr. 1 5170' I 2.41" ID. Size Spf Interval (TVD) (7A sands 2 -3/8" HES XN- Nipple (1.875" pkg. bore) I 5178' I No -Go 1.791" 3 3/8" 4 5130' - 5160' 4106' - 4132' OB sands 2 -3/8" Baker `E' Hydro Trip Sub 3 3/8" 4 5188' - 5218' 4156' - 4182' w/ muleshoe pup 1 5182' I (2.00" pkg. bore) Hydro Trip Sub ELMD 5185' 1 I: I. 1 5411' 1 7" HES Float Collar PBTD 1.75" Delrin Ball. 1 5496' I 7" HES Float Shoe . /1. • DATE REV. BY COMMENTS 11/13/02 J. Jones MILNE POINT UNIT Drilled by Cased Doyon 141 WELL No.: S-33iA 12/17/02 Lee Hulme Completion Rig 4ES API : 50 -029- 23123 -01 -00 2/3/07 Mr. M. Ross Side Track & Completion Doyon 14 BP EXPLORATION (AK) • • T F " ` „ L E SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMIISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276-7542 Alecia Wood Production Engineer BP Exploration (Alaska), Inc. . �.Q 6- Itig P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Milne Point Field, Schrader Bluff Oil Pool, MPS -33ALS Sundry Number: 312 -279 Dear Ms. Wood: t..ANNED .AUG L 2012 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, P Cathy . Foerster Chair ' 54' DATED this day of August, 2012. Encl. 4. 4 � STATE OF ALASKA , � RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION JUL 2 5 2012 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 MC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool El Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations \ U� ' t VPerforate ❑ Pull Tubing I] Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well L i . f 7 Stimulate ❑ Alter Casing ❑ Other. Al 6e- j_ 2. Operator Name: 4. Current Well Gass: 5. Permit to Drill Number: •TE E'k1 A4E AT BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 206 -172 -0 't' 1131) i 2 3. A d d r e s s : 6 . API Number: � . v z 7 _ y7, f i r . . ,, Stratigraphic El Service P.O. Box 196612, Anchorage, AK 99519 -6612 50-0 - 1 IP; 3, ,y 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No 0 MPS -33ALS 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL0380109 . MILNE POINT, SCHRADER BLFF 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): 5500 4432 - 5410 4352 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 82 20" X 34" 215.5# A53 30 - 112 30 - 112 Surface 2757 9 -5/8" 40# L -80 28 - 2785 28 - 2527.37 5750 3090 Intermediate None None None None None None Production 5470 7" 26# L -80 26 - 5496 26 - 4428.53 7240 5410 Liner None None None None None None Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attachment See Attachment 2 -3/8" 4.7# L -80 4154 25 - 5185 Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD (ft) and TVD (ft): See Attachment for Packer Depths No SSV Installed No SSV Installed 12. Attachments: Description Summary of Proposal 111 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service El - 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 8/21/12 Oil ❑ Gas ❑ WDSPL El Suspended ❑ 16. Verbal Approval: Date: WINJ 0 • GINJ El WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Prepared by Garry Catron 564 -4424 Printed Name Alecia Wood Title Production Engineer Signature I ., Phone Date A MCI- cQ 5t.12 q 5siga 4195i la- COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 51 2 - 4 1 - 1 0 1 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: /0 - 4 0 + APPROVED BY Approved by: ILI / p COMMISSIONER THE COMMISSION Date: 9 -1-- /Z. eie,9 0 r-We O/ 0 f012 t Submit in Duplicate � 31.5 i i i Z- ORIGNAL 1 '17:4"' ,i. • • Perforation Attachment ADL0380109 Well Date Perf Code MD Top MD Base TVD Top TVD Base MPS -33ALS 1/31/07 PER 5130 5160 4107 4132 MPS -33ALS 1/31/07 PER 5188 5218 4156 4182 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BRIDGE BPS PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF • • Packers and SSV's Attachment ADL0380109 Well Facility Type MD Top Description TVD Top MPS -33ALS PACKER 5102 2 -3/8" Baker GT Dual Packer 4083 MPS -33ALS PACKER 5170 7" x 2 -3/8" Baker FH Ret Packer 4141 bp • • To: Mark O'Malley /Rob Handy Date: June 22, 2012 MPU Ops Team Leaders From: Alecia Wood, MPU Schrader Pad Engineer 907 - 564 -5492 Subject: MPS -33ALS MBE Treatment Step Unit Operation 1 F Shut in all offset producers. Bullhead water into MPS - 33ALS. 2 F Bullhead treatment down MPS -33ALS (OB sand). Keep well and offset producers and injectors shut in for minimum of 2 days and flow producers to a tank before returning to production if necessary. OBJECTIVE 1. Divert water by sealing the preferential path of injection with a cement acting fluid and a rigid gel. Measure of success 1. Treatments are displaced into formation. 2. Post injection is adequate to achieve injection rate target at below target pressure. 3. Decrease of watercut over time in offset producers is observed. CRITICAL ISSUES • Ensure pumping pressure is not above the fracture gradient. • Ensure cleanliness of pump equipment and hard line (pre and post job) & properly dispose of remnant fluid per guidance from the Environmental Team. Background MPS -33 was drilled and completed as an OA/OB dual string injector in the Schrader Bluff in 2002. MPS -33 supports producers MPS -17 ( -400 bopd), MPS -23 ( -300 bopd), and MPS -25 ( -900 bopd). After nine months of injection the first MBE developed in the OA (short string) to MPS -23. Additional MBE's followed in 2004 and 2005 in the OB (long string) to both MPS -23 and MPS -25. MBE treatments were attempted in 2005 in both the short string and the long string with zero success. A second round of treatments in 2006 had very limited success, lasting less than 2 months. MPS -33 was sidetracked 500 feet away to MPS -33A in 2007. MPS -33A was also completed as a dual string injector in the Schrader Bluff OA/OB. An MBE broke through in the OA (short string) of the newly drilled MPS -33A in only 40 days to MPS -23. The long string was more successful lasting -3 years before breaking though in the OB (long string) to MPS -25. An MBE treatment was performed in the long string (OB) in 2010 lasting 151 days. Currently MPS -23 is online, however MPS -25 is shut in and MPS -17 is choked back due to a lack of injection support in HU 10. Cumulative injection totals combined between MPS -33 and MPS -33A are as follows: OA - 0.656 MMBBL, OB - 1.672 MM BBL. • • PROCEDURE Stage 1. Injection Test 1. RU, hold pre -job safety meeting, PT surface lines 2. Ensure offset producers are SI. 3. Spear in with Methanol, followed by produced water. Attempt to hold injection rate constant while adjusting pressure as needed. 4. Contact Engineering to discuss the injection pressure /rate trends. Once consensus is achieved that the fluid can be successfully placed into formation at acceptable rate /pressure continue with remainder of program. Stage 2. Treatment 5. Ensure offset producers are offline 6. Pump produced water pre -flush followed by cement acting fluid treatment and diesel displacement. Allow setup time. 7. Pump produced water pre -flush followed by high volume gel treatment and diesel over flush. 8. Capture a gel sample at surface and suspend in a warm water bath (to simulate downhole conditions) to monitor actual setting time. 9. Rig down all equipment and hold post -job assessment meeting to capture learnings to be incorporated into future jobs. 10. Forward all post job assessments (w/ all rheology test summary) and continuous pressure and rate data from job to Pad Engineer. 4111 Tree: CON 2 1'16 5N Dual string Weltheartir k 2 IV 5M F alai &Trig MPS-33Ai Orig. KB Elev. = 65.70' Hanger thread 2 Ur EUE top and MT boltorn Orig. GL Elev. = 38.30 2' GIVI-H BPI/ profile 20' k 34' insulated, 215 ft, A-53 1112' NOTE I SNORT STRING IS THE LOWER VALVE I LONG STRMS IS THE HIGHER VAL ON THE TREE ON THE TREE Short String 3001' 2-113- PI P X-NI e 575' . Dore; I I k ; Ell 2 :, (t675 pIg. boneI 3053 KOP a 700" Max hole angle = 45 deg 4 3850 He angle thni pe-rtx = 35 deg I 2200' I 9 561' HOWC0 near Shoe 9 r 40If L-80 OTC Carting IdrM Ia - 8.679, map. .0282 bpfl 7' 26*, L-80, OTC Gran OM Id - 6.151, cap.- 363 bon 2-310 4.7 VA L-00, Ilydrn 563 lotIng IMO - 1.901, cap - CO3E7 tar 2-atr X-Nipple 0_875 pkg bore: I 5c56 I HES I 5056' I 2-3M HES X-Nipple 11 575 pkg. bore', Ell 2-343" Baler 'GT' Rel. "dal pkr I 5i02 I 1.945' 13. I 51 t2 12 HES X14-141pple f1.875 pkg Imre' XM No-Go 1.79r I 5123' I TUbIng /MEG Perforation Summary r n 2-318" Baler "Flr net Mir. I 5170' I 2.41" ID Size Spf Interval (ND) 2-3,15 HES X14-Nlpple (11175' p&g. towel I 5178' I DO..6101116 No-Go 1 .75t 3 3 4 5130' - 515,0 41O6-1l _ULU= 2-321 Et Hydro Trip Sub 3 WE' 4 5ta.9. 5215' 4156 I siez I 7 m uieshoe pup p DT pig, bore' Hydro Trip Sub ELMO I sler I 1.75 Dern, Ball. I 5411 7" HES Float Coltar POTD 549.5 I r i Peat shoe DATE REV. BY COMMENTS MILNE POINT UNIT 11/13/02 J JafteS Wiled by cased Doyen 141 WELL No..: S 12217f02 Lee Huirne Completkin Rig 4E5 API :50 21=7 un. V. Ross Side Tract & Completion Doyon 14 BP EXPLORATION (AK) • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 i ISE ') FEB 2. 4 all Mr. Tom Maunder // Alaska Oil and Gas Conservation Commission a 0(O 17 333 West 7 Avenue 1 3 3 fl Anchorage, Alaska 99501 r Subject: Corrosion Inhibitor Treatments of MPS -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPS -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, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10.404) MPS -Pad 10111/2011 Corrosion Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft pal MPS-01A 2070340 50029231410100 025 NA 0.25 NA 5.1 9/6/2011 MPS-02 2031270 50029231690000 2.5 NA 2.5 NA 23.8 7/30/2011 MPS-03 2021460 50029231050000 Open Flutes - Treated MPS-04 2030520 50029231480000 1.7 NA 1.7 NA 17.0 7/30/2011 MPS-05 2021370 50029231000000 Open Flutes - Treated MPS-06 2031090 50029231630000 1.7 NA 1.7 NA 17.0 7/30/2011 MPS-07 2020720 50029230790000 1 NA 1 NA 13.6 11/3/2009 MPS-08 2031230 50029231680000 1.3 NA 1.3 NA 10.2 7/30/2011 MPS-09 2020200 50029230670000 0.5 NA 0.5 NA 5.1 11/3/2009 MPS -10A 2051250 50029231520100 1.3 NA 1.3 NA 11.9 7/29/2011 MPS -11 2021130 50029230920000 1 NA 1 NA 10.2 7/29/2011 MPS -12 2030230 50029231390000 0.6 NA 0.6 NA 6.8 7/29/2011 MPS -13 2021240 50029230930000 1 NA 1 NA 11.9 11/3/2009 MPS -14 2031040 50029231620000 1.8 NA 1.8 NA 22.1 729/2011 MPS -15 2012450 50029230610000 9.6 NA 9.6 NA 88.4 7/31/2011 MPS -16 2030650 50029231510000 1.2 NA 1.2 NA 10.2 7/29/2011 MPS-17 2021730 50029231150000 Open Flutes - Treated MPS -18 2022420 50029231330000 1.3 NA 1.3 NA 11.9 7/292011 MPS -19A 2022330 50029231210100 1.8 NA 1.8 NA 23.8 7/29/2011 MPS-20 2022410 50029231320000 1.3 NA 1.3 NA 11.9 7/29/2011 MPS -21 2020090 50029230650000 1.8 NA 1.8 NA 22.1 11/3/2009 MPS-22 2031470 50029231760000 9.1 NA 9.1 NA 83.3 7/28/2011 MPS-23 2021320 50029230980000 Open Flutes - Treated MPS -24 2030380 50029231420000 1.3 NA 1.3 NA 10.2 7282011 MPS-25 2021030 50029230890000 Open Flutes - Treated MPS-26 2030610 50029231500000 1 NA 1 NA 8.5 7282011 MPS -27 2020850 50029230840000 0.9 NA 0.9 NA 8.5 7/28/2011 MPS -28 2030940 50029231580000 1.1 NA 1.1 NA 11.9 7/28/2011 MPS -29 2021950 50029231190000 Open Flutes - Treated MPS-30 2022360 50029231310000 1.2 NA 1.2 NA 11.9 7/28/2011 MPS-31 2020140 50029230660000 Open Flutes - Treated MPS-32 2030920 50029231570000 0.8 NA 0.8 NA 6.8 7282011 ---- MPS -33A 2061720 50029231230100 1 NA 1 NA 6.8 728/2011 MPS-34 2031300 50029231710000 6 NA 6 NA 49.3 7/28/2011 MPS-35 2031430 50029231750000 1.2 NA 1.2 NA 11.9 7/28/2011 MPS-37 2070520 50029233550000 13.9 Need top job NA MPS-39 2081830 50029234050000 0.7 NA 0.7 NA 4.3 8/18/2011 MPS-41A 2081610 50029234010100 Sealed NA NA NA NA NA MPS-43 2081760 50029234040000 Dust Cover NA NA NA 6.8 10/11/2011 , MPS -90 2051350 50029232760000 0.6 NA 0.6 NA 3.4 9/6/2011 MPSB-04 500299990799 0.6 NA 0.6 NA 3.4 7/302011 • • SMITE OIF ALASEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Keith Lopez rr�� Petroleum Engineer o ' 119- BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Milne Point Field, Schrader Bluff Oil Pool, MPS -33ASS Sundry Number: 311 -290 Dear Mr. Lopez: � S 4 `Z UV Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair DATED this Z`� day of September, 2011. Encl. STATE OF ALASKA , - � � ALASKA. AND GAS CONSERVATION COMMISSIO 9:029W APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operation Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: MBE TREATMENT El 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 206 -1720 - 3. Address: P.O. Box 196612 Stratigraphic ❑ Service iti , 6. API Number: 0, G Anchorage, AK 99519 -6612 50- 029 - 23123X-00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: - Spacing Exception Required? Yes III No MPS -33ASS 9. Property Designation (Lease Number): 10. Field /Pool(s): ADLO- 380109 - MILNE POINT Field / SCHRADER BLUFF Pool - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 5500 - 4432.09 - 5410 - 4352.04- NONE NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 82' 20" 215.5# A -53 30 112 30 112 Surface 2757' 9 -5/8" 40# L -80 28 2785 28 2527 5750 3090 Production 5470' 7" 26# L -80 26 5496 26 4429 7240 5410 Production Liner Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 0 5130 - 5160 4106.56 - 4132.03 2 -3/8" 4.7# L -80 24 5123 Packers and SSSV Tvoe: 2 -3/8" Baker GT Dual Packer Packers and SSSV MD and ND (ft): 5102 4083 7 X 2.375 Baker FH Ret Packer 5170 4141 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service 0 - 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 10/4/2011 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ 0 - GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact KEITH LOPEZ Printed Name KEITH LOPEZ Title PE Signature � Phone Date 1 564 -5718 9/20/2011 Prepared by Joe Lastufka 564 -4091 % COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 4 gib , ECE vED Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ SEP 6B 6 2 fl1 Other: SEP f! E9 Alaska Oil & Gas Cons. Commission Anchorage Subsequent Form Required: / 0 — go/ APPROVED BY q Approved by: ♦ .. / COMMISSIONER THE COMMISSION Date: 7/2 / / " RBD S SEP3 010 rIr+IAIf1 L AI 9A74 Form 10 -403 Revised 1/2010 l7 I V Submit in Duplicate • • by To: Mark O'Malley /Rob Handy Date: September 20, 2011 MPU Ops Team Leaders From: Keith Lopez, MPU Schrader Pad Engineer 907 - 564 -5718 Subject: MPS -33ASS MBE Treatment Step Unit Operation 1 F Shut in all offset producers. Bullhead water into MPS - 33ASS. 2 F Bullhead treatment down MPS -33ASS (OA_ sand). Keep well and offset producers and injectors shut in for minimum of 2 days and flow producers to a • tank before returning to production if necessary. OBJECTIVE 1. Divert water by sealing the preferential path of injection with a cement acting fluid and a rigid gel. Measure of success 1. Treatments are displaced into formation. 2. Post injection is adequate to achieve injection rate target at below target pressure. 3. Decrease of watercut over time in offset producers is seen. CRITICAL ISSUES • Ensure pumping pressure is not above the fracture gradient. • Ensure cleanliness of pump equipment and hard line (pre and post job) & properly dispose of remnant fluid per guidance from the Environmental Team. Background MPS -33A is a dual completed injector in the OA and OB sands supporting MPS -25 and MPS - 23. This well was sidetracked from MPS -33 due to Matrix Bypass Events that developed in both zones. Both zones re- established their MBE paths in the sidetracked well in a relatively short period of time. The OA zone (SS) has an MBE with MPS -23 and the injectivity in this zone is high enough that no surface pressure is held at target injection rates. The purpose of this treatment is to block the preferential path to decrease injectivity and re- establish matrix water flooding. PROCEDURE Stage 1. Injection Test 1. RU, hold pre -job safety meeting, PT surface lines 2. Ensure offset producers are SI. 3. Spear in with Methanol, followed by produced water. Attempt to hold injection rate constant while adjusting pressure as needed. • • 4. Contact Engineering to discuss the injection pressure /rate trends. Once consensus is achieved that the fluid can be successfully placed into formation at acceptable rate /pressure continue with remainder of program. Stage 2. Treatment 5. Ensure offset producers are offline 6. Pump produced water pre -flush followed by cement acting fluid treatment and diesel displacement. Allow setup time. 7. Pump produced water pre -flush followed by high volume gel treatment and diesel over flush. 8. Capture a gel sample at surface and suspend in a warm water bath (to simulate downhole conditions) to monitor actual setting time. 9. Rig down all equipment and hold post -job assessment meeting to capture !earnings to be incorporated into future jobs. 10. Forward all post job assessments (w/ all rheology test summary) and continuous pressure and rate data from job to Pad Engineer. • Tree C!Vi 2 1 16 Eli Dua sting Wei hies&"1'x 2 3,8"51 /Fi:tualf.rng MPS -33Ai F•:2 = 55 -ranger thread 2 3 ELE top- and IET bcdor — C 1 '3 _ E e r. = sb :J 2' C14Vi -H ERV Droille :.. 2 3' x 34' irstAted. 015 ti A - 5:3 1 11 "NOTE NOT? SHORT STRING 1S THE LOA :ER VALVE LONG STRi'iG 10 THE HIGHER VALVE ON TIE TREE ON THE TREE Short String 3 nng Strinn 3021' 12 -3'3' d=E X- Nipple ii-E7.5• pkg. more I I I X- N,c71e;' E'S" pkg. cored 3023 I KOP 700' Max_ hole angle = 45 deg a 3859' Hole angle thru perfa = 35 deg 1 2270' I 9 5m' HOWCO Floarr. Shoe t f' 40; L -50 5TC Casing 1drttt Ib - 8.674, cap. - .02732 bprf 7' 268, L-53, BTC Casing :drift IS - 6.151, cap.- .2383 tort 2 -3,5 ", 47 #.T L-82, Hytlnl 553 71, r 9Y'd - 1.901, Vii.- .0O3E7 tor, 1 5255' 12-3;5' 1ES X -N pole 1 pkg. core 1 I - - air : 575 pkg. bore; I 52 E6 x 2-15" Baker 'Or Rel. awl pkr. I c I • - =5"17 I 5 1 2 ' I HES XM••Ntppie (1.875' pag beret No -Go 1.79'° I -" I Tubing :al ! WL.EG D A Perforation Summary x 2 -173' Baker Ftf ReL pkr. 1 5170' I 2..01'17. Size Spt Interval (1 Of. s.anK 2 -3d8' HES XH - Nlppk:11.875• pi ;. Oche.) I 517E' 1 ND GO 1.7_ 338' 4 5t30'- 51f3 4106'- 4132' OB samix 2 +E• Eater T aiyt i1 Trip Sub a 1E• 4 517!3 - 52t;3' 4155 -4182 .. Etc. atr room eshae t"up I 12.136' pig. Wei Hydro Trip Sub ELMD 1 51'35' I 1.7E' Dent Ea: I 5:1 I T' HES Float Collar =ETD I = I" -1 E S float Shore A A► DATE ='E'•. B' COME 'ITS 1' 137_ MILNE POINT UNIT Drilled by Cased ? {on 11 WELL No.. S -33iA 2' 1- 2 -,- 1,_; ° Cornpeton Rig 4EC API : 50 - 23123 - - - _ > 0 , de Track a Completion Cc • = BP EXPLORATION {AK) • • siforE o[F ALANKKA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Keith Lopez Petroleum Engineer IA ...rig- g- BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Milne Point Field, Schrader Bluff Oil Pool, MPS -33ALS Sundry Number: 311 -291 Dear Mr. Lopez: SEE? t 2. Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. cy Chair DATED this ? `da of September, 2011. Encl. • • • Page 1 of 1 Schwartz, Guy L (DOA) From: Lastufka, Joseph N (Wipro) [lastufjn @BP.com] Sent: Tuesday, September 27, 2011 9:43 AM To: Schwartz, Guy L (DOA) Cc: Saltmarsh, Arthur C (DOA) Subject: RE: MPS -33A API numbers. Guy, I apologize for not correcting these before sending them out. The -82 and -83 are internal numbers for separating the long and short strings in the well. In the future I will do my best to remember to change both strings to the permitted API number. If you have any additional questions, please don't hesitate to let me know. Thanks!! Joe Lastufka Petrotechnical Data Technologist I Wipro Technologies I T: 907 564 4091 I M: 907 227 8496 Jioseph.lastufka(a wipro.com I Anchorage, AK USA I www.wipro.com From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent: Tuesday, September 27, 2011 9:29 AM To: Lastufka, Joseph N (Wipro) Cc: Saltmarsh, Arthur C (DOA) Subject: MPS -33A API numbers. Joe, I got the MBE sundries for MPS -33A LS and SS . For some reason the API numbers you sent with them 50- 029 - 23123 -82 for the Long string and 50- 029 - 12123 -83 for the short string don't come up in our system. The Commission only recognizes this as one well ... MPS -33A with API number 50- 029 - 23123 -01 since there was only one PTD issued. Give me a call to discuss this. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) 9/27/2011 STATE OF ALASKA CO , � , ,e i � ALASKA OAND GAS CONSERVATION COMMISSION. 9-,?91/ APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate❑ Pull Tubing ❑ Time Extension ❑ Operation Shutdown ❑ Re -enter Susp. Well ❑ Stimulate Alter Casing ❑ Other: MBE TREATMENT is 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 206 -1720 - 3. Address: P.O. Box 196612 Stratigraphic ❑ Service 0 _ 6. API Number: 04 Anchorage, AK 99519 -6612 50- 029 - 231230 - T' g" • /! 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No ❑ MPS -33ALS • 9. Property Designation (Lease Number): 10. Field /Pool(s): ADLO- 380109 MILNE POINT Field / SCHRADER BLUFF Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 5500 - 4432.09 - 5410 - 4352.04 - NONE NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 82' 20" 215.5# A -53 30 112 30 112 Surface 2757' 9 -5/8" 40# L -80 28 2785 28 2527 5750 3090 Production 5470' 7" 26# L -80 26 5496 26 4429 7240 5410 Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): O 5130 - 5160 4106.56 - 4132.03 2 -3/8" 4.7# L -80 25 5185 0 5188 - 5218 4156.15 - 4182.22 Packers and SSSV Tvoe: 2 -3/8" Baker GT Dual Packer Packers and SSSV MD and TVD (ft): 5102 4083 2 -3/8" Baker FH Ret Packer 5170 4141 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service 0 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 10/4/2011 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ , 16. Verbal Approval: Date: WINJ 151 GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Keith Lopez Printed Name Keith Lopez Title PE Signature / Phone Date / %4R 564 -5718 9/20/2011 Prepared by Joe Lastufka 564 -4091 e/ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 i On Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ DECEIVED Other: SEP 2 6 2011 Alaska Oil & Gas Cons. Commission Subsequent Form Required: /0— yQ / ri;IGl t3; iirj(? APPROVED BY Approved by: .. t COMMISSIONER THE COMMISSION Date: /29 // isDM3 SEP 3 0 Nti 7 7L7•" ORIGINAL —. /. Submit in Du Form 10-403 Revised 1/2010 plicate • by 0 To: Mark O'Malley /Rob Handy Date: September 20, 2011 MPU Ops Team Leaders From: Keith Lopez, MPU Schrader Pad Engineer 907- 564 -5718 Subject: MPS -33ALS MBE Treatment Step Unit Operation 1 F Shut in all offset producers. Bullhead water into MPS - 33ALS. 2 F Bullhead treatment down MPS -33ALS (OB sand). Keep well and offset producers and injectors shut in for minimum of 2 days and flow producers to a • tank before returning to production if necessary. OBJECTIVE 1. Divert water by sealing the preferential path of injection with a rigid gel. Measure of success 1. Treatments are displaced into formation. 2. Post injection is adequate to achieve injection rate target at below target pressure. • 3. Decrease of watercut over time in offset producers is seen. CRITICAL ISSUES • Ensure pumping pressure is not above the fracture gradient. • Ensure cleanliness of pump equipment and hard line (pre and post job) & properly dispose of remnant fluid per guidance from the Environmental Team. Background MPS -33A is a dual completed injector in the OA and OB sands supporting MPS -25 and MPS - 23. This well was sidetracked from MPS -33 due to Matrix Bypass Events that developed in both zones. Both zones re- established their MBE paths in the sidetracked well in a relatively short period of time. The OB zone (LS) has an MBE with MPS -25. An MBE treatment was pumped last year on 11/13/10. The purpose of this treatment is to block the preferential path to decrease injectivity and re- establish matrix water flooding. PROCEDURE Stage 1. Injection Test 1. RU, hold pre -job safety meeting, PT surface lines 2. Ensure offset producers are SI. 3. Spear in with Methanol, followed by produced water. Attempt to hold injection rate constant while adjusting pressure as needed. • • 4. Contact Engineering to discuss the injection pressure /rate trends. Once consensus is achieved that the fluid can be successfully placed into formation at acceptable rate /pressure continue with remainder of program. Stage 2. Treatment 5. Ensure offset producers are offline 6. Pump produced water pre -flush followed by high volume gel treatment and diesel over flush. 7. Capture a gel sample at surface and suspend in a warm water bath (to simulate downhole conditions) to monitor actual setting time. 8. Rig down all equipment and hold post job assessment meeting to capture learnings to be incorporated into future jobs. 9. Forward all post job assessments (w/ all rheology test summary) and continuous pressure and rate data from job to Pad Engineer. . • • Tree: SIG 2 1.16' !.%4 Dua sting 4' ,elihead:'1'x236'StJFMC Dual rang MPS-33J .i Orig. KBE,e'v.= 85.741 ranger thread 2 3 EUE top and IBT bo;lonn 1 Or GL E'ev. = 30.20 T C (W -H EPV ,oroflie c'9' x 34' iroti ated. 2 15 *4 A. - 53 1 112 ...NOTE... , 13 __ ' SHORT STRING 15 THE LOWER VALVE LC ;7. 7R1 4G IS THE HIGHER VALVE ON THE TREE s_: ^1 71 -E TREE Short String Long String 1 30:1' I2 -33' HES X- Nlpple 11.875' pkg. or Q -EC X.- Nlpzale it .e 75' pkg. Dore 1 302? I i KOP '?. 700' Max_ hole angle = 45 deg a 3850 Hole angle thru perfo = 35 deg 1 2200' I 9 5.8' HCWCO FIoa4 Shoe ' I 9 5,18` 40tr L-913 BTC Casing idrttt td - 6.679, cap. - .0282 bpi: 7' 268, L-817, OTC Casing :rink ls- 6.151,cap.- :0363Cpri 2 -3 +8`, 4.7 P.11 L-8D, Hydra 563 3ufkng (daft' Id - 1.901, c .- .0O3E7 tiph -_ 12-3M' 1f0 X- Sipple (1.E75' pkg. oore - ® = X.-‘4 pple V . ? ?5' pkg. bore 15:21: . " x 2-2,5* Baker'GT' Ret dual pkr. 15t02 I • 5 -5' I3 1 5112' I2 -3 «B' HES XN- Nlpple [1.875 pkg. bore) No-Go 1.791' 1 5123' I Tubing tat I W LEG Perforation Summary '' x 2-3,8' Baker Ret pkr. 1 5170 I 2.41' 10. Size Spf Interval (1VV13) aA saner 2 -3!8 HES X 4- Nipple ;1.575 pkg. bcrel 1 517E I No-So 1.751 3 aor 4 6130' -5157 4106' -4132' o OB sand& 2 -318' Baker 'E' Hydro Trip Out• lir 4 5188' - 3218' s' 41st° - 41 a' rn uleshe? pup 1 5162' I I ■;2.0C' Dag. Bore) 1 I Hydro Trip Sub ELMD 1 5185' I 541, I 7' HES Float Collar PETG 1.7" Ge rin Bali I f -9f I -_ 1 Float Shoe w ► DATE = E'J.5'• COMMENTS 1111302 J. loner MILNE POINT UNIT Dreier! bye Cased mayor 14' WELL No.: S-33iA 12117,132 .ee Hulrrre Cornp+eton Rig 4ES API : 50 21307 !,i' !1. R.cbs S:de Track a Cen'plellor Gc yr. 1 ' - BP EXPLORATION (AK) • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Monday, March 14, 2011 P.I. Supervisor i --5(7-1 I SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC S -33A FROM: Jeff Jones MILNE PT UNIT SB S -33A Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv't5,— NON-CONFIDENTIAL Comm Well Name: MILNE PT UNIT SB S - 33A API Well Number: 50 029 - 23123 - 01 - 00 Inspector Name: JeffJones Insp Num: mitJJ110314073751 Permit Number: 206 - 172 - Inspection Date: 3/12/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well j S - ' Type Inj. W " TVD 4083 / I IA I 160 1780 - 1750 I 1730 P.T.D 2061720 1TypeTest I SPT Test psi 1500 , OA 30 110 110 110 Interval P/F P - Tubing 800 800 I 800 800 Notes: 1 BBL diesel pumped. 1 well inspected; no exceptions noted. - Monday, March 14, 2011 Page 1 of 1 u • ~~Q~~ 0~ Q~Q~~{Q /.E,.Po,~..~a~.~~ Keith Lopez Wells Engineer BP Exploration (Alaska), Inc. ~„ P.O. Box 196612 Anchorage, AK 99519-6612 ~O Re: Milne Point Field, Schrader Bluff Pool, MPS-33ALS Sundry Number: 310-237 Dear Mr. Lopez: ,~ ~a~a~`c~r~~ ~«i ~~'~~` Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy ~ Foerster Commissioner e DATED this day of August, 2010. Encl. C~~ ~~ STATE OF ALASKA ALAS~L AND GAS CONSERVATION COMMISSI~ APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 0 ~,~ ~~~ 1. Type of Request: Abandon ^ Plug for Redrill ^ Pertorate New Pool^ Repair Well ^ Change Approved Program ^ Suspend ^ Plug Pertorations ^ Perforate ^ Pull Tubing ^ Time Extension ^ Operation Shutdown ^ Re-enter Susp. Well ^ Stimulate^ Alter Casing ^ 0 Other: MBE TREATMENT 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ^ Exploratory ^ 206-1720 3. Address: P.O. Box 196612 Stratigraphic ^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-23123-82-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No ^ MPS-33ALS 9. Property Designation (Lease Number): 10. Field/Pool(s): ADLO-380109 MILNE POINT Field / SCHRADER BLUFF Pool 11 • PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 5500 4432.09 5410 4352 NONE NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 112 20" 215# A-53 SURFACE 112 SURFACE 112 Surtace 2785 9-5/8" 40# L-80 28 2785 28 2527 5750 3090 Intermediate Production 5496 7" 26# L-80 32 5496 32 4429 7240 5410 Liner Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): O 5130 - 5160 4106.56 - 4132.03 2-3/8" 4.7# L-80 SURFACE 5185 O 5188 - 5218 4156.15 - 4182.22 Packers and SSSV Tvoe: 7"X2-3/8" BAKER GT RET DUAL PKR Packers and SSSV MD and ND (ftl: 5102 4083 7"X2-3/8" BAKER FH RET PKR 5170 4141 12. Attachments: Description Summary of Proposal [y~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ^~ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 8/13/2010 Oil ^ Gas ^ WDSPL ^ Suspended ^ 16. Verbal Approval: Date: WINJ ~ GINJ ^ WAG ^ Abandoned ^ Commission Representative: GSTOR ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact KEITH LOPEZ Printed Name KEITH LOPEZ Title WELLS ENGINEER Signature Phone Date 564-5718 7/30/2010 Prepared by Gary Preble 564-4944 COMMISSION USE ONLY Num witness Sund tif i i th t t ti e ma diti f l N C C ber: 3'® ~ ry y omm on so a represen a v y on ons o approva : o ss a C.Y~ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: ~~~i ~'~('°S .~'~E:1 ~! `~ Ll1u~ Subsequent Form Required: 10' N ~~ 418Ska 6~-' ~ X818 ~.~$. C~~IZISS10fl ~,~ri-~~)r~ge APPROVED BY (~ Approved by: COMMISSIONER THE COMMISSION Date: ("~ -~ _ /~ /~l[7~ ~UG Q ~ ~~ Form 10-403 Revised 1/2010 O K 1 ~ 4 fVA L y~. d-v-,~ ~ ~~~~.~~ Submit in Duplicat ~~~~~ e CJ To: Mark O'Malley/Nathan Leonard MPU Well Operations Supervisor From: Keith Lopez, MPU Schrader Pad Engineer Subject: MPS-33ALS MBE Treatment • Date: July 29, 2010 907-564-5718 Step Unit Operation 1 F Shut in all offset producers. Bullhead water into MPS-33ALS. 2 F Bullhead treatment down MPS-33ALS (OB sand). Keep well and offset producers and injectors shut in for minimum of 2 days and flow producers to a tank before returnin to production. OBJECTIVE 1. Divert water by sealing the preferential path of injection with a cement acting fluid and a rigid gel. Measure of success 1. Treatments are fully displaced into formation. 2. Post injection is adequate to achieve injection rate target at below target pressure. ° 3. Decrease of watercut over time in offset producers is seen. CRITICAL ISSUES • Ensure pumping pressure is not above the fracture gradient. • Ensure cleanliness of pump equipment and hard line (pre and post job) & properly dispose of remnant fluid per guidance from the Environmental Team. PROCEDURE Stage 1. Injection Test 1. RU, hold pre-job safety meeting, PT surface lines 2. Ensure offset producers are SI. - 3. Spear in with Methanol, followed by produced water. Attempt to hold injection rate constant while adjusting pressure as needed. 4. Contact Engineering to discuss the injection pressure/rate trends. Once consensus is achieved that the fluid can be successfully placed into formation at acceptable rate/pressure continue with remainder of program. Stage 2. Treatment 5. Ensure offset producers are offline 6. Pump produced water pre-flush followed by cement acting fluid treatment and diesel displacement. Allow setup time. 7. Pump produced water pre-flush followed by high volume gel treatment and diesel over flush. 8. Capture a gel sample at surface and suspend in a warm water bath (to simulate downhole conditions) to monitor actual setting time. 9. Rig down all equipment and hold post job assessment meeting to capture learnings to be incorporated into future jobs. 10. Forward all post job assessments (w/ all rheology test summary) and continuous pressure and rate data from job to Pad Engineer. Tree: ~"a 2 1~16'".~?1+f f7ua{ s~lr~ "4Ve8thE3d:~1' x ~ ~~~' a~ Fli~~ dual sr~ig P~-~3~4-~ t=°arfger it^r=a€~ 2 3eg' ELTE tvp an~i ;@T tc?iam Z' GIld-H f5F5f prr~flle 4 €T x S4" dresukated, ~1E= ~4~ R-F••' 11~° 3G~t1' ~-313' yE5 }4-trbk¢pl¢ f:'1.~'S' pkg. bore ~dri~. KB Elev. = t35.ra7' [3ri~_ ~L Eev. = 30.0' "NOTE'°° tOhdG ~TRIPI~ 15 THE H€~~~^,.aHER tF.A:1'~' ~f4 THE °REE Lor~q 5#~na ~3~!' +iES lC-fv~ple f"f.E,S' pkg. Dare; 30[x? x200' 9 aaa" H~~Wc'CC Ftaa' ~nae 9 513' .*.~? L-~0 6TRC Gas~rg tlr?it ~ - ~,6?'3. cap. - ,G28~ l~p.^,a €;drr?t~ - 6.151. ~~~.- .0363 11tsf'r -3r;3', ~..7 ~7t L-90. Ii5? lubirg Ftlrit fffi - 1.°~ci. cap.-.Of}&97 bpft SC5b' r-3r3• HE.~ X-Npfe t:~:STS" pkg. bare;. 1-3+*3' HES X°9ple ~Y.935° pkg. bare, a'~a"6' ?" x 2-3~~E' i3akar'GT` Rei_ r~ual pkr. 51,Ot' Sts' 2-3.+'HES %4J-NSppfe di.37S`~tg. bbae) Naha 1.~~#' 51 ~a' Tublrg tafr ~' iV'EG ~erfc>rati~un Snmrnary r' x 2-3~~7' Qaker""Fh€' Ret pkr. 5?70' 2.C1'i~. 2-3€B' HES XN-PItFP`~ 11 3?5' ~t~. bcxe) 51??. Ma-~a 1. ~ ~#' 2-3ec3• f3ak+er 'E' -ivs~a Tt9p :SUuG t+!lt tT'<il$P61'rrY2 pup ~ 1$i` Hydro Trip Sut+ E~~I'~1~ 51+35 5e1 'r' HES Fteat Catsar ~'BTD 5196' ~° rES =w~a~~tlag C^.~.TE EL+. f3't~ ti~ia"0~ a .tams *~,`?7+'02 Lee Hutrite .2,"„t'C~' kir Inf. t~G56 Dried by asetl ~Cpan 14t carr~teaar Rig $E~ S=de Track ~ ~a^,mpleila'a Dt~ 1. r 5° C}Hlriri B~€. dtiit6l_d~tdE Pf~r~T uNET VYELL Nt~_: 5-3~i,4 AP : 5U-0t29-23 f 23-01-00 BR EXPL()Ft,4T~t~N (AK) ~~:, ~ _ T ..y~.. ti ~... ~~ ~ ~ ~ ~ ~~ ~, = ~ ' r ~, - ~ .~ N ~r ~~ ~' <+ ;~ ~' 4 `` 3 ~ ~ ~. MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Mazker.doc .3 l~~ DATA SUBMITTAL COMPLIANCE REPORT. 11 /18/2008 Permit to Drill 2061720 Well Name/No. MILNE PT UNIT SB S-33A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23123-01-00 MD 5500 TVD 4432 Completion Date 2/3!2007 Completion Status 1WINJ Current Status 1WINJ _ UIC Y REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: DIR, GR, RES, PWD, NEUlDEN, IFR/CASANDRA, SCMT/CCL, USIT (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Tye Med/Frmt Number Name Scale Media No Start Stop CH Received Comments D D Asc Directional Survey 2756 8305 Open 3/27/2007 14548 ~ement Evaluation 59 5371 Case 3/22/2007 LIS Veri, CET 14548 Cement Evaluation 5 Col 100 5370 Case 3/22/2007 USIT, CCL, GR 31-Jan- 2007 15114~Induction/Resistivity 2629 5497 Open 5/8/2007 LIS Veri, GR, CALA, FET, 15114 LIS Verification 16957VSee Notes Induction/Resistivity Induction/Resistivity Well Cores/Samples Information: Name NPHI, DRHO, RHOB, NCNT, ROP 2629 5497 Open 5/8/2007 LIS Veri, GR, CALA, FET, NPHI, DRHO, RHOB, NCNT,ROP 0 0 9/30/2008 PDF, EMF and CGM for EWR Logs in MD and TVD 25 Col 2792 5500 Open 9/30/2008 MD ROP, DGR, EWR, CTN, ALD, ACAL 25 Col 2532 4432 Open 9/30/2008 TVD DGR, EWR, CTN, ALD, ACAL Sample Interval Set Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 11 /18/2008 Permit to Drill 2061720 Well NamelNo. MILNE PT UNIT SB S-33A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23123-01-00 MD 5500 TVD 4432 Completion Date 2/3/2007 Completion Status 1WINJ Current Status 1WINJ UIC Y ADDITIONAL INFORMATION Well Cored? Y I I~ Daily History Received? ~ N Chips Received? T'17d"' Formation Tops ~ N Analysis Y / N Received? __ __ _ Comments: Compliance Reviewed By: _ ____ - _. _ _ __ Date: I • WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: MPS-33A September 23, 2008 AK-MW-4801118 MPS-33A: 2" x 5" MD Resistivity & Gamma Ray Logs: 1 Color Logs 50-029-23123-O1 2" x 5" TVD Resistivity & Gamma Ray Logs: 1 Color Logs 50-029-23123-01 Digital Log Images: 1 CD Rom 50-029-23123-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date _ Signed: ~-., ~~ ~~, WELL LCIG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs MPS-33A May 3 , 2007 AK-MW-4801118 1 LIS formatted CD with verification Listing. API#:50-029-23123-O1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 ~~. ~. ~: ;~ <, BP Exploration (Alaska) Inc. Petrotechnical Data Center MB33 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Date: ~`~~ ~~~t Signed: t~ has ~~+~~. sdt~r~t ;i~~i~°~, ~¢~~;ar~ ~~~ ~' SOT APR, 0 3 2007 ,~ • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska Oil & Gas Cans. Commission WELL COMPLETION OR RECOMPLETION REPORT AND LOG Anchorage Revision: 04-02-07, Start Injection 1 a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG 20AAC25.105 2oAAC2s.,~o ~~~ ^ GINJ ®WINJ ^ WDSPL No. of Completions Other • ~ 1 b. Well Class: ^ Development ^ Exploratory ^ Stratigraphic ®Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or d. 27372D8a 12. Permit to Drill Number 206-172 3. Address: P.O. Box 196812, Anchorage, Alaska 99519-6612 6. Date Spudded Z 3 •D~ 1/26/2007 ~~ 13. API Number 50-029-23123-01-00 4a. Location of Well (Governmental Section): Surface: ' S ' 7. Date T.D. Reached ~ / • ~ 1/27/2007 14. Well Name and Number: MPS-33Ai ' 3255 F L, 398 FEL, SEC. 12, T12N, R10E, UM Top of Productive Horizon: 2250' FNL, 2970' FEL, SEC. 12, T12N, R10E, UM g. KB Elevation (ft): 72.01- 15. Field /Pool(s): Milne Point Unit / Schrader Bluff Total Depth: 2297 FNL, 3138' FEL, SEC. 12, T12N, R10E, UM 9. Plug Back Depth (MD+TVD) 5410 ~ + 4352 ~ Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 565613 y- 5999921 Zone- ASP4 10. Total Depth (MD+TVD) 5500 ~ + 4432 ~ Ft 16. Property Designation: ADL 380109 TPI: x- 563043 y- 5999673 Zone- ASP4 Total Depth: x- 562875 y- 5999625 Zone- ASP4 11. Depth where SSSV set None MD 17. Land Use Permit: 18. Directional Survey ^ Yes ®No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1800' (Approx.) 21. Logs Run: DIR, GR, RES, PWD, NEU/DEN, IFR/CASANDRA, SCMT/CCL, USIT 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 92# H-40 Surface 112' Surface 112' 42" 260 sx Arctic Set A rox. 9-5/8" 40# L-80 28' 2785' 28' 2527' 12-1/4" 765 sx PF'L' 200 sx Class'G' 7" 26# L-80 32' 54 6' 32' 4429' 8-1/2" 6 x PF'E' 145 sx Cla s " ' 23. Perforations open to Production (MD + TVD of Top and 24. TUBING RECORD Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET MD PACKER SET MD 4-1/2" Gun Diameter, 12 SPF 2-3/8", 4.7#, L-80 5119' 5102' MD TVD MD TVD 2-3/8", 4.6#, L-80 5185' 5170' OA Sands OA Sands 25. ACID, FRaCTURE, _CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT He KIND OF MATERIAL USED 5130' - 5160' 4107' - 4132' 27g2' Top of Window OB Sands OB Sands Freeze Protected with 10 BBLS of McOH 5188' 5218' 4156' 4182' - - 26. PRODUCTION TEST Date First Production: March 23, 2007 Method of Operation (Flowing, Gas Lift, etc.): Water Injection Date of Test Hours Tested PRODUCTION FOR TEST PERIOD OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO FIOW TUbing PreSS. CaSing PreSSUre CALCULATED 24-HOUR RATE OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate shut, if nece, ry). Submit core chips; if none, state "none". F L ~a .- ;~~~ 1 ~ 2007 ~~~~ None ~~1~ .'1`-'J'am Form 10-407 Revised 12/2003 ~ ~j CONTINUED ON REVERSE SIDE ~~]~ l ~` 28. GEOLOGIC MARKS 29. ORMATION TESTS Include and briefly summarize test results. List intervals tested, Na,rwe MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Ugnu MA 4625' 3732' Ugnu MB1 4670' 3763' None Ugnu MB2 4735' 3807' Ugnu MC 4900' 3925' NA 4947' 3961' NB 4972' 3980' NC 5016' 4014' NE 5036' 4030' NF 5091' 4074' Top of OA Sands 5131' 4107' Base of OA Sands 5165' 4136' Top of OB Sands 5186' 4154' Base of OB Sands 5215' 4180' Top of Bd 5342' 4292' Base of Bd 5370' 4317' 30. List of Attachments: Well Work Summary 31. I hereby certify that the fore oing is true and correct to the best of my knowledge. Signed Sondra ewman ~_Title Technical Assistant Dat - - MPS-33Ai 206-172 Prepared By NameMumber. Sondra Stewman, 564-4750 Well Number Permit No. / A royal No. Drilling Engineer: Adrienne McVey, 564-4184 INSTRUCTIONS GeNew-r.: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion.. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: True vertical thickness. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: If no cores taken, indicate "None". IreM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only :' Digital Wellfile • Well Events for SurfaceWell -MPS-33 Location: BP -> ALASKA -> ALASKA CONSOLIDATED TEAM -> MPU -> MPS -> MPS-33 Date Range: 07/Feb/2007 to 02/Apr/2007 Data Source(s): DIMS, AWGRS Page 1 of 1 Events Source Well Date Description AWGRS MPS-33 03/31/2007 LS/SS/IA = 882/580/200. MIT IA to 1600 psi PASSED. (Witnessed by AOGCC, Lou Grimaldi). IA lost 30 psi in the 1st 15 min and 0 psi in the 2nd 15 min. Bled IA to 200 psi. Final WHP's = 882/580/200 AWGRS MPS-33 03/18/2007 (Freeze Protect) T/I/0= 0/0/175 Freeze Protect Tubing with 12 BBLS 60/40 McOH FWHP=0/0/175. AWGRS MPS-33 03/18/2007 *** CONTINUED FROM 03/17/07 *** SWAB »» SHORT STRING «« SWAB 30 GALLONS OF FLUID FROM SHORT STRING. PULL 1.875" FTP FROM 3001' MD. *** WELL LEFT S/I *** AWGRS MPS-33 03/17/2007 T/I/0=0/0/100. (Freeze protect). Freeze protect long string tbg w/ 12 bbls 60/40 meth. FWHP=200/0/100. AWGRS MPS-33 03/17/2007 *** CONTINUED FROM 03-17-07 *** SWAB »» LONG STRING «« MADE A TOTAL OF 6 RUNS.RECOVERED A TOTAL OF 10 GALLONS OF OIL FOR SAMPLE. Pulled flow through plug from the top X nipple. »» SHORT SRING «« MADE A TOTAL OF 19 RUNS.RECOVERED A TOTAL OF 7 GALLONS OF OIL FOR SAMPLE. **** CONTINUE ON 03-18-07 *** AWGRS MPS-33 03/16/2007 SWAB TUBING *** WELL S/I ON ARRIVAL *** «< LONG STRING »> SWAB FLUID DOWN FROM 870' SLM TO 1300' SLM.MADE A TOTAL OF 25 RUNS. *** CONTINUE ON 03-17-07 *** AW.G.RS MPS-33 02/20/2007 ***CONT FROM 2/19/07 *** CHANGE OVER FLANGE TO LONG STRING. RIH W/ 1.70 CENT TEL AND SB LOC TT @ 5170' SLM [12 FT CORR] TAG BOTTOM @ 5393' SLM (5405' CORR DEPTH) RIH W/ 1.77 CENT AND SOFT SET SPARTEK GAUGES 3 HR SBHP @ 5178' MD, SET 1.875 " FTP IN X-NIPPLE @ 2980' SLM, RDMO ***WELL LEFT S/I*** AWGRS MPS-33 02/19/2007 SS/I/0= 0/0/100 MIT-T (Short String) to 3500 psi. ****PASSED**** Pumped 2 bbls 60/40 meth down tbg to pressure up to 3500. 1st 15 min loss of 450 psi. Bumped pressure up with less than .1 bbls. TBG lost 225 psi 1st 15 min, & lost 25 psi 2nd 15 min. Total loss of 250 psi in 30 min. Bled tbg pressure back to 0 psi. FW HP's=0/0/ 100 AWGRS MPS-33 02/19/2007 *** CONTINUE FROM 02-18-07 *** SBHPS »» SHORT STRING «« RIH W/ 1.81" CENT.,S.S,DUAL SPARTEK GAUGES.MADE THIRTY STOP @ 4582' MD & THREE HOUR STOP @ 5114' MD. PULL RHC BODY FROM 5090 SLM SET FTP @ 2980 SLM ]OB COMPLETED ON SHORT STRING ***CONT ON 2/20/07 *** AWGRS MPS-33 02/18/2007 *** BOTH STRINGS S/I ON ARRIVAL *** SWAP FLANGES ON WELL HEAD *** CONTINUE ON 02-19-07 *** AWGRS MPS-33 02/07/2007 Well Support Techs rigged up and set the foundation, flowlines and welllrouse. All flanges were torque to spec. they then rigged up and removed both the BPV'S. The flowlines were leaktested to 3000 psi for 10 minutes. NOTE: The BPV'S were left OUT and the leajk test was GOOD. Refresh List http://digitalwellfile.bpweb.bp.com/W e1lEvents/Home/Default. aspx 4/2/2007 o2i22/2o0~ Schlumberger Alaska Data 8: Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Jnh if ~~~ ~ ~~~ NO. 4158 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay n~~n QI r..l..~ nn MPS-33A 11676926 CH EDIT USIT (PDC-GR) 01/31/07 1 1 W-35 11486088 RST 12/15/06 1 1 J-02B 10964121 RST 01/26/05 1 1 C-36A 11209600 MCNL 04/24/06 1 1 04-38 11477734 RST 12/02/06 1 1 A-05A NIA USIT (CEMENT EVALUATION) 01109/07 1 A-05A 11626272 USIT (CEMENT EVALUATION) 01130/07 1 ~ .-~r+.a~ .~v nlYV VYLGVVC RCliClr l O/ JIV ryIrVV ArYV RCI VRn11 rVV VIVO ~.VYT tAl.r'1 I V: BP Exploration (Alaska) Inc. _ ~ ~ Petrotechnical Data Center LR2-1 I •-,~~ ~~ ~~~ 900 E. Benson Blvd. P~ Anchorage, Alaska 99508 tt Date Delivered: II~~R ~ o:I ~QCI~ \(~ afar 1~i~ ~t ~ AZ ~ (, 6t6I'. (.,:(lt"f1!'ilI a~lfaf"1 !'~P1flif3Y'<~1fj Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth l t~ I ~' Received by: C~ ~~ ~ ~~ s.~~ STATE OF ALASKA MAR 0 2 Z0~7 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LA~ska Oii & Gas Cons. Commission Anchorage 1a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG zoAa,czs.,os zoAACZS.,,o ^ GINJ ®WINJ ^ WDSPL No. of Completions Other 1b. Well Class: ^ Development ^ Exploratory ^ Stratigraphic ®Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Ab d. 2/3!2007 ~.~~~ 12. Permit to Drill Number 206-172 ~ 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 1/26/2007 ' 13. API Number 50-029-23123-01-00 ~ 4a. Location of Well (Governmental Section): Surface: ' ' ~ 7. Date T.D. Reached 1/27/2007 ` 14. Well Name and Number: MPS-33Ai ' 3255 FSL, 398 FEL, SEC. 12, T12N, R10E, UM Top of Productive Horizon: 2250' FNL, 2970' FEL, SEC. 12, T12N, R10E, UM 8. KB Elevation (ft): 72.01 15. Field /Pool(s): Milne Point Unit / Schrader Bluff Total Depth: 2297 FNL, 3138' FEL, SEC. 12, T12N, R10E, UM 9. Plug Back Depth (MD+TVD) 5410 + 4352 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 565613 ' y- 5999921 ~ Zone- ASP4 10. Total Depth (MD+TVD) ~ 5500 + 4432 ^ Ft 16. Property Designation: ADL 380109 TPI: x- 563043 y- 5999673 Zone- ASP4 Total Depth: x- 562875: y- 5999625 ~ Zone- ASP4 11. Depth where SSSV set None MD 17. Land Use Permit: 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1800' (Approx.) 21. Logs Run: L/i~YGo~/ o? 79~~lD ~s3,g ~7YD e DIR, GR, RES, PWD, NEUlDEN, IFR/CASANDRA, SCMT/CCL, USIT 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD :.HOLE AMOUNT SIZE WTc PER FT. " GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD .PULLED 20" 92# H-40 Surface 112' Surface 112' 42" 260 sx Arctic Set A rox. 9-5/8" 40# L-80 28' 2785' 28' 2527' 12-1/4" 765 sx PF'L' 200 sx Class'G' 7" 26# L-80 32' 5496' 32' 4429' 8-1/2" 65 sx PF'E' 145 sx Class "G' 23. Perforations open to Production (MD + TVD of Top and 24. TUBING RECORD Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET MD PACKER SET MD 4-1/2" Gun Diameter, 12 SPF 2-3/8", 4.7#, L-80 5119' 5102' MD TVD MD TVD 2-3/8", 4.6#, L-80 5185' 5170' OA Sands OA Sands 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 5130' - 5160' 4107' - 4132' 27g2' Top of Window OB Sands OB Sands Freeze Protected with 10 BBLS of McOH 5 i 88' 5218' 415 2' ' - - 418 6 26. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): NIA Date of Test Hours Tested PRODUCTION FOR TEST PERIOD OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO FIOW TUbing PreSS. CaSing PreSSUre CALCULATED 24-HOUR RATE OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". ~ ~~~'' ` - ~: ~ ~~i:3 ~+~ A None ,, s ~~ ~r~~ ~ ~ 20Q~ ~ RiFI~U ` Form 10-407 Revised 12/2003 ~ ^ ~ ~ ~ ~ ~(~,~TINUED ON REVERSE SIDE ~'~,, ,.~~.... ~~~~ *28 GEOLOGIC MARKS 29. ORMATION TESTS Include and briefly summarize test results. List intervals tested, NAMe MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Ugnu MA 4625' 3732' Ugnu M61 4670' 3763' None Ugnu M62 4735` 3807 Ugnu MC 4900' 3925' NA 494T 3961' N B 4972' 3980' NC 5016' 4014' N E 5036' 4030' N F 5091' 4074' Top of OA Sands 5131' 4107' Base of OA Sands 5165' 4136' Top of OB Sands 5186' 4154' Base of OB Sands 5215' 4180' Top of Bd 5342' 4292' Base of Bd 5370' 4317' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys and aLeak-Off Test Summary. 31. I hereby certify that th fo reg i e o ng is true and correct to the best of my knowledge. `~ `,, ~ ~ ~~",: ~ Signed Sondra Stea ; Title Technical Assistant Date ~) 'Ci I `( _. MPS-33Ai 206-172 Prepared By Name/Number. Sondra Stewman, 564-4750 Well Number Permit No. / A royal No. Driving Engineer: Adrienne McVey, 564-4184 INSTRUCTIONS GeNeRn~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Irene 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: True vertical thickness. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". IreM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only Tree: CIW 2 1116" 5M Dual stn Wellhead:i 1" x 2 3/8" 5M FMC ual string Hanger thread 2 3/8" EUE top and IBT 2" CIW-H BPV profile 20" x 34" insulated, 215 #!ft A-53 3001' 2-3/8" HES X-Nipple (1.875' KOP C«~ 700` Max. hole angle = 45 deg @ ; Hole angle thru perfs = 35 deg ~' 9 5/8" HOWCO Float Shoi 9 5/8" 40# L-80 BTRC Casinc (drift id = 8.679, cap. _ .0282 7" 26#, L-80, BTRC Casing (drift id = 6.151, cap.= .0383 2-3/8", 4.7 #/ft L-80, IBT tubi, (drift id = 1.901, cap.=.00387 5056` 2-3/8" HES X-Nipple (1.875' 5112' 2-3/8" HES XN-Nipple (1.87 No 5123' Tubing tail / WLEG Perforation Summa Size Spf Interval -~Z ~ a, OA sands '9'~8' 4 5130` - 5160' 41 ~1 2 t a OB sands ~-3fi3` ~ 5188' - 5218' 41 5411' 7" HES Float Collar PBTD 5496' 7" HES Float Shoe DATE REV. BY 11/13/02 J. Jones 12/17/02 Lee Hulme 11/13/02 Mr. M. Ross COMMENTS Drilled by Cased Doyon 141 Completion Rig 4ES Side Track & Completion Doyon 14 Orig. KB Elev. = 65.70` Orig. GL Elev. = 38.20` ~8" HES X-Nipple (1.875" pkg. bore) 3003' 3" HES X-Nipple (1.875" pkg. bore) 5056' ' x 2-3/8" Baker "GT" Ret. dual pkr. 5102' 945"ID. 3/8" Baker "FH" Ret. pkr. 5170' D. HES XN-Nipple (1.875" pkg. bore) 5178' No-Go 1.791" Baker'E' Hydro Trip Sub leshoe pup 5182' " pkg. bore) Hydro Trip Sub ELMD 5185' 75" Delrin Ball. MILNE POINT UNIT WELL No.: 5-33iA API : 50-029-23123-01-00 BP EXPLORATION (AK) MPS-33iA BP Operations Summary Report Legal Well Name: MPS-33 Common Well Name: MPS-33 Event Name: REENTER+COMPLETE Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date From - To Hours i Task ~ Code NPT 1/17/2007 17:00 - 18:00 ~ 1.00 ~ RIGD ~ P 18:00 - 19:00 1.00 RIGD P 19:00 - 20:00 1.00 MOB P 20:00 - 00:00 4.00 MOB P 1/18/2007 00:00 - 03:00 3.00 MOB P 03:00 - 14:00 11.00 MOB P 14:00 - 18:00 4.00 RIGU P 18:00 - 20:00 2.00 RIGU P 20:00 - 00:00 4.00 RIGU P 1/19/2007 00:00 - 01:00 1.00 WHSUR P 01:00 - 02:30 1.50 WHSUR P 02:30 - 03:00 0.50 WHSUR P 03:00 - 06:00 3.00 WHSUR P 06:00 - 06:30 0.50 WHSUR P 06:30 - 07:00 0.50 WHSUR P 07:00 - 09:30 2.50 WHSUR P 09:30 - 12:00 I 2.501 WHSUR I P 12:00 - 13:30 1.50 WHSUR P 13:30-21:30 8.00 WHSUR P 21:30 - 22:00 0.50 WHSUR N 22:00 - 00:00 2.00 WHSUR N 1/20/2007 00:00 - 03:30 3.50 WHSUR N 03:30 - 04:30 1.00 WHSUR N 04:30 - 05:30 1.00 WHSUR N 05:30 - 10:00 4.50 WHSUR P 10:00 - 10:30 0.50 WHSUR P 10:30-15:00 4.50 WHSUR P 15:00 - 15:30 0.50 PULL P 15:30 - 17:30 2.00 PULL P 17:30 - 23:30 I 6.001 PULL I N Start: 1 /16/2007 Rig Release: 2/3/2007 Rig Number: 14 Page 1 of 8 'I Spud Date: 10/26/2002 End: 2/3/2007 Phase Description of Operations POST RD rockwasher -Remove doors -Remove cellar heaters -Prep rig for move POST Skid rig floor from drlg position to move position PRE Move rig off well MPF-99i to center of pad PRE Install front booster frame, install front and rear boosters for move from F-pad to S-pad PRE Repair rear drive motor leak PRE Move rig from MPF-Pad to MPS-Pad PRE Remove rear boosters -Install cellar heaters /doors -Remove front boosters /frame -Install stairs -Hang tree in cellar PRE PJSM -Spot rig over well MPS-33A -Shim rig -Skid rig floor from move to drlg position PRE Slide conveyor out -Spot rock washer -Berm same - RU rig floor -Prepare pits to take on seawater -Install augar -Get steam, water circulating DECOMP Con'r RU circulating lines to tiger tank DECOMP PU lubricator - RU to tree -Pull BPV's - RD - LD lubricator DECOMP Test lines with air -Confirm all lines /valves open DECOMP PJSM -Pump 25 bbls down short string -Pump 40 bbls Safe-Sur-O pill down long string -Pump 180 bbls 100 degree seawater -Shut down 20 mins -Pump additional 25 bbls - 4 bpm @ 1150 psi DECOMP Blow down lines to tiger tank -Choke - RD lines to tiger tank - Tree DECOMP Dry rod in TWC with FMC -Test to 1000 psi from below DECOMP RD test equipment -Blow down injection line -Vac out tree - Install tree lift cap - ND tree /adapter -Check threads on tubing hangers 2 3/8" 8rd -Threads good DECOMP NU BOP -Riser - Flowline -Choke line -Double annulus valve DECOMP PJSM -Change out top rams to 2 3/8" Dual block DECOMP RU test equipment -Test BOP -Test Blinds - Choke manifold, 4" Floor safety valves -HCR Kill /Manual Kill - Upper /Lower IBOP - to 250 psi low ! 3000 psi high - 5 mins. each test -Record on chart -Good -Attempt to test Annular - No Test RREP DECOMP RD test equipment -Blow down choke manifold - RREP DECOMP ND Flow line /riser and riser adapter flange RREP DECOMP Change out Annular element RREP DECOMP Nipple up riser -Flow line RREP DECOMP RU test equipment DECOMP Test Annular - 2 3/8" Dual rams -HCR choke -Manual Choke - 2 3/8" Floor Safety valves -Dart valves - 250 low - 3000 high - 5 mins each test DECOMP RD testing equipment -Blow down choke /kill DECOMP Suck out stack for pulling TWC's - RU lubricator -Pull TWC's - RD lubricator - LD same DECOMP PJSM - RU GBR 2 3/8" Dual equipment DECOMP MU Landing joints -BOLDS -Attempt to pull dual strings -Pull 70K over block weight - No sucess -Work strings separatley w/ 70k over- Not free DPRB DECOMP RU circulating lines -Circulate well heating up fluid for chemical cut on Dual strings -While waiting on Schlumberger Printed: 2/5/2007 7:06:28 AM BP Operations Summary Report Page2of8~ (Legal Well Name: MPS-33 Common Well Name: MPS-33 Spud Date: 10/26/2002 .Event Name: REENTER+COMPLETE Start: 1/16/2007 End: 2/3/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 2/3/2007 j Rig Name: DOYON 14 Rig Number: 14 Date ~ From - To~ours Task Code~NPT I Phase Description of Operations 1/20/2007 23:30 - 00:00 0.50 PULL N DPRB DECOMP Pull to 20K on both strings 30% over string weight 1/21/2007 00:00 - 00:30 0.50 PULL N DPRB DECOMP Circulate hot seawater down tubing to increase temp to 80 00:30 - 03:00 I 2.501 PULL I N 03:00 - 05:00 I 2.001 PULL I N 05:00 - 07:30 I 2.501 PULL I N 07:30 - 10:00 I 2.501 PULL I N 10:00 - 12:00 I 2.001 PULL I N 12:00 - 14:00 2.00 PULL N 14:00 - 18:30 4.50 PULL N 18:30 - 19:30 I 1.001 PULL I P 19:30 - 23:00 3.50 PULL P 23:00 - 00:00 1.00 PULL P 11/22/2007 100:00 - 04:00 I 4.001 PULL I P 04:00 - 05:00 ~ 1.00 ~ PULL ~ P 05:00 - 06:00 1.00 PULL P 06:00 - 07:30 1.50 BOPSU P 07:30 - 08:00 0.50 PULL P 08:00 - 11:00 3.00 PULL P 11:00 - 11:30 0.50 PULL P 11:30 - 13:30 2.00 PULL P 13:30 - 14:00 0.50 PULL P 14:00 - 16:30 2.50 PULL P 16:30 - 17:30 1.00 PULL P 17:30 - 19:00 1.50 PULL P 19:00 - 19:30 0.50 PULL P 19:30 - 21:30 I 2.001 PULL I P degree -GPM 106 - PP 315 DPRB DECOMP RU Schlumberger E-line equipment - Con't circulating down short string -GPM 106 - PP 310 DPRB DECOMP RIH with string shot in long side -Set down 3290 WLD -Set CCL 3264' -String shot fired from 3267' to 3239' - POH with tools - LD String shot DPRB DECOMP PJSM (Chemical cutter) -Load chemcial cutter - MU and PU Chemical cutter (Continue to circulate warm seawater). DPRB DECOMP RIH in Long side w/ chemical cutter -Spot C.C. at 3273' & fire same -Good indication - POH -Good shot DPRB DECOMP LD C.C. - RD circ. head from short side - RD pack-off from long side - PU on long side to ensure pipe cut -Pipe free w/ 70k up wt. DPRB DECOMP RU to circ. on long side - RU for wireline on short side - Circ. seawater and RIH w/ string shot on short side -Fire string shot from 3254'-3266' - POH - LD String shot DPRB DECOMP PJSM - MU Chemical cutter - Rlh on short side spot CCL ~ 3243' -Fire chemical cutter C~ 3260' -Good indication - POH - RD Schlumberger DECOMP PJSM -Pull hangers to rig floor -PUW 75K (Block wt + 25K) - LD Hangers, Landing joints, -Change elevators - RU power tongs DECOMP POH -Lay down long string 1 x 1 - (Total laid down 103 jts + cut off 20.59' - 3 pup joints - 1 X Nipple) DECOMP Rig down dual elevators -Dual slips and associated running equipment -Clear rig floor of all dual equipment /tools - prepare to LD short string DECOMP LD short string - (103 joints + 1 cut joint 5.62' - 4 pup joints 1 X Nipple) DECOMP RD power tongs -Change elevators -Bails -Break XO's to 2 3/8" safety valves -Clear floor of all dual string /tubing equipment DECOMP Install test plug -Change out dual rams to 2 7/8" X 5" VBR's DECOMP Test Accumulator -Top 2 7/8" X 5" - Btm 3 1/2" X 6" VBR's - 250 low 3000 high - 5 mins each test -Pull test plug -Install wear ring DECOMP MU BHA DECOMP RIH - PU 4" DP 1 x 1 from pipe shed -Tag top of tubing 3273' DECOMP CBU 2 X -GPM 380 - PP 1530 - No Rotation -PUW 95 -SOW 90 DECOMP PJSM - POH to BHA DECOMP LD BHA -Jars -Bit sub -Scraper -Bit -Clear rig floor - Moblize Howco EZSV to rig floor DECOMP MU EZSV - Con't RIH to 2968' -Set EZSV -Shear off 136K DECOMP CBU 1 X -GPM 385 - PP 780 -Blow down - RU test equipment - Test to 3000 psi for 15 mins -Recorded on chart -Test good - RD test equipment -Blow down lines DECOMP POH - LD Howco running tool -Clear rig flor DECOMP MU Baker Multi-String cutter dressed for 7" 26# casing - Stablizer - XO DECOMP RIH with cutter to 2906' -Picking up 51 joints 4" DP from pipe Printed: 2/5/2007 7:06:28 AM BP Page 3 of 8 Operations Summary Report Legal Well Name: MPS-33 Common Well Name: MPS-33 Event Name: REENTER+COMPLETE Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date From - To Hours Task ,' Code 1/22/2007 19:30 - 21:30 2.00 PULL P 21:30 - 22:00 0.50 PULL P Start: 1 /16/2007 Rig Release: 2/3/2007 Rig Number: 14 Spud Date: 10!26/2002 End: 2/3/2007 22:00 - 22:30 I 0.501 PULL I P 22:30 - 00:00 I 1.501 PULL I P 1/23/2007 I - 01:00 I 1.001 PULL I P 01:00 - 02:00 I 1.001 PULL I P 02:00 - 03:00 I 1.001 PULL I P 03:00 - 05:00 I 2.001 BOPSUFi P 05:00 - 06:00 1.00 PULL ~ P 06:00 - 08:00 2.00 BOPSU P 08:00 - 09:30 1.50 PULL P 09:30 - 10:00 0.50 PULL P 10:00 - 10:30 I 0.501 PULL I P 10:30 - 12:00 I 1.501 PULL I P 12:00 - 13:30 1.50 PULL P 13:30 - 15:00 1.50 BOPSU P 15:00 - 17:00 I 2.001 PULL I P NPT Phase ~ Description of Operations DECOMP shed -PJSM - DECOMP PJSM -Locate collar ~ 2907' -Pull up 20' to 2887' -PUW 90 - SOW 85 - ROTW 88 DECOMP Cut 7" L-80 26# casing -RPM 40 - TO 2 to 5 -GPM 152 - PP 560 DECOMP Close rams -Open OA valve -Reported returns to tiger tank - Pump 37 bbls Safe-Sur O - 71 bbls seawater -bpm 3.5 @ 1300 psi -Notified that very little returns coming back -Slowed pump to 2 bpm @ 1000 psi -Checked return line to tiger tank from OA valve -Shut down -Well flowed back 6 to 7 bbls seawater in 30 mins -Then decreased to 2 bbls next 25 mins - Cftanged return line from tiger tank to injection line -Lined up to rock washer -Attempt to pump down Dp taking returns to Rock washer -Pumped 1 bpm for 2.5 bbls @ 700 psi no retruns -Shut down pump DECOMP Open rams - CBU 1.5 X - 3 bpm @ 320 psi - 6 bpm @ 1300 psi - No Losses on btms up DECOMP Attempt to pump down OA - Taking returns up 7" -Pump 1 bpm -Pressure increased to 1200 psi -Pumped 1.3 bbls total - Shut down -Pressure bled off to 1100 psi in 20 mins -Bleed off pressure - DECOMP POH with Baker Multi-String cutter -Hole took correct hole fill on trip out - LD baker tools DECOMP Pull wear ring -Install test plug -Change top VBR's to 7" casing rams - RU test equipment -Test door seals to 1500 psi for 5 mins - RD testing equipment -Pull test plug DECOMP MU 7" casing spear - LD spear in 1 piece in pipe shed (Decision was made to cut casing again). DECOMP Install test plug -Change top rams to 2 7/8" x 5" variables - Test door seals to 1500 psi -Pull test plug -Install wear ring. DECOMP PU Multi-string cutter - RIH to 2758' DECOMP Screw in T.D. -Obtain parameters -Break circulation w/ 29 spm 310 psi -Locate casing collar at 2786' - PU and spot knives at 2771' -PJSM on cutting casing and circulating out freeze protect DECOMP Cut 7' casing w/ 40 rpm 1 k tq - 43 spm 700 psi -Observe 200 psi pressure drop -Increase pump rate to 54 spm 770 psi - Casing cut out - 200 psi pressure on "OA" -Continue rotating 10 min. DECOMP Close annular -Open line to slop tank -Returns to slop tank w/ no pump -Pump 8 bbls seawater to establish good circulation - Pump 35 bbl "Safe Surf O" pill -Chase w/ warm seawater - Initial pump press. 2.5 bpm 500 psi -Increase rate to 3.5 bpm 850 psi -Final circulating pressure = 1040 psi 3.3 bpm -Total volume pumped = 190 bbls -Total recovery in slop tank = 190 bbls -Open choke - No pressure observed -Open annular - Observe well - OK -Break circulation -Slack off and tag cut at 2771' DECOMP PJSM -Flow check - POH - LD M.S. cutter assembly DECOMP PJSM -Pull wear ring -Install test plug -Change top rams to 4 1/2" x 7" -Test door seals to 1500 psi - RD test equip. DECOMP PJSM -Make up 7" spear -engage hanger -BOLDS -Pull casing to rig floor -PUW 110 -Release from spear - LD spear - Printed: 2/5/2007 7:06:28 AM ~ ~ BP Operations Summary Report Legal Well Name: MPS-33 Common Well Name: MPS-33 Event Name: REENTER+COMPLETE Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date j From - To ! Hours ~ Task ~ Code NPT -1 - - 1/23/2007 15:00 - 17:00 2.00 PULL P 17:00 - 21:00 4.00 PULL P 21:00 - 23:30 I 2.501 BOPSUR P 23:30 - 00:00 1 /24/2007 00:00 - 01:30 01:30 - 02:30 02:30 - 03:30 03:30 - 04:30 0.501 PULL I P 1.50 PULL P 1.00 PULL P 1.00 PULL P 1.00 PULL P 04:30 - 06:00 06:00 - 07:30 07:30 - 08:30 08:30 - 09:30 09:30 - 10:00 10:00 - 11:00 11:00 - 11:30 11:30 - 13:30 13:30 - 14:30 14:30 - 16:00 16:00 - 17:00 17:00 - 18:00 18:00 - 20:00 20:00 - 21:00 21:00 - 22:00 22:00 - 23:00 23:00 - 00:00 1.50 PULL P 1.50 PULL P 1.00 PULL P 1.00 PULL P 0.50 PULL P 1.00 PULL P 0.50 PULL P 2.00 PULL P 1.00 PULL P 1.50 PULL P 1.00 STCTPL P 1,00 STCTPL P 2.00 STCTPL P 1.00 STCTPL P 1.00 STCTPL P 1.00 I STCTPL I P 1.00 I STCTPL I P Page 4 of 8 I Spud Date: 10/26/2002 Start: 1 /16/2007 End: 2/3/2007 Rig Release: 2/3/2007 Rig Number: 14 Phase ~ Description of Operations DECOMP RU casing equipment - LD hanger - MU safety valve DECOMP PJSM - LD 7" casing -Total laid down 67 joints + cut joint 25,00' - RD casing equiment DECOMP PJSM -Install test plug -Change out 7" casing rams to 2 7/8" x 5" VBR's -Test to 250 low 3000 high - 5 mins each test - Record on chart - RD testing equipment -Install wear ring DECOMP Moblize BHA to rig floor -Change out handling equipment to 5" DECOMP MU 7" Spear Assy - PU 19 joints 5" HW DP - 1 x 1 from pipe shed DECOMP RIH from 624' to top of 7" casing stub @ 2771' - PUW 105 - SOW 95 DECOMP Latch fish -Jar on fish -Jar 200K over string weight (hit 25 times) -Working string weight up to 425K -Holding 700 psi on pump (3 bbis pumped away) -Fish free -Pull up into 9 5/8" shoe - DECOMP CBU -Reciprocating string full 90' -BPM 7 - PP 500 - (Cement contaminated fluid back on bottoms up) DECOMP Monitor well - POH with fish DECOMP Stand back HWDP - LD BHA - LD 7" casing -Recovered 2 jts + 2 cut jts. (16.10' & 22.06') DECOMP Clear rig floor of BHA & casing equip. -Mobilize BHA to floor DECOMP MU cleanout BHA -RIH to 9 5/8" shoe at 2792' DECOMP Screw in T.D. -Obtain parameters -Wash down & tag EZSV at 2968' DECOMP Pump H.V sweep around - 440 gpm 870 psi - 60 rpm 1 k tq. DECOMP Pump out to shoe w/ 440 gpm DECOMP Change swivel packing on Top Drive DECOMP POH f/ 2766' to 206' DECOMP LD 4 3/4" DC's & BHA -Clear floor of tools /equipment WEXIT PJSM - RU to PU 3 1/2" cmt string - PU Cmt string -Change handling tools WEXIT RIH to 2792' WEXIT Break circulation -Circulate while waiting on water for cement job -GPM 390 PP 590 -Blow down Top Drive WEXIT Con't RIH from 2792' to 2968' -Tag EZSV plug - RU cement line -Break circulation -CBU -BPM 390 - PP 800 -Give to Dowell Schlumberger WEXIT Pump 5 bbls water - 4 bpm Cam? 275 Pressure test lines to 2500 Pump 17 bbis water - 4 bpm Q 275 Pump 27.5 bbis Class G Cement 17ppg -Yield 1.0 - 4.5 bpm C~ 550 Pump 3 bbls water - 2 bpm 150 Give to rig - Displace with 21 bbis seawater - (cut displacement short 3 bblsj - 7 bpm 130 / 5 bpm 300 Cement in place 21:30 Hrs - RD cement head -Cement lines WEXIT Pull 8 stands -Install wiper ball -Pump 25 bbl nut plug - Followed by 140 bbis seawater - 12 bpm @ 800 - (Trace cement back) WEXIT POH with 4" DP - RU power tongs -Handling tools - LD 3 1/2" cement string Printed: 2/5/2007 7:06:28 AM gp Page 5 of 8 Operations Summary Report Legal Well Name: MPS-33 Common Well Name: MPS-33 Spud Date: 10/26/2002 Event Name: REENTER+COMPLETE Start: 1/16/2007 End: 2/3/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 2/3/2007 Rig Name: DOYON 14 Rig Number: 14 Date From - To IL Hours Task ~ Code ~ NPT Phase Description of Operations __ - _ ~ L--- _~_~__ - -- M M~ 1/25/2007 00:00 - 01:00 1.00 STCTPL P WEXIT LD 3 1/2" cement string 01:00 - 02:30 1.50 STCTPL P WEXIT RD tubing equipment -Clear floor of all equipment /tools - Moblize BHA to rig floor 02:30 - 05:00 2.50 STCTPL P WEXIT PJSM - MU BHA - 8 1/2" bit, 1.5 deg. bent housing motor - MWD (DIR/GR/RES/NEU/DEN and Geo Tap) 05:00 - 07:00 2.00 STCTPL P WEXIT Upload MWD -Surface test MWD w/ 470 gpm 860 psi 07:00 - 19:00 12.00 STCTPL P WEXIT Wait on cement -Change out hydraulic line under rig floor - 19:00 - 23:00 23:00 - 23:30 23:30 - 00:00 1/26/2007 00:00 - 03:30 4.00 STCTPL P 0.50 STCTPL P 0.50 STCTPL P 3.50 STCTPL P 03:30 - 04:00 0.50 STCTPL P 3 ~ 04:00 - 05:00 1.00 STCTPL P , ~~[[ ~~ ~ 05:00 - 10:00 5.00 STCTPL P 10:00 - 10:30 0.50 EVAL P ~~ ~ 10:30 - 00:00 13.50 DRILL P 1/27/2007 100:00 - 00:00 I 24.00 DRILL P 1/28/2007 00:00 - 02:00 2.00 DRILL P 02:00 - 04:30 2.50 DRILL P 04:30 - 05:30 1.00 DRILL P 05:30 - 07:00 1.50 DRILL P 07:00 - 08:30 1.50 DRILL P 08:30 - 10:30 2.00 DRILL P 10:30 - 11:00 0.50 DRILL P 11:00 - 22:00 11.00 EVAL P Charge Top Drive accumulator -Clean pits & prep for LSND mud WEXIT Up load MWD -PJSM -Load nukes - Con't MU BHA - DC's - HW DP -Jars - HW DP WEXIT RIH with BHA to 2200' WEXIT Break circulation -GPM 420 - PP 1150 - (23:30 hrs 1000 psi compressive strength) WEXIT RIH from 2200 to 2540' -Tag cement stringers - PU -Break circulation -Wash from 2540 to 2552' -Tag firm cement - taking 5 to 10K -Drill cement from 2560 to 2575' -Tag hard cement -Taking 15 to 20K -Drill hard cemet from 2575' to 2792'-GPM420-PP1420-RPM 40-T04K-W0B10to' ~ 15K WEXIT CBU -GPM 420 - PP 1450 WEXIT Displace seawater to 8.8 ppg LSND -Pump 30 bbl spacer - Followed with 8.8 ppg LSND -GPM 450 - PP 1200 -RPM 40 - TO 4 WEXIT KO -Time drill from 2792' to 2833' -GPM 450 - PP 1000 - WOB2to5K ~- W EXIT FIT - TMD 2792 - TVD 2533 - MW 8.9 ppg -Surface pressure 540 = 13 EMW PROD1 Directional Drill from 2833' to 4122' - WOB 10 to 15 -RPM 80 - TOon6-offs-GPM590-PPon 2430-off 2310-PUW 235- SOW 101 - ROTW 115 -ECD 9.8 PROD1 ° :4irectional Drill 8 1/2" hole from 4122' to T.D: @ 5500' - WOB 15-RPM80-TQon6-off6-GPM530-PPon2970-off 2750 -PUW 130 -SOW 106 - ROTW 130 -ECD 9.96 PROD1 CBU4X-GPM530-PP2750-RPM 80-T06K-PUW 130- SOW 106 - ROTW 130 -ECD 10 PROD1 Pump to shoe @ drlg rate -From 5500' to 2785' -Pack off 4220 to 4180 -Slight pack-off 4085' -Tight spot @ 2895 40 overpull -Run back through tight spot no problem -Pull back through same spot 40 over - Con't POH to 2768' no other problems PROD1 CBU 2 X -GPM 550 - PP 2140 -ECD 10 -Clay balls with some coal back on bottoms up -Took 3.5 bottoms up to clean up hole PRODi Cut Drig line -Rig Service -Top Drive Service @ 9 5/8" casing shoe PROD1 RIH to total depth @ 5500' - No hole problems encountered - PUW 180 -SOW 110 - ROTW 130 - ECD 10 PROD1 Circulate hole clean /condition mud -GPM 530 - PP 2970 PROD1 Pump out to 5235' /Geo-Tap sensor depth @ 5133' -GPM 500 - PP 2820 -ECD 9.86 PROD1 Geo-Tap readings starting ~ 5133' to 5455' then from 5038' to 5138'-RIH to 5413' Printed: 2/5/2007 7:06:28 AM BP Operations Summary Report Legal Well Name: MPS-33 Common Well Name: MPS-33 Event Name: REENTER+COMPLETE Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date ~ From - To Hours Task Code --- 1 /28/2007 ~ 22:00 - 00:00 2.00 CASE ~ P 1/29/2007 00:00 - 00:30 0.50 CASE P PROD1 00:30 - 02:30 2.00 CASE P PROD1 02:30 - 03:30 1.00 CASE P PROD1 03:30 - 04:30 1.00 CASE P PROD1 04:30 - 10:00 5.50 CASE P PROD1 10:00 - 10:30 0.50 CASE P PRODi 10:30 - 11:30 1.00 BOPSU P PROD1 11:30 - 13:00 1.50 CASE P PROD1 13:00 - 18:00 5.00 CASE P PROD1 18:00 - 18:30 0.50 CASE P PROD1 18:30 - 22:00 3.50 CASE P PROD1 22:00 - 00:00 I 2.001 CASE I P I I PROD1 1/30/2007 02:00 - 03:30 1.50 CEMT P I PROD1 I PROD1 03:30 - 04:30 1.00 CEMT P PROD1 04:30 - 05:30 1.00 CEMT P PROD1 05:30 - 10:30 5.00 CASE P PROD1 10:30 - 11:30 ~ 1.00 ~ BOPSUFI P ~ ~ PROD1 11:30 - 13:00 1.50 BOPSU~ P PROD1 13:00 - 15:00 2.00 BOPSU P PROD1 Start: 1 /16/2007 Rig Release: 2/3/2007 Rig Number: 14 Page6of8~ Spud Date: 10/26/2002 End: 2/3/2007 Description of Operations Precauctionary wash from 5413' to 5500' -CBU 4 X -GPM 530 -PP 2975-RPM 80-T06.5 -PUW 180-SOW 110-ROTW 135 -ECD 9.87 CBU 1 X-GPM530-PP2950-RPM 80-T06.5-POW 180- SOW 110 - ROTW 135 -ECD 9.8 Flow check -Well static -Pump out from 5500 to 2768' @ drilling rate CBU 2 X -GPM 520 - PP 2000 -RPM 70 - TO 2K -Flow check 10 mins -Well static - Pumpdry job - POH from 2768' to 771' PJSM - LD BHA -Down load Nukes / MW D Clear rig floor of all tools Pull wear ring -Install test plug -Change top VBR's 2 7/8" x 5" to 4 1/2" x 7" VBR's -Test door seals to 1500 PJSM - RU 7" casing equipment PU float equipment -Check floats - PU /Run 7" casing to 2792' Circulate casing volume -BPM 5 - PP 500 Con't PU /Run 7" casing from 2792' to 5500' -Break circulation -CBU-BPM5-PP 520-PUW 195-SOW 120 Break out 19' pup jt. - LD Franks fill up tool - MU XO 7" BTC-M Box X 7" TC11 Pin - MU Cemeting head /lines -Break circulation -BPM 5 - PP 500 Circulate /Condition mud for Cement job -BPM 5 - PP 520 - PUW -SOW Give to Schlumberger Dowell Pump 10 bbls water - 3 bpm @ 230 Test lines to 4000 psi Pump 25 bbls Mud Push mixed at 10.4 ppg - 3.5 bpm @ 340 Kick out bottom plug Pump 5 bbls Mud Push mixed @ 10.4 ppg - 2.5 bpm @ 270 Mix and pump 26 bbls Lead (Crete Design mixed @ 12.5 ppg 65 sxs -Yield 2.24 - 5 bpm @ 130 Mix and pump 30 bbls Tail (Class 'G") mixed @ 15.8 ppg 145 sxs -Yield 1.17 - 4 bpm @ 90 Shut down - Open up wash down line -Wash out cement line - Close bypass valve Give to rig Kick out BTM plug Pump 30 bbls pert pill - 7 bpm @ 130 174 bbls seawater - 5.5 bpm @ 300 3 bbls seawater - 2.3 bpm @ 650 Bump plug with 3300 psi -BTM O-Ring in btm of head leaking - Bleed off to 1000 psi -Pump back to 1500 held for 10 mins - Bleed off pressure -Floats holding - CIP 03:30 hrs Flush stack with water -Drain stack - Slowdown lines ND Riser -Flow line -Choke hose - BOP's Set emergency slips with 200K -Cut landing joint -Install packoff and test to 4300 psi for 30 minutes N/U BOPE -Pump 30 bbls mud down backside @ 105 GPM @ 650 psi Change top rams to 2 3/8" dual rams Install test plug -Test break on BOP stack and choke line to 250 psi low, 3000 psi high for 5 minutes each (good test) -Pull NPT Phase IPRODI Printed: 2/5/2007 7:06:28 AM BP Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 1 /30/2007 13:00 - 15:00 15:00 - 19:30 19:30 - 21:00 MPS-33 MPS-33 REENTER+COMPLETE DOYON DRILLING INC. DOYON 14 Hours I Task I Code 2.00 BOPSU P 4.50 EVAL P 1.50 EVAL P Start: 1 /16/2007 Rig Release: 2/3/2007 Rig Number: 14 NPT ~-Phase PROD1 PROD1 PROD1 21:00 - 23:00 2.00 EVAL P PROD1 23:00 - 00:00 1.00 EVAL P PROD1 1/31/2007 00:00 - 03:00 3.00 EVAL P PROD1 03:00 - 05:00 2.00 EVAL P PROD1 05:00 - 08:00 3.00 EVAL P PROD1 08:00 - 09:00 1.00 EVAL P PROD1 09:00 - 10:30 1.50 EVAL P PROD1 10:30 - 11:00 0.50 EVAL P PROD1 11:00 - 12:00 1.00 EVAL P PROD1 12:00 - 13:00 1.00 EVAL P PROD1 13:00 - 18;00 5.00 EVAL P PROD1 18:00 - 00:00 6.00 EVAL P PROD1 2/1/2007 100:00 - 06:30 I 6.501 EVAL I N I WAIT I PROD1 06:30 - 08:00 I 1.501 RUNCON7P I I RUNCMP 08:00 - 09:30 I 1.501 RUNCON~ I I RUNCMP 09:30 - 10:00 0.50 BUNCO RUNCMP 10:00 - 10:30 0.50 BUNCO P RUNCMP 10:30 - 00:00 13.50 BUNCO P RUNCMP 2/2/2007 00:00 - 00:30 0.50 BUNCO P RUNCMP 00:30 - 01:30 1.00 BUNCO P RUNCMP 01:30 - 04:00 2.50 BUNCO P RUNCMP 04:00 - 04:30 0.50 BUNCO RUNCMP 04:30 - 06:30 2.00 BUNCO RUNCMP 06:30 - 08:30 I 2.001 RUNCONIP I I RUNCMP 08:30 - 09:30 ~ 1.00 ~ RUNCOI~yIP I RUNCMP 09:30 - 10:30 I 1.001 RUNCOAVIP I I RUNCMP 10:30 - 13:00 2.50 BUNCO DFAL RUNCMP 13:00 - 16:00 3.00 BUNCO DFAL RUNCMP 16:00 - 17:00 1.00 BUNCO DFAL RUNCMP Page 7 of 8 Spud Date: 10/26/2002 End: 2/3/2007 Description of Operations test plug -Install wear ring PJSM - UD DP from derrick in mousehole PJSM - R/U and test 7" casing to 3500 psi for 30 minutes (good test) Spot SWS -PJSM w/SWS - R/U to log Run GR/USIT/CCL logs Continue run GR/USIT/CCL with SWS UD USIT logs and M/U perf guns RIH w/perf guns on E-line - Perf from 5188' to 5218' - (4 1/2" HSD powerjet 4512, HMX, 12 spf guns at 135/45 degree phasing) UD guns -All guns fired - P/U guns for 2nd run RIH w/perf guns on E-line - Perf from 5130' to 5160' - (4 1/2" HSD powerjet 4512, HMX, 12 spf guns at 135/45 degree phasing) UD guns -All guns fired - M/U junk basket and 6.0" guage ring RIH with junk baskeUgauge ring to 5398' UD junk baskeUguage ring - R/D SWS Monitor well -Stand by waiting on weather Phase 3 conditions -Monitor well -Review and update procedures Phase 3 conditions -Monitor well -Review and update procedures Mobilize dual string casing equipment to rig floor -Swap tubing joints in pipeshed to equalize lengths Pull wear ring -Install test plug - R/U dual string test joint and test top rams to 250 psi low, 3000 psi high for 5 minutes each R/U 2 3/8" dual string tubing equipment Make dummy run with dual string hanger Run 2 3/8" 4.7# dual string tubing Continue run 2 3/8" 4.7# dual string tubing Space out - M/U hanger -Land tubing - RILD's R/U SWS E-line -Run GRlCCL logs and confirm packer depths - R/D SWS R/D GBR tubing equipment R/U -Pump 80 bbls inhibited seawater ~ 3 BPM, 550 psi, then 58 bls diesel @ 1.7 BPM, 750 psi down annulus taking returns out short string for freeze proect Drop ball on long string -Pump 2.4 BPM ~ 1250 psi to seat ball -Pressure up to 2500 psi and hold for 5 minutes to set packers -Open short string and annulus -Pressure up to 3000 psi on long string for 30 minutes (good test) -Pressure to 3500 psi for 30 minutes (good test) -Pressure up to 3900 psi and shear hydro-trip sub (pressure bled off to 750 psi) -Bled off pressure Pressure up on 2 3/8" X 7" annulus with Hot Oil to 3500 psi for 30 minutes (good test) -Bleed off pressure Drop rod and ball down short string -Attempt pressure up to 3000 psi (failed) Wait on SWS slickline unit Spot and R/U SWS slickline unit RIH with wireline to retrieve ball & rod (no success) - C/O retrieval tool Printed: 2/5/2007 7:06:28 AM • ! BP Page 8 of 8 ~ Operations Summary Report Legal Well Name: MPS-33 Common Well Name: MPS-33 Spud Date: 10/26/2002 Event Name: REENTER+COMPLETE Start: 1/16/2007 End: 2/3/2007 Contractor Name: DOYON DRILLING INC. Rig Release: 2/3/2007 Rig Name: DOYON 14 Rig Number: 14 Date I! From - To ', Hours Task ; Code j NPT i L i Phase 'I Description of Operations ~ 2/2/2007 17:00 - 17:30 _ _ 0.50 BUNCO DFAL RUNCMP RIH with wireline and retrieve ball & rod 17:30 - 18:00 0.50 BUNCO DFAL RUNCMP Bullhead 10 bbls seawater down short side (1100 psi, 2 BPM) 18:00 - 18:30 0.50 BUNCO DFAL RUNCMP R/D SWS wireline equipment 18:30 - 19:30 1.00 BUNCO RUNCMP R/D pump in lines - UD landing joints -Vacuum water from BOP stack 19:30 - 20:30 1.00 BUNCO RUNCMP Set TWC's -Pressure test from top to 1000 psi for 10 min 20:30 - 22:30 2.00 BUNCO P RUNCMP N/D BOP stack 22:30 - 00:00 1.50 BUNCO P RUNCMP N/U adapter flange and tree 2/3/2007 00:00 - 00:30 0.50 W HSUR P RUNCMP Continue N/U adapter & tree 00:30 - 01:30 1.00 WHSUR P RUNCMP Test adaptor flange to 5000 psi for 10 minutes (good test) - Test tree long and short sides to 5000 psi for 10 minutes each (good test) 01:30 - 03:00 1.50 WHSUR P RUNCMP P/U lubricator -Pull TWC's -Set BPV's 03:00 - 04:00 1.00 WHSUR P RUNCMP R/U Hot Oil -Pump 10 bbls methenol /water down each side (long string = 1150 psi @ 1 bpm, short string = 950 psi @ 1 bpm) 04:00 - 05:00 1.00 WHSUR P RUNCMP Secure well -Release rig @ 0500 hours Printed: 2/5/2007 7:06:28 AM BP Leak-Off Test Summary Legal Name: MPS-33 Common Name: MPS-33 Test Date Test Type _ ~ Test Depth (TMD) Test Depth (ND~ AMW _~ __ _ _-- _ ------ 10/29/2002 FIT 2,795.0 (ft) 2,532.0 (ft) 9.00 (ppg) 1/26/2007 FIT 2,792.0 (ft) 2,533.0 (ft) 8.90 (ppg) Page 1 of 1 Surface Pressu a eak Off Pressure (BHP) EMW _- - 330 (psi) 1,514 (psi) 11.51 (ppg) 540 (psi) 1,711 (psi) 13.00 (ppg) • Printed: 2/5/2007 7:06:23 AM Halliburton Company Survey Report Company: BP AMOCO Date: 2/19/2007 Time: 11:11:03 Page: 1 ', Field: Milne Point Co-ordinate(NE) Reference: WeII: MPS-33, True North ~i Site: M Pt S Pad Well: MPS-33 Vertical (TVD) Reference: MPS-33A: 72.0 Section (VS) Reference: WeII (O.OON,O.OOE,264.34Azi) Wellpath: MPS-33A Survey Calculation Method: Minimum Curvature Db: Oracle Field: Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 19 27 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Well: MPS-33 Slot Name: Well Position: +N/-S -50.64 ft Northing: 5999920.86 ft Latitude: 70 24 36.830 N +E/-W -732.54 ft Easting : 565613.01 ft Longitude: 149 27 56.642 W Position Uncertainty: 0.00 ft Wellpath: MPS-33A Drilled From: MPS-33 500292312301 Tie-on Depth: 2756.89 ft Current Datum: MPS-33A: Height 72.01 ft Above System Datum: Mean Sea Level Magnetic Data: 1 /19/2006 Declination: 24.17 deg Field Strength: 57608 nT Mag Dip Angle: 80.89 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 33.81 0.00 0.00 264.34 Survey Program for DeSnitive Wellpath Date: 1/3/2007 Validated: No Version: 6 Actual From To Survey Toolcode Tool Name ft ft 185.31 185.31 MPS-33 GYRO (185.31-185.31) (1 CB-GYRO-SS Camera based gyro single shots 325.74 2756.89 MPS-33 IFR (325.74-5227.52) (1 MWD+IFR+MS MWD +IFR + Multi Station 2793.87 5436.40 MPS-33A IIFR+MS+Sag (2793.87-5 MWD+IFR+MS MWD +IFR + Multi Station Survey f I biD Intl Azim TVD Sys TVD N/S E/W AIapN MapE Tool ft deg deg ft ft ft ft ft ft 33.81 0.00 0.00 33.81 -38.20 0.00 0.00 5999920.86 565613.01 TIE LINE 185.31 0.41 326.00 185.31 113.30 0.45 -0.30 5999921.31 565612.70 CB-GYRO-SS 325.74 0.31 352.46 325.74 253.73 1.24 -0.63 5999922.10 565612.37 MWD+IFR+MS 416.13 0.22 351.28 416.13 344.12 1.66 -0.69 5999922.51 565612.30 MWD+IFR+MS 505.48 0.06 327.07 505.47 433.46 1.87 -0.74 5999922.72 565612.25 MWD+IFR+MS 596.35 0.31 305.09 596.34 524.33 2.05 -0.97 5999922.90 565612.02 MWD+IFR+MS 685.52 1.00 269.99 685.51 613.50 2.19 -1.95 5999923.03 565611.04 MWD+IFR+MS 781.18 3.07 275.29 781.10 709.09 2.42 -5.33 5999923.23 565607.66 MWD+IFR+MS 873.57 4.94 284.68 873.26 801.25 3.66 -11.64 5999924.41 565601.34 MWD+IFR+MS 966.72 8.49 286.66 965.76 893.75 6.65 -22.11 5999927.31 565590.84 MWD+IFR+MS 1061.36 12.69 279.66 1058.77 986.76 10.40 -39.06 5999930.91 565573.86 MWD+IFR+MS 1155.94 14.56 281.08 1150.69 1078.68 14.42 -60.97 5999934.75 565551.92 MWD+IFR+MS 1252.64 15.41 278.88 1244.10 1172.09 18.74 -85.60 5999938.85 565527.26 MWD+IFR+MS 1347.39 20.31 274.22 1334.26 1262,25 21.90 -114.45 5999941.75 565498.38 MWD+IFR+MS 1438.78 25.30 267.35 1418.49 1346.48 22.16 -149.81 5999941.70 565463.03 MWD+IFR+MS 1534.39 24.33 271.07 1505.28 1433.27 21.59 -189.91 5999940.77 565422.94 MWD+IFR+MS 1625.25 24.99 273.37 1587.85 1515.84 23.06 -227.78 5999941.92 565385.05 MWD+IFR+MS 1719.36 23.44 272.97 1673.68 1601.67 25.20 -266.32 5999943.72 565346.50 MWD+IFR+MS 1812.21 25.26 277.49 1758.28 1686.27 28.74 -304.41 5999946.92 565308.38 MWD+IFR+MS 1904.45 25.89 277.71 1841.48 1769.47 34.01 -343.88 5999951.84 565268.87 MWD+IFR+MS 1998.54 29.14 279.33 1924.91 1852.90 40.48 -386.86 5999957.94 565225.85 MWD+IFR+MS 2092.62 34.07 281.24 2005.02 1933.01 49.34 -435.34 5999966.37 565177.30 MWD+IFR+MS 2185.11 35.52 278.89 2080.97 2008.96 58.54 -487.30 5999975.11 565125.26 MWD+IFR+MS 2279.11 37.98 281.14 2156.29 2084.28 68.35 -542.66 5999984.43 565069.82 MWD+IFR+MS 2371.30 41.19 278.12 2227.33 2155.32 78.12 -600.57 5999993.69 565011.83 MWD+IFR+MS 2463.84 41.95 277.82 2296.57 2224.56 86.63 -661.38 6000001.67 564950.96 MWD+IFR+MS 2559.11 44.04 276.90 2366.25 2294.24 94.95 -725.81 6000009.42 564886.47 MWD+IFR+MS 2654.39 43.65 278.29 2434.96 2362.95 ]03.67 -791.23 6000017.56 564820.98 MWD+IFR+MS 6 Halliburton Com an P Y Survey Report Company: BP AmoCO Field: Milne Point Site: M Pt S Pad Well: MPS-33 Wellpath: MPS-33A Survey Mll Incl ft deg im deg _ TVll ft s TVD ft Date: 2/19/2007 Time: 11:11:03 Pagc: 2 Co-ordinate(NE)Reference: Well: MPS-33, True North Vertical (TVD) Reference_ MPS-33A: 72.0 Section (VS) Reference: Well (O.OON,O.OOE,264.34Azi) Survey Calculation Method: Minimum Curvature Db: Oracle _- - - N/S E1W lYlapN MapE Tool ft ft ft ft 2756.89 45.84 276.86 2507.76 2435.75 113.16 -862.75 6000026.43 564749.38 MWD+IFR+MS 2793.87 45.63 274.82 2533.58 '' 2461.57 115.85 -889.09 6000028.89 564723.02 MWD+IFR+MS 2825.91 46.67 273.07 2555.77 2483.76 117.44 -912.14 6000030.27 564699.96 MWD+IFR+MS 2921.34 49.10 267.90 2619.79 2547.78 117.98 -982.88 6000030.19 564629.23 MWD+IFR+MS 2983.41 51.00 264.63 2659.65 2587.64 114.86 -1030.34 6000026.65 564581.80 MWD+IFR+MS 3076.98 47.19 259.54 2720.93 2648.92 105.22 -1100.34 6000016.40 564511.89 MWD+IFR+MS 3170.65 45.94 259.52 2785.33 2713.32 92.86 -1167.23 6000003.45 564445.12 MWD+IFR+MS 3266.47 46.26 259.50 2851.77 2779.76 80.29 -1235.12 5999990.29 564377.35 MWD+IFR+MS 3360.21 48.46 258.58 2915.27 2843.26 67.17 -1302.81 5999976.58 564309.78 MWD+IFR+MS 3456.06 49.05 258.51 2978.46 2906.45 52.86 -1373.44 5999961.65 564239.28 MWD+IFR+MS 3550.64 50.81 257.46 3039.34 2967.33 37.78 -1444.23 5999945.95 564168.64 MWD+IFR+MS 3644.46 50.34 256.22 3098.93 3026.92 21.29 -1514.80 5999928.84 564098.23 MWD+IFR+MS 3737.91 49.94 255.92 3158.82 3086.81 4.02 -1584.42 5999910.96 564028.77 MWD+IFR+MS 3833.12 49.75 255.71 3220.22 3148.21 -13.81 -1654.97 5999892.51 563958.38 MWD+IFR+MS 3928.46 49.28 256.76 3282.12 3210.11 -31.07 -1725.40 5999874.64 563888.11 MWD+IFR+MS 4024.99 49.50 256.72 3344.95 3272.94 -47.88 -1796.73 5999857.21 563816.94 MWD+IFR+MS 4120.24 50.34 256.34 3406.27 3334.26 -64.86 -1867.60 5999839.61 563746.23 MWD+IFR+MS 4214.43 49.69 256.05 3466.80 3394.79 -82.08 -1937.69 5999821.77 563676.30 MWD+IFR+MS 4309.45 50.44 255.93 3527.79 3455.78 -99.71 -2008.38 5999803.52 563605.78 MWD+IFR+MS 4404.75 50.16 257.37 3588.67 3516,66 -116.65 -2079.72 5999785.96 563534.60 MWD+IFR+MS 4500.21 49.34 257.44 3650.35 3578.34 -132.53 -2150.82 5999769.45 563463.64 MWD+IFR+MS 4595.01 48.64 257.32 3712.56 3640.55 -148.16 -2220.63 5999753.21 563393.98 MWD+IFR+MS 4687.47 47.05 256.79 3774.61 3702.60 -163.51 -2287.43 5999737.28 563327.33 MWD+IFR+MS 4783.03 45.26 256.86 3840.80 3768.79 -179.22 -2354.53 5999720.98 563260.37 MWD+IFR+MS 4879.67 42.59 256.89 3910.40 3838.39 -194.44 -2419.81 5999705.19 563195.23 MWD+IFR+MS 4975.14 39.79 258.45 3982.24 3910.23 -207.89 -2481.22 5999691.20 563133.95 MWD+IFR+MS 5069.04 36.11 259.31 4056.27 3984.26 -219.04 -2537.87 5999679.55 563077.41 MWD+IFR+MS 5162.48 30.90 256.64 4134.16 4062.15 -229.70 -2588.30 5999668.45 563027.07 MWD+IFR+MS 5258.58 27.95 255.13 4217.86 4145.85 -241.19 -2634.09 5999656.57 562981.39 MWD+IFR+MS 5352.89 27.50 254.40 4301.34 4229.33 -252.71 -2676.42 5999644.67 562939.16 MWD+IFR+MS 5436.40 27.19 253.18 4375.52 4303.51 -263.42 -2713.26 5999633.64 562902.43 MWD+IFR+MS 5500.00 27.19 253.18 4432.09 ~ 4360.08 -271.83 -2741.07 5999624.99 i 562874.69 ~ PROJECTED to TD ~ r 22-Feb-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPS-33A Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 2,756.89' MD Window /Kickoff Survey 2,793.87' MD (if applicable) Projected Survey: 8,305.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date c~7 /W~1 7 Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) a a G - /?Z _. SARAH PALIN, GO ERNO ALASKA OIL C11 V ~ VAJ 333 W. 7"' AVENtiE, SUITE t00 ANCHORAGE, ALASKA 99501-3539 CONSERVATION COMMISSION ;' PHONE (907)279-1433 FAX (907j 276-75423 Dan Kara Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Kuparuk River Field, Milne Point Unit, Schrader Bluff Oil Pool, MPS-33Ai BP Exploration (Alaska) Inc. Permit No: 206-172 Surface Location: 3255' FSL, 398' FEL, SEC. 12, T12N, R10E, UM Bottomhole Location: 2274' FNL, 3067' FEL, SEC. 12, T12N, R10E, UM Dear Mr. Kara: Enclosed is the approved application for permit to redrill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). DATED this~J day of December, 2006 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~E~Elvtu - STATE OF ALASKA ~~LAS~A ~6AND GAS CONSERVATION COMMI N Alaska Oil & Gas Cons. Coml>~is~i MIT TO DRILL ~{ 20 AAC 25.005 V `Schrader Bluff OA/OB Dual Injector 1 a. Type of work ^ Drill ®Redrill ~ ^ Re-Entry 1 b. Current el ss ^ Exploratory ^ Development Gas ®Service ^ Multiple Zone ^ Stratigraphic Test ^ Development Oil ^ Single Zone 1 c. Specify if well is proposed for: ^ Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 • 11. Well Name and Number: MPS-33Ai ' 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 5353 TVD 4311 - 12. Field /Pool(s): Milne Point Unit / Schrader Bluff 4a. Location of Well (Governmental Section): Surface: 3255' FSL 398' FEL SEC 12 T12N R10E UM 7. Property Designation: ADL 380109 - , , . , , , Top of Productive Horizon: 2248' FNL, 2954' FEL, SEC. 12, T12N, R10E, UM 8. Land Use Permit: 13. Approximate Spud Date: January 3, 2007 Total Depth: 2274' FNL, 3067' FEL, SEC. 12, T12N, R10E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 3025' 4b. Location of Well (State Base Plane Coordinates): Surface: x-565613 y-5999921 ~ Zone-ASP4 10. KB Elevation (Height above GL): 65.7 feet 15. Distance to Nearest Well Within Pool: 1175' away from MPS-23 16. Deviated Wells: Kickoff Depth: 2800 feet Maximum Hole An le: 49.5 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 1929 ' Surface: 1517 18. asin Pr ram: S e ~ catio n To -' ' ttih' De om ntit of em nt c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 8-1/2" 7" 26# L-80 TCII/BTC-M 5353' Surface Surface 5353' 4310' 112 sx LiteCrete 122 sx Cla s 'G' 19. PRESE NT=WELL CONDITION SUMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 5280 Total Depth TVD (ft): Plugs (measured): 4368 None Effective Depth MD (ft): 5190 Effective Depth TVD (ft): 4295 Junk (measured): 5190' asing Length Size ement Volume MD D Conductor /Structural 112' 20" 260 sx Arctic Set A rox. 112' 112' Surface 2757' 9-5/8" 765 sx PF'L' 200 sx Class'G' 2785' 2525' Intermediate Pr c i n 524 ' 7" 50 sx PF 'E' 16 sx Clas 527 ' 4364' Liner Perforation Depth MD (ft): 4980' - 5065' Perforation Depth TVD (ft): 4122' - 4192' 20. Attachments ~ Filing Fee, $100 ^ BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Adrienne McVey, 564-4184 Printed Name Dan Kara Title Senior Drilling Engineer Prepared By Name/Number: Si nature ~ I't-l ~~o o Phone 564-5667 Date Sondra Stewman, 564-4750 Commission Use Onl Permit To Drill Number: ~~~ l7 API Number: 50-029-23123-01-00 Permit Approval See cover letter for Date: other re uiremen s Conditions of Approval: ~-~s If box is checked, well may not be used to explore for, test, or produce coalbed me~th/sre, gas hydrates, or gas contained shales: ~/ µ~ ~ ~r C~MCcr~~ C~vCx~~p Samples Req'd: ^ Yes ~,Jv No Mud Log Req'd: ,^,/Yes L+f No °~ HZS Measures: ^ Yes [v]~N irectional Survey Req'd: L~J Yes ^ No l ~©C ~C-S~ CAS ~Cl~l~1I~C_ ~ r-~ Other: ~ ~~ o-~.t.~-~ O Pccc'~~~o ~-S ~ a~c~cC~ ~ C~ ~ ~ ~~~ APPROVED BY THE COMMISSION Date f - ~ j` ,COMMISSIONER Form 10-401 Revised 12/20D5 Submit n Duplicate J ~ t Y ~ ~ iz•i3•oL (?,~''~~C~,' Milne Point Well MPS-33A Schrader OA/OB Dual Injector Drilling and Completion Plan Summary Type of Well: Schrader Bluff OA/OB Dual Injector Surface Location: 2,024' FNL and 398' FEL (AS BUllt) Section 12, T12N, R10E UM ' E = 565,613' N = 5,999,921' Top OA 2,248' FNL and 2,954' FEL Section 12, T12N, R10E UM E = 563,059' N = 5,999,675' Z = 4,110' TVD TOp OB 2,255' FNL and 2,984' FEL Section 12, T12N, R10E UM E = 563,029' N = 5,999,668' Z = 4,162' TVD TD 2,274' FNL and 3,067' FEL Section 12, T12N, R10E UM E = 562,946' N = 5,999,649' Z = 4,310' TVD Distance to Propert line 3025' Distance to nearest well 1175' from MPS-23 Estimated Start Date: 3r January, 2007 TMD: 5,353 ~ TVD: 4,311 Max Inc: 49.5° KOP: 2800' - KBE: 65.7' Well Desi n: Ultra Slimhole Ob'ective: Schrader Bluff OA/OB Maximum anticipated BHP: 1929 psi at 4,122' TVDss (OB Sand) Maximum surface pressure: 1517 psi (Based on a full column of gas at 0.1 psi/ft) Planned BOP Test ressure: 3000 psi • Mud Program • 8-1/2" Intermediate/Production Hole (2.785' - 5.353'1: LSND MD Density pp PV YP pH ~ API Filtrate MBT 2785'-4948' 8.8-9.3 8-14 18-26 9.0-10.0 6-8 <25 4948'-5353' 9.3 - 9.6 14 - 18 18 - 26 9.0 - 10.0 6 - 8 < 25 Casing/Tubing Program Hole Size Casing Size Wt/Ft Grade Conn Length Top MD Top TVD Bottom MD Bottom TVD 8.5 7 26.0 L-80 TCII 3900 0 0 3900 3260 8.5 7 26.0 L-80 BTC-M 1453 3900 3260 5353 4310 - 2-3/8 4.7 L-80 563 5122 0 0 5122 4110 - 2-3/8 4.7 L-80 563 5182 0 0 5182 4162 Cement Program Casing Size 7", 26#, L-80, TCII/BTC-M Production Casing Basis Tail cement = 500' MD above the TUZC. 40% excess over gauge hole. Total Cement Volume: 85.4 bbl Wash 5 bbl water 10 bbl CW 100 S acer 30 bbl of MudPush Lead 30.2 bbl, 112 sx LiteCRETE mixed at 12.5 & 1.52 ft /sx Tail 25.2 bbl, 122 sx "G" mixed at 15.8 Ib/ al & 1.17 ft /sx Tem BHST =80°F from SOR Evaluation Program 8-1/2" Section Open Hole: DIR/GR/RES • PWD • GeoTap • NEU/DEN - • IFR/CASANDRA • InSite/InterACT Cased Hole: GR/SCMT/CCL PDC mode • Formation Markers Formation Tops TMD ft TVDss ft BHP si Surface Pressure Gradient psi/ft EMW Ib/ al BPRF 1750 760 585 0.434 8.35 TUZC 4329 3473 1508 1161 0.434 8.35 U nu-MB1 4683 3703 1608 1238 0.434 8.35 U nu-MB2 4742 3744 1626 1251 0.434 8.35 U nu-MC 4915 3873 1682 1294 0.434 8.35 SBF2-NA 4948 3899 1825 1435 0.468 9.00 SBF1-NB 4987 3930 1839 1446 0.468 9.00 SBE4-NC 5012 3951 1849 1454 0.468 9.00 SBE2-NE 5029 3965 1856 1459 0.468 9.00 SBE1-NF 5085 4012 1878 1476 0.468 9.00 TSBD-To OA 5122 4044 1893 1488 0.468 9.00 TSBC-Base OA 5151 4069 1904 1497 0.468 9.00 TSBB-To OB 5182 4096 1917 1507 0.468 9.00 SBA5 -Base OB 5212 4122 1929 - 1517 0.468 9.00 Recommended Bit Program Hole Size Depth (TMD) Footage Bit Type TFA GPM 8-1/2 2,785' - 5,353 2,568' Hughes Christensen MXL-1 .50-.70 500-600 Well Control Intermediate/Production Hole • Maximum anticipated BHP: • Maximum surface pressure: • Planned BOP test pressure: • Integrity tests: Kick tolerance: • Planned completion fluid: 1929 psi at 4,122' TVDss (OB Sand) ~ 1517 psi at (Based on a full column of gas at 0.1 psi/ft) 3,000 psi FIT to 12.0 Ib/gal 20' below the 9-5/8" shoe. 33 bbls with 9.4 Ib/gal mud at the 9-5/8" shoe. Kill weight brine (9.3 ppg) with diesel cap. Drilling Hazards & Contingencies Lost Circulation • Lost circulation is not reported as a major problem for S-Pad. However, the N sands are expected to be close to original formation pressure (~8.4 ppg, 1750 psi based on MPS-24 SBHP), whereas the O sands may be depleted (~5.8 ppg, 1200 psi based on offsets S-33, S- 17, and S-13). Due to this pressure differential, the potential for lost circulation in the OA/OB sands exists. Good drilling practices must be maintained and ECD's monitored. 3 • Expected Pressures , • Standard pressure gradient (8.35 ppg) is expected through the Ugnu. The N and O sands are expected to have a pressure gradient of 9.0 ppg, but take note of potential depletion in the - OA/OB sands. Pad Data Sheet • Please Read the S-Pad Data Sheet thoroughly. Hydrocarbons Hydrocarbons are possible in the Ugnu & Schrader Bluff interval. Faults • There are no predicted fault crossings for this well. Hydrogen Sulfide • MPS Pad is not designated as an H2S Pad. H2S detected from S-Pad wells: Well Name H2S Level Date of Reading #1 Closest SHL Well H2S Level MPS-34 < 2 ppm 5/15/2005 #2 Closest SHL Well H2S Level MPS-35 < 2 ppm 5/15/2005 #3 Closest SHL Well H2S Level MPS-23 < 2 ppm 5/15/2005 Max. Recorded H2S on Pad/Facility MPS-19A < 2 ppm 5/15/2005 Anti-collision Issues • MPS-33A passes the Major Risk Criteria except for the MPS-33 original wellbore. This wellbore will be abandoned. Distance to Nearest Property • MPS-10A is planned to be 3025' from the nearest Milne Point property line. Distance to Nearest Well Within Pool • MPS-33A is 1175' from the nearest sand penetration (MPS-23). - Procedure Summary Pre-Rig Operations 1. Full-bore cement P&A both strings. Final cement volume should be determined by infectivity test. Minimum cement volume should be sufficient to cover perforations and leave TOC at +/- 4000' MD (Approximately 8 bbls on short string and 12 bbls on long string). 2. Run Wireline drift and tag TOC. Pressure test both strings. 3. Chemical cut tubing strings at 3300' MD. Circulate strings and IA. 4. Install BPV. Drilling 5. MIRU. NU BOPE and test. 6. Pull dual 2.375" completion from 3300' MD. 7. PU DP. RIH w/ casing scraper to tubing stubs. 8. RIH and set 7" bridge plug at 2961' MD. 4 ~/ 9. Make mechanical cut at 2879' (below 9-5/8" shoe) in 7.0" casing. ~....'~i~ 10. Circulate out OA freeze protect, pull and lay down 7" casing. ~~~5 ~~~~ 11. RIH w/ tubing stinger on DP and lay a 17.0 ppg cement plug from 7" stub to 200' inside 9-5/8" casing shoe (estimated at 30 bbls). 12. Dress off cement and sidetrack well below 9-5/8" casing shoe. 13. Drill 8.5" hole as per directional plan to 5353' MD/4310' TVD 0150' below base OB). 14. Run and cement 7.0" casing. 15. RU E-line and run bond logs. 16. Displace drilling mud to brine. 17. E-line perforate OA and OB sands. 18. Run dual completion. 19. Land tubing hanger and test. Test IA. 20. Set BPV, ND BOP, install and test tree, pull BPV. 21. Freeze protect inner annulus. 22. Rig down. 5 r by ~ ~ ~ `~" BP EXPLORATION MPS-33A Field: Milne Point ENG: A. McVey Pad: S-Pad Schrader Bluff OA/OB Injector RIG: Doyon 14 RKB: 65.7 DIR 1 LWD OH FORM DEP TH HOLE CASING Cement Slur INFO MWD LOGS MD ND SIZE SPECS ry Wellhead Permafrost 20" Conductor FMC Ultra 112' Slimhole Surf Cso (Pre-Sett 9-518" 40 Ib/ft L-80, BTC Int. Yield 5750 psi Collaspse 3090 psi Drift - 8.679" Base Permafrost 1,873' 1,816' Casing Point 2,785' 2,525' 45.6° E 12-1/4" KOP 2,835' 2,560' DIR/GR/RES NONE InterlProd Csa 0' - 3900' NEU/DEN 7" 26.0 Ibs/ft GeoTap L-80, TCII Int. Yield 7240 psi Cement Slurry IFR/CASANDRA Collapse 5410 psi Lead Top of Lead Cement 3,700' 3,130' Drift - 6.151" 30.2 bbls, 112 sx InSite/InterACT 12.5 ppg 3900-5353' : 1.52 ft3/sx 7" 26.0 Ibs/ft TUZC 4,329' 3,539' 49.5° L-80, BTC-M Int. Yield 7240 psi Cement Slurry Top of Tail Cement 4,654' 3,750' ~ Collapse 5410 psi Tail Drift - 6.151" 25.2 bbls, 122 sx ' ' 15.8 PP9 Top of NA 4,948 3,965 1.17 ft3/sx Top of NB 4,987' 3,996' Top of NC 5,012' 4,017' Top of OA 5,122' 4,110' GR/SCMT/CCL Test Csg to Top of OB 5,182' 4.162' 30` Required 3500 psi Casing Pofnt 5,353' 4,311' 8-1/2" 12/6/2006 MPS-33A Well Plan Schematic.xls • • 0 b o~ m aNaN 4 y ~ N W C N N fT7m~~ WCOUQILUWU.~rn rnm ~ ~ `o < F~- ~ oQ, w F~~~ZZZZZFFF~ ~ i ~ ~. I I. ~ ~ y Z o 4 0. .o'n .n vi-~o F '~ ..»Nrvo°NOO~o=ate`.== ',. ' L SDP-NOVi ~ y~ ~ 3 > rJPrPn vPi ~D OO O 0 PN YI VI~~^JNNOpON VO'10N0~ ~ ° ~ ~ O° =N~J~ ¢ ~ a~~v°v7ooo~nv,~nvNi ~ I s ~ l": $ ^~ 0000000000000 r v oo~iovo ~ 'A nnr nr rrr rr nnn oonovo O cc pp~~ _ ~' p ~ LJ. 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O ~ 4r1. a O Z N rv ~~ z O tii - ti g~~ ~ ~ ° '^ 00 r~ F, ~ ~ F~? ~z H 4. ~ n~ ` ~y ~y 3Fv~FF ', v ~ o m Z ~~~o~ ~ U ~ fee W ~`f o"c~z~; ~~ fL l^N~Lp ~ 9 ~ W o O H y g C ~ ~~ ~vN `~ U~ ~ ^0 L O ~ o ~ y Q o Z . ~' P ~~ I W ^ ~ z 3 u~ ~ ~' ~, 7 7 - F ~ 0 N 9 h U 3V h ? ~ rv o ; L a 5* ~ = m C ~ ~ ~ '~3> g. f~HW ^ 0 ~ ~ 1 m 8 ~ `~ o C O F~~~ `o 4~}~~ - u _ F J 0 J ~ Z ~ ~ Q ~ a = l g __ )~ l I ~k [m;y00S1 gtdap Iea~uaA aniy I~~f~~~--~~-i~~~ii~~ F W ~ ^ z O U ~ N 0 r z z - o 0 u c °o COMPANY DETAILS REFERENCE INFORMATION SURVEY PROGRAM BP Amoco o-ordinate (N; EI Reference: Well Centre: MPS-33, Tnre North Depth Fm Depth To Survey/Plan Tool Plm: MPS-33A wp115 (MPS-33iPlan MPS-33A) Vertical (TVDI Reference: MPS-33: 65.711 Calculation Method: Minimum Curvature Section (VSI Reference: Slot- (11.I1lIN,l1.WE) 2785.1NI 5354.20 Platmed: MPS-33A wp05 V46 MWD*IFR+MS Created By:Troy Jakabosky QakaNl(u bp.coB~te: 11/Ii21N16 Error System: ISCWSA Measured Depth Rekrence: MPS-33: 65.70 Scan Methud: Tras- Cylinder North Calculation Method: Minimum Curvature WELL DETAll.S Ertor Surface: Elliptical + Casing Warning Mehod: Rules Based Name +N/-S +Fl-W Northing Fasting Latitude Longitude Slol ^ LIBURTON HA - MPS-33 -511.64 -732.54 59999211.N6 565613A1 711"24'36.NSUN 149"2T56.642W N/A is. TARGET DETAILS Sperry OPI~~~IIg $t@PVICtH6 - - ~ Name TVD +N/-S +E%-W Northing Fasting Shape - ~ _ . _.. ~ MPS-33A TI rer.l 4110.70 -223.43 -2557.31 5999675.00 563058.00 Circle (Radius: 100) I 570 '_8 s ~ 0 s 5 0 rn -' FORMATION TOP DETAILS No. TVDPath MDPath Formation I 3538.70 4329.31 TUZC 2 3768.70 4682.62 MBI 3 3809.70 4742.12 MB2 4 3938.70 4915.22 MC' 5 3964.70 4948.06 NA 6 3995.70 4986.50 NB 7 4016.70 5012.12 NC 8 4030.70 5029.03 NE 9 4077.70 5084.86 NF 10 I I 4109.70 4134 70 5122. I I 98 5150 TSBD -TOP OA TSBC - BASE OA 12 . 4161.70 . 5182.15 TSSB- TOP OB 13 4187.70 5212.18 SBAi -BASE OB -2 279 ~-._ . _ ~_ __-. CASMG DETAILS .. __. .. . ___--.. .._._.. ___. No. TVD MD Name Sizc 1 4310.70 5354.20 7" 7.000 SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/_W DLeg TFace VSec Target 2785.00 45.59 276.13 2525.49 115.95 -887.23 0.00 0.00 872.66 2 2835.00 45.97 273.39 2560.36 118.92 -922.93 4.00 -80.00 907.93 3 3149.50 49.51 257.05 2772.61 98.72 -1153.26 4.00 -79.32 1139.15 4 4635.51 49.51 257.05 3737.52 -154.63 ?254.62 0.00 0.00 '_259.25 ~"I"I"I"rT 5 5123.26 30.00 257.42 4110.70 -223.43 -2557.31 4.00 179.44 2567.01 MPS-33ATIrev.1 6 5354.20 30.00 257.42 4310.70 -248.58 -2670.01 0.00 0.00 2681.56 1 -1425 • Sperry-Sun BP Planning Report Company: BP Amoco Date: 1111/2006 Time: 14:45:42 Page: 1 Field: Milne Point Co-ordinate(NE) Reference: WeIL• MPS-33; True North Site: M Pt S Pad Vertical (TVD) Reference: MPS-33: 65.7. WeIL• MPS-33 Section (VS) Reference: Wetl (O:OON,O.OOE,264.68Azi) Wellpath: Plan MPS-33A Survey Calculation Method: Minimum Curvature l)b: Oracte Plan: MPS-33A wp05 Date Composed: 11/1/2006 MPS-33A Mill and Drill Version: 46 Principal: Yes Tied-to: From: Definitive Path Field: Milne Point North Slope UNITED STATES Map SysterdjS State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo DatumIVAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum:Mean Sea t_evel Geomagnetic Model: bggm2006 Site: M Pt S Pad Site Position: Northing: 5999978.00 ft Latitude: 70 24 37.329 N From: Map Easting: 566345.00 ft Longitude: 149 27 35.171 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.51 deg Well: MPS-33 Slot Name: Well Position: +N/-S -50.64 ft Northing: 5999920.86 ft ~ Latitude: 70 24 36.830 N +E/-W -732.54 ft Easting : 565613.01 ft ~ Longitude: 149 27 56.642 W Position Uncertainty: 0.00 ft Casing Points MD TVD Diameter Hole Size Name ft ft in in 5354.20 4310.70 7.000 8.500 7" Formations MD TVD Formations Lithology Dip Angle Dip Direction ft ft deg deg 0.00 BPRF 0.00 0.00 4329.31 3538.70 TUZC 0.00 0.00 4682.62 3768.70 M61 0.00 0.00 4742.12 3809.70 M62 0.00 0.00 4915.22 3938.70 MC 0.00 0.00 4948.06 3964.70 NA 0.00 0.00 4986.50 3995.70 NB 0.00 0.00 5012.12 4016.70 NC 0.00 0.00 5029.03 4030.70 NE 0.00 0.00 5084.86 4077.70 NF 0.00 0.00 5122.11 4109.70 TSBD -TOP OA 0.00 0.00 5150.98 4134.70 TSBC -BASE OA 0.00 0.00 5182.15 4161.70 TSSB- TOP OB 0.00 0.00 5212.18 4187.70 SBAS -BASE OB 0.00 0.00 Targets Map Map <---- Latitude ----> <--- Longitude --- Name Description TVD +NI-S +E/-W Northing Easting Deg ;Min rSec Deg Min' Ser Dip. Dir. ft ft ft ft ft MPS-33A T1 rev.1 4110.70 -223.43 -2557.31 5999675.00 563058.00 70 24 34.629 N 149 29 11.595 W -Circle (Radius: 100) -Plan hit target Plan Section Information MD Incl Azim TVD. +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ftdeg/100ftdeg/100ft deg 2785.00 45.59 276.13 2525.49 115.95 -887.23 0.00 0.00 0.00 0.00 2835.00 45.97 273.39 2560.36 118.92 -922.93 4.00 0.76 -5.48 -80.00 3149.50 49.51 257.05 2772.61 98.72 -1153.26 4.00 1.13 -5.20 -79.32 4635.51 49.51 257.05 3737.52 -154.63 -2254.62 0.00 0.00 0.00 0.00 5123.26 30.00 257.42 4110.70 -223.43 -2557.31 4.00 -4.00 0.08 179.44 MPS-33A T1 rev.1 Sperry-Sun BP Planning Report • Company: BP Amoco Date: 11/1/2006 Time: 14145:42 Page : 2 -Fields Milne Point C o-ordinate( NE) Reference: WeIL• MPS-33,True North. Site: M Pt SPad V ertica l (TVD) Reference; `MPS-33:65:7 Well: MPS-33 Section (VS} Reference:'. We11 (O.OON,O.OOE,264.68Azi) Wellpath: Plan MPS-33A Survey Calculation Method: Minimum Curvature Dh: Oracle Plan Section Information MD; Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft' ft ft deg/100ftdeg/100ftdegl100ft deg 5354.20 30.00 257.42 4310 .70 -248.58 -2670 .01 0.00 0.00 0.00 0.00 Survey MD ' Incl Azim TVD Sys TVD VS N/S E/W DLS MapN MapE TooUCo ft deg deg ft ft fit ft ft degN00ft ft ft 2785. 00 45. 59 276. 13 2525. 49 2459. 79 872. 66 115 .95 -887. 23 0.00 6000029. 00 564724.88 Start Dir 1 / 2800. 00 45. 70 275. 31 2535. 97 2470. 27 883. 19 117 .02 -897. 90 4.00 6000029. 97 564714.20 MWD+IFR 2$05. 00 45. 73 275. 03 2539. 46 2473. 76 886. 71 117 .34 -901. 47 4.00 6000030. 26 564710.63 Start Dir 4 2835. 00 45. 97 273. 39 2560. 36 2494. 66 907. 93 118 .92 -922. 93 4.00 6000031. 65 564689.16 MWD+IFR 2900. 00 46. 51 269. 87 2605. 33 2539. 63 954. 52 120 .25 -969. 84 4.00 6000032. 57 564642.24 MWD+IFR 3000. 00 47. 54 264. 58 2673. 52 2607. 82 1027. 56 116 .68 -1042. 87 4.00 6000028. 36 564569.26 MWD+IFR 3100. 00 48. 80 259. 49 2740. 24 .2674. 54 1101. 94 106 .33 -1116. 61 4.00 6000017. 37 564495.62 MWD+IFR 3101. 87 48. 83 259. 40 2741. 47 2675. 77 1103. 34 106 .07 -1117. 99 4.00 6000017. 10 564494.24 End Dir 1 3149. 50 49. 51 257. 05 2772. 61 2706. 91 1139. 15 98 .72 -1153. 26 4.00 6000009. 43 564459.04 MWD+IFR 3200. 00 49. 51 257. 05 2805. 41 2739. 71 1177. 21 90 .11 -1190. 69 0.00 6000000. 49 564421.68 MWD+IFR 3300. 00 49. 51 257. 05 2870. 34 2804. 64 1252. 59 73 .06 -1264. 81 0.00 5999982. 80 564347.73 MWD+IFR 3400. 00 49. 51 257. 05 2935. 27 2869. 57 1327. 97 56 .01 -1338. 92 0.00 5999965. 10 564273,77 MWD+IFR 3500. 00 49. 51 257. 05 3000. 21 2934. 51 1403. 34 38 .96 -1413. 04 0.00 5999947. 40 564199.82 MWD+IFR 3600. 00 49. 51 257. 05 3065. 14 2999. 44 1478. 72 21 .91 -1487. 15 0.00 5999929. 71 564125.86 MWD+IFR 3700. 00 49. 51 257. 05 3130. 07 3064. 37 1554. 10 4 .86 -1561. 27 0.00 5999912. 01 564051.91 MWD+IFR 3800. 00 49. 51 257. 05 3195. 00 3129. 30 1629. 47 -12 .18 -1635. 38 0.00 5999894. 31 563977.95 MWD+IFR 3900. 00 49. 51 257. 05 3259. 94 3194. 24 1704. 85 -29 .23 -1709. 50 0.00 5999876. 61 563904.00 MWD+IFR 4000. 00 49. 51 257. 05 3324. 87 3259. 17 1780. 22 -46 .28 -1783. 61 0.00 5999858. 92 563830.04 MWD+IFR 4100. 00 49. 51 257. 05 3389. 80 3324. 10 1855. 60 -63 .33 -1857. 73 0.00 5999841. 22 563756.09 MWD+IFR 4200. 00 49. 51 257. 05 3454. 74 3389. 04 1930. 98 -80. 38 -1931. 84 0.00 5999823. 52 563682.13 MWD+IFR 4300. 00 49. 51 257. 05 3519. 67 3453. 97 2006. 35 -97. 43 -2005. 96 0.00 5999805. 83 563608.17 MWD+IFR 4329. 31 49. 51 257. 05 3538. 70 3473. 00 2028. 44 -102 .42 -2027. 68 0.00 5999800. 64 563586.50 TUZC 4400. 00 49. 51 257. 05 3584. 60 3518. 90 2081. 73 -114 .47 -2080. 07 0.00 5999788. 13 563534.22 MWD+IFR 4500. 00 49. 51 257. 05 3649. 54 3583. 84 2157. 11 -131 .52 -2154. 19 0.00 5999770. 43 563460.26 MWD+IFR 4600. 00 49. 51 257. 05 3714. 47 3648. 77 2232. 48 -148. 57 -2228. 30 0.00 5999752. 73 563386.31 MWD+IFR 4635. 51 49. 51 257. 05 3737. 52 3671. 82 2259. 25 -154. 63 -2254. 62 0.00 5999746. 45 563360.05 MWD+IFR 4637. 67 49. 42 257. 05 3738. 93 3673. 23 2260. 88 -154 .99 -2256. 22 4.00 5999746. 07 563358.45 Start Dir 4 4682. 62 47. 62 257. 07 3768. 70 3703. 00 2294. 25 -162 .54 -2289. 04 4.00 5999738. 24 563325.70 M61 4700. 00 46. 93 257. 08 3780. 49 3714. 79 2306. 91 -165 .39 -2301. 49 4.00 5999735. 27 563313.28 MWD+IFR 4742. 12 45. 24 257. 10 3809. 70 3744. 00 2336. 98 -172. 17 -2331. 06 4.00 5999728. 24 563283.77 MB2 4800. 00 42. 93 257. 14 3851. 27 3785. 57 2376. 90 -181. 14 -2370. 32 4.00 5999718. 92 563244.60 MWD+IFR 4900. 00 38. 93 257. 21 3926. 81 3861. 11 2441. 84 -195. 68 -2434. 18 4.00 5999703. 82 563180.87 MWD+IFR 4915. 22 38. 32 257. 22 3938. 70 3873. 00 2451. 26 -197 .79 -2443. 45 4.00 5999701. 64 563171.63 MC 4948. 06 37. 01 257. 25 3964. 70 3899. 00 2471. 16 -202 .22 -2463. 02 4.00 5999697. 03 563152.10 NA 4986. 50 35. 47 257. 28 3995. 70 3930. 00 2493. 69 -207. 23 -2485. 18 4.00 5999691. 83 563129.98 NB 5000. 00 34. 93 257. 29 4006. 73 3941. 03 2501. 41 -208. 94 -2492. 77 4.00 5999690. 05 563122.41 MWD+IFR 5012. 12 34. 45 257. 30 4016. 70 3951. 00 2508. 25 -210. 46 -2499. 50 4.00 5999688. 47 563115.69 NC 5029. 03 33. 77 257. 32 4030. 70 3965. 00 2517. 65 -212. 54 -2508. 75 4.00 5999686. 31 563106.46 NE 5084. 86 31. 54 257. 38 4077. 70 4012. 00 2547. 53 -219 .14 -2538. 14 4.00 5999679. 45 563077.13 NF 5100. 00 30. 93 257. 39 4090. 65 4024. 95 2555. 31 -220 .86 -2545. 80 4.00 5999677. 67 563069.49 MWD+IFR 5122. 11 30. 05 257. 42 4109. 70 4044. 00 2566. 44 -223. 30 -2556. 75 4.00 5999675. 13 563058.56 TSBD - TO 5122. 20 30. 04 257. 42 4109. 78 4044. 08 2566. 49 -223. 31 -2556. 79 4.00 5999675. 12 563058.52 End Dir : 1 5123. 26 30. 00 257. 42 4110. 70 4045. 00 2567. 01 -223. 43 -2557. 31 4.00 5999675. 00 563058.00 MPS-33A 5150. 98 30. 00 257. 42 4134. 70 4069. 00 2580. 76 -226 .45 -2570. 84 0.00 5999671. 86 563044.50 TSBC - B 5182. 15 30. 00 257. 42 4161. 70 4096. 00 2596. 22 -229 .84 -2586. 05 0.00 5999668. 33 563029.32 TSSB- TO 5200. 00 30. 00 257. 42 4177. 16 4111. 46 2605. 07 -231. 78 -2594. 76 0.00 5999666. 31 563020.63 MWD+IFR 5212. 18 30. 00 257. 42 4187. 70 4122. 00 2611. 11 -233. 11 -2600. 70 0.00 5999664. 94 563014.70 SBA5 - B 5300. 00 30. 00 257. 42 4263. 76 4198. 06 2654. 67 -242 .67 -2643. 56 0.00 5999655. 00 562971.93 MWD+IFR ment OA ~2 rev. OA ~B OB S i Sperry-Sun BP Planning Report Company: BP Amoco Date: 11/1/2006 ' Time: 14:45:42 Nape: 3 Field:' Milne Point Co-ordinate(NE) Reference; WeIL• MPS-33, TrueNOrth Site: M PtSPad: Vertical (TVD) Reference: MPS-33: 65.7 Wel[: MPS-33 Section (VS) Reference: We11(O.OON,O.OpE,264.68Azi) Wellpath Plan MPS-33A Survey Calculation Metbod:`Minimum Curvature Db: Oracle Survey MD, Incl Azim TVD Sys TVD VS N/S E/W DLS MapN MapE Tool/Co ft deg deg., ft ft _ft ft ft deg/100ft ft ft 5353.14 30.00 257.42 4309.78 4244.08 2681.03 -248.46 -2669.49 0.00 5999648.98 562946.06 Total Dept 5354.20 30.00 257.42 4310.70 4245.00 2681.56 -248.58 -2670.01 0.00 5999648.86 562945.54 7" nent WF:LI. UF.IAII \ N N/\ ~1~ W Nunhwk Iva1wN I~wW: Lrog01AW tiWl Alrn ti <ara -n!.a FYI//711N `1~5n1i 111 ;n.J',1.4i11N IJ'I !]'tl la!W WA ANTI-COLLISION $(:1-fING$ Inlelpolation MethodMD Interval: SII.UII peplll RangeFrom: 27%S.IM) TO: SjSQ.21) Maximum Range: 732.67 Reference: Plan: MP$-33A wp115 1'UMI'ANY IIF.INI ti NI'AwiKU ('aY:ulntuw Al1h,J: nluumuw l'iu, N)vi~ Ivor S>sww. uc wsn s..m nl.•Im1d' Ira. r'>hn,Wr Nom Ivor lwlau~. IJLINAW <';.wy W;muN hk~1641: Kuk:s kavvl ti11KVF.Y rKUIiKAM Ihpw lm Ihplh lip \ ): 1'kw lua'1 !].\5 MI StSJ.!I IL JAII'ti~,tA x1115 VN~ nlWl>~II~KAI~ WIlL•AIII UI:I,W % 160 From Colour To MD rlan hlrs.itn ISO 2785 3800 rwlwl wet.,A Mrs.?i Te,w Alu. ±7x5 W 33 3800 4000 3 ~ 4000 4250 itel Uan,~ Mrs-tt, as nm 4250 4500 v.s4rmw ~o Lrtpw s .~,.~,, 4SOO 47SO AoN~ N/-S L'-W Lrum IVIr 125 4750 5000 ua u4 oilr o)N1 nsn 5000 5250 5250 5500 5500 5750 ~n I~Ai1Nl) S7SO WOO IOO II ,j~ hll'\-IJ Inf 1'ti-IJI. M1IaNU KUL 6000 6250 ~ Mrs.!!IAU'+-!!, nlaN4k,a j 6250 -- 6500 - Mrs.!, Inu'satl. M:+N'. 14\k 6 AII'\-!i lAllti-!?LII n1eNn 14.1 ' ' 6 50 1-N Inll %-]J1. nlupr Kul M111 6500 7 hll'1~`J IMI'1-_`JI'kll. MaNr W+1 6750 7000 - All'4-!JIAl15-_`JYB`_LAIaprWsl JO 5 ~ MI'n-!]IAlrti-.71. n1aN'114,1 nlrs-!] Inutia7u 1. nWNn Kul ` ` ' ]I AIIti- , IMr%- kl I MnN'r klsk A1r%-_% IAllti !x'1. AIaN~r Rut / ' ) ~ All's-_x 1Alr%'\ 1'kll, AleNU Kink All'%-_%IAII'%-`_xl'k'1 AIaN'r krk All'%-,U IAIIti-?U1. AIaN'r kuk U 32 AIIN-ti ~All'ti-??I Nlll! kkl R% O . . A1P\-tJ Ihll'%~t J1. FIaNU kuk ~ hll'%-?J lAlrti-?iLll. h1aN'r kuk ~ AII'ti-tJ lhll's-?JI_1. MaNu kuk 1`Iw1 All'ti~t'I (flan nlrS-?'l 1. AInM'r k,ik - 1'Lw AII•S-NI IFwu} Maj+~r Ruk ' ' kw Afl 4-JI (Marv lruul~Aluru kuk - 1 I'I;w All'1-itA All'x-,tA ar113 25 f130 4 0 270 90 25 .- 0 5 240 120 100 Pre Plans Removed. See AC Scan for Plans Parents Profile @ No Errors 125 .. ~ ' ' \I 1 K>N UIiTAII ti A ' -~ ~F/-W DI •y TFacc V1n' laryn k¢ MU hY An IYU ~N 21 SO 1 !,%S.W 41.54 !7fi.ly !5!5 J'I 11545 .x%7.21 U.INI U.W A7_i fly 2x?S.W JS.Y] .7114 !SNI.t6 II%.Y2 !)`_2.4? 4.W -%UAU YI1J.Yt t t ` 150 ? II?I.IS ,]!.61 46.72 -IIS ±R J.W -T) ?IJ4.SU n51 25]US _ J Nd 5.51 J451 !c].U5 ?,,,.;, -l iynt 22i{6? UJNI RW 2!5'1'5 519.!r, t~p1 !<, i2 Jllu ]u !, .It !55711 i1N1 ITi 31 `_SG]JII All'%-,tA Tl ml , A1 ,r,u ul u,N1 21X1 ` GA1-6 n V 5]J! -01 2Jnsx ` 160 1 ay . 1 . _ LLINI _ 2 80 Travelling Cylinder Azimuth (TFO+AZI) [ deg] vs Centre to Centre Separation [SOft/in] • • C] Sperry-Sun Anticollision Report • Company: BP Amoco Dater 11/1/2006 Time: 14:45:06 Page: I Field: Milne Point Reference Site: M Pt S Pad Co-ordinat e(NE) Reference; -Well: MPS-33, True North. Reference Well:: MPS-33 Vertical (T VD) Reference: MPS-33: 6 5.7 Reference WellpatlPlan MPS-33A Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Reference: Principal Plan & PLANNED PROGRAM Interpolation MethodMD Interval: 50.00 ft Error Model: ISCWSA Ellipse Depth Range: 2785.00 to 5354.20 ft Scan Method: Trav Cylinder North Maximum Radius: 732.67 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 4/26/2005 Validated: No Version: 0 Planned From To Survey Toolcode Tool Na me ft ft 179.00 179.00 MPS-33 GYRO (179.00-179.00) (1) CB-GYRO-SS Camera based gyro single shots 319.43 2785.00 MPS-33 IFR (319.43-5221.21) (1) MWD+IFR+MS MWD +I FR + Multi Station 2785.00 5354.20 Planned: MPS-3 3A wp05 V46 MWD+IFR+ MS MWD +I FR + Multi Station Casing Points MD TVD Diameter Hole Size Name ft fit in in 5354.20 4310.70 7.000 8.500 7" Summary --------- ----------- Offsef Wellpath -------- -------------> Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft - ft - ft M Pt S Pad MPS-14 MPS-14 V6 3231.26 3400.00 273.87 68.70 205.17 Pass: Major Risk M Pt S Pad MPS-22 MPS-22 V8 4022.45 4150.00 279.57 97.08 182.49 Pass: Major Risk M Pt S Pad MPS-23 MPS-23 V12 Out of range M Pt S Pad MPS-23 MPS-23L1 V2 Out of range M Pt S Pad MPS-24 MPS-24 V3 4726.02 5300.00 452.92 90.42 362.50 Pass: Major Risk M Pt S Pad MPS-24 MPS-24P61 V11 2796.22 3000.00 491.44 50.32 441.12 Pass: Major Risk M Pt S Pad MPS-24 MPS-24PB2 V5 4726.02 5300.00 452.92 90.50 362.43 Pass: Major Risk M Pt S Pad MPS-27 MPS-27 V9 2811.39 2950.00 610.58 66.76 543.82 Pass: Major Risk M Pt S Pad MPS-27 MPS-27L1 V7 2811.39 2950.00 610.58 66.66 543.91 Pass: Major Risk M Pt S Pad MPS-27 MPS-27P61 V2 2811.39 2950.00 610.58 66.78 543.80 Pass: Major Risk M Pt S Pad MPS-28 MPS-28 V5 2810.54 2850.00 273.35 65.16 208.19 Pass: Major Risk M Pt S Pad MPS-28 MPS-28P61 V6 2810.54 2850.00 273.35 65.14 208.21 Pass: Major Risk M Pt S Pad MPS-28 MPS-28P62 V5 2810.54 2850.00 273.35 65.14 208.21 Pass: Major Risk M Pt S Pad MPS-30 MPS-30 V11 2812.43 2850.00 163.47 57.69 105.78 Pass: Major Risk M Pt S Pad MPS-31 MPS-31 V8 2850.29 3000.00 638.25 64.77 573.48 Pass: Major Risk M Pt S Pad MPS-33 MPS-33 V11 2800.00 2800.00 0.06 0.65 -0.59 FAIL: NOERRORS M Pt S Pad MPS-34 MPS-34 V9 2803.19 2750.00 666.17 56.25 609.92 Pass: Major Risk M Pt S Pad MPS-34 MPS-34L1 V1 2803.19 2750.00 666.17 56.10 610.07 Pass: Major Risk M Pt S Pad MPS-34 MPS-34L2 V9 2803.19 2750.00 666.17 56.10 610.07 Pass: Major Risk M Pt S Pad Plan MPS-39 Plan MPS-39 V4 Plan: M 2815.28 2800.00 446.36 61.57 384.79 Pass: Major Risk M Pt S Pad Plan MPS-40 Fern V1 Plan: Fern wp0 2816.27 2750.00 597.72 59.25 538.47 Pass: Major Risk M Pt S Pad Plan MPS-41 Mary Jean VO Plan : Mar 2787.89 2700.00 441.98 56.83 385.15 Pass: Major Risk Site: M PtS Pad Well: MPS-14 Rule Assigned: Major Ri sk Wellpath: MPS-14 V6 Inter-Site Error: 0.00 ft .Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD ReC -0ffset TFp+AZI TFO-H S Casing/ HBistance Area Deviatio n Warning fit ft ft ft ft ft deg deg in ft ft ft 2794.27 2531.97 3000.00 2520.42 5.75 7.37 190.86 275.24 7.000 292.66 66.75 225.91 Pass 2852.42 2572.46 3050.00 2539.23 5.83 7.69 193.59 281.15 7.000 292.63 68.00 224.63 Pass 2910.49 2612.54 3100.00 2558.09 5.92 7.98 196.34 287.04 7.000 291.25 68.96 222.29 Pass 2968.33 2652.07 3150.00 2577.12 6.01 8.24 199.13 292.90 7.000 289.10 69.67 219.42 Pass 3025.75 2690.86 3200.00 2596.33 6.11 8.48 202.01 298.75 7.000 286.24 70.10 216.15 Pass 3082.56 2728.73 3250.00 2615.74 6.21 8.71 205.01 304.65 7.000 282.78 70.21 212.57 Pass 3138.60 2765.53 3300.00 2635.28 6.31 8.92 208.20 310.62 7.000 278.99 69.98 209.01 Pass 3185.96 2796.29 3350.00 2654.91 6.43 9.15 212.30 315.26 7.000 275.71 69.46 206.25 Pass 3231.26 2825.70 3400.00 2674.51 6.55 9.41 216.70 319.65 7.000 273.87 68.70 205.17 Pass 3276.43 2855.03 3450.00 2694.05 6.67 9.67 221.19 324.14 7.000 273.43 67.63 205.80 Pass 3321.62 2884.38 3500.00 2713.78 6.79 9.93 225.66 328.62 7.000 274.40 66.19 208.20 Pass MPU S-33A Area of Review I_I ~_~ .- ~ _- ~~_, .- , _- -_ - ' y '., ~ I ... ~ - I I N• 7 - Ibi , R a_ S-~~I_ , 3000' ---~~ ...... . .. ........... .. .. .. .~;~ ! ~ ~ t_ ~ _ ~ _ _. . - -_ I~PU ~ U :7 ~ J _-~~ r - ~ _{!.~ (.,~~~'U SB _ i~J'1PU SB S~'3L1 tvlPU SB S-~ ~ 7 • SFD 12/13/2006 061213_2061720_MPU_S-33A_AOR.ppt • ~ Sondra D. Stewman ss-sr,z52 150 BP Exploration AK-INC. "Mastercard Check" PO Box 196612 MB 7-5 I ~-~~j- Anchora9e, AK 99519-6612 DATE PAY TO THE OrrRD~~E,,R OF V~~ ~~ ~ OLLARS First National k Alaska Anchorage, AK 99501 MEMOS ~~'~ :i25200060~:99i4622?L564~~' 050 CI T~~S1~IT~':~L LET'T'ER C'HEC'KLIST W-ELL ~i :~?~IE i~/" ~{ .~ PTl)# ZQ ~ - ~ ~ 7i ®evelopment V Ser~-ice Exploratory- Stratigraphie Vest lion-Conventional Well Cirele Appropriate Letter /Paragraphs to be Inclaxded in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER w'H.AT (OPTIONS) APPLIES MULTI LATE;Z:AL ~ The permit is for a new wellbore segment of existing weli ([f [ast two digits in ,Permit No. . API No. ~0- API number are - between 60-69) ,Production should continue to be reported as a function of the .original API number stated above. PLOT HOLE In accordance with 20 .=~~C ?_5.005(f), a1f records, data and logs ' I acquired for the pilot hole must be clearly differentiated in both i well name ( PH) and API number (~0- - -_) From records, data and logs ;acquired for well SPACI?vG ~ The permit is approved subject to full compliance with 20 AAC EXCEPTION ~ ?3.0». Approval to perforate and produce !inject is contingent upon issuance of a conservation order approving a spacing ' exception. assumes the I liability of any protest to the spacing exception that may occur. DRY D[TCH AlI drv ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or ;from where samples are first caught and 10' sample intervals ; I through target zones. Please note the following special condition of this permit: ;~ Non-Conventional; production or production testing of coal bed methane is not allowed I Well ;for (name of well) until after (Companv Name) has designed and ~, implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing nr,,,,,..,.,. Rev: l 25; 06 C 'jody`transmittaf checklist WELL PERMIT CHECKLIST Field & Pool MILNE POINT, SCHRADER BLFF OIL - 525140 Well Name: MILNE PT UNIT SB S-33A ______Program SE_R___ Well bore seg ^ PTD#:2061720 Company CONOCOPHILLIPS ALASKA INC Initial Class/Type SER ! PEND GeoArea 890 Unit 11328 _ On1Off Shore On Annular Disposal ~' Administration 1 Permit-fee attached_________ __ ________________ ______________ _Yes._--_- .-.-_-..-__._--.-_---.,-,_- 2 Lease number apprapriate_ _ - - . - - Yes - - - - _ _ Entire well in ADL 380109_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 3 Uni_quewell-name and number------------------------------------- -Yes.___ -___-__--_._._ 4 Well located in a_defined_pool- - - - - - - - - - - - - - - - - - - - - - - - Yes - Milne Point Schrader Bluff Oil Pool (525140), governed by_CO 477, as_ amended by_CO 477.05. - 5 Well located proper distance-from drilling unit_boundary- - .. _ - . - - _ _ Yes - _ _ - _ - CO 477.05 specifies no restrictjons as to well spacing except that no pay shall be opened - 6 Well located proper distance-from other wells_ _ Yes - in a well closer than 500' from the exterior boundary gf the-affected area. In'ection,zone will be _ 3000'- _ _ _ a 7 Sufficient acreage available in d_ril_ling unit- - - - - - - - - - -- - - - - - - - - - --- - --- - - - -Yes . _ _ - _ - -from MPU boundary._ _ . _ _ . _ _ _ _ _ - 8 If_deviated,is_wellboreplat_inclu_ded---------------------------------- - Yes___--- _. 9 OperatoroNyaffectedparty_______,_____,___------------------_ -Yes__--_ -.--- 10 Operator has_appropriate.bondinforce ----- -- -------- -- - -- Yes ----- - -- ------ ------ -- ---------- -- ----- -- -- -------~-- -- - 11 Permit can be issued without conservation order Yes - - - - Appr Date 12 Per_mitcan be issued without administrative-approval _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ - _ SFD 12!13!2006 13 Can permit be approved before 15-day wait Yes 14 Well located within area and_strata authorized by Injection Order # (put_1O# in_comments)-(Fpr - Yes - - - Area Injection Order No.- tOti- _ - - - - 15 All wells within 114_mile area of review identified (Far sefvice well only)- - - - - - - - - - - - - - -Yes _ - - - - - -MPU S-30, 5-25, S-25L1, 5-24, S-24PB1, S-24PB2, S-23, S-23L1- - - - _ - - - - - - - - - _ -------------- 16 Pre-produced injector duration-of pre Productionl_essthan3months_(Forservicewellonly)_ _No_______ ______________,.______________ ___,.__._____,__________.____,_____ 17 Nonconven,ga_sconformstoAS31,05,030(j.1.A),([.2.A-D)------------------- - - NA------- --------------- ---_------------ -------------------------------- Engineering 18 Conductor strip rovided 9P NA- Conductor installed in MPS-33_(202-212), - 19 Su_rfacecasing-protectsal!known-USDWs__________________- -- -.- . -NA____.- -All_aquifersexempted,40CFR-147.102-(b)~3).._-. _-.-..-----_- ------.--_.__--_.._.__ 2D CMT vol adequate-to circulate_on conductor_ & surf_csg - NA_ Surface casing installed in MPS-33._ ------------------------------------------- 21 CMT-vol, adequate-to tie-in long string tosurf csg_ - _ _ - NA_ _ - - _ _ - _ Production. casing set in MPS-33. - - _ _ _ 22 CMT_will coverall know_n_productiye horizons- - - - - - - - - - - - - - Yes ------ --------------------------------------------------------------------- 23 Casing designs adequate for C,T,B&permafr_ost-__- -_--_--- -_. Yes__..-_ .............. .. -._-.-- __....-- .-. 24 Adequate tankage_or re_serye pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes . - - - .Rig is-equipped with steel_pits. - No reserve pitplanned, All waste to approved dispos_al_wells._ - 25 If_a_re-drill, has-a-10-403 for abandonment been approved _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ - - 306-385._ 26 Adequate wellbore separationproposed _ _ _ _ _ _ ____ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes - - - - _ _ -Proximity analysis performed, Traveling cylinder path calculated, New well diverges from original well. - - - . _ . 27 If djverter required, does it meet regulations_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ _ _ _ _ _ BOP Stack will already_be in place, _ _ _ _ _ _ _ _ _ _ _ _ _ Appr Date 28 Drilling Fluid. program schematic-8 equip list adequate_ - - Yes Maximum expected f_o[mation pressure 9,0_EMW._ Planned mudweght_up 9.6-or as needed_ _ _ _ _ _ _ _ _ _ _ _ _ _ TE((M 12114!2006 29 BOPEs,-dotheymeetregulation______________________________-.--- _Yes----_- ---..---.__-.__-._--__._-_---_..---._---_____.---._-,-__,__----.---_ ~ 30 BOPE_ptess rating appropriate; test to-(put psig in comments)- - Yes - MASP calculated at 1517psi. 3000 psi_BOP testplanned, _Y 31 Choke_manifoldcomp_IieswlAPl_RP-53 (May 84)------------- Yes-_____ ---_-----_____________ ' 32 Work willoccurwithoutoperationshutdown------------------------ ----- -Yes-__--- -------.-______- 33 Is presence-of H2S gas_ probable- - - - - - - - - - - - - - - - - - - - -- - - - - - - -- - - - -- - - No- - - - . - - . 5 ?ppm H2$ has been-reported atS. pad, Mud should-preclude on-rig. Rig has sensorsandalarms, - - - - - - _ _ 34 Mechanical_cond_ition of wells within AOR verified (Forservice well only) Yes - _ - - No issues identified with_any wells in AOR._ -------------------------------- Geology 35 Permik can be issued w!o hydrogen sulfide measures . - .. - - . - Yes - _ - - . - - Operator_reports Less than 2 ppm H2S measured in_ihe S-Pad wells, _ - - - 36 Dala-presented on, potential overpressure zones Yes _ Schrader_ Bluff N sands expected to be normally-pressured (-8.4ppg), but underlying_O-sands - _ - _ - - - _ _ Appr Date 37 Seismic analysis-of shallow as-zones- - - - _ _ - - _ _ - g NA_ - _ . - _ _ . ma be de leted as low as 5 8 y . p - (- - - - , - ppg). _Discussed _in Drilling Hazards & Contingencies section_of app, - - - . - _ . SFD 12/13/2006 38 Seabed condition survey-(if off-shore) - _ - , - _ . . NA 39 Contact name/phone for weekly_progress reports [exploratory only] NA_ Geologic Engineering Public Commissioner: Date: Commissioner: Date Co sinner Date s Well f-iistory File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special efifort has been made to chronologically organize this category of information. . • mps-33a.tapx Sperry-Sun Drillin Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed May 02 14:40:18 2007 Reel Header Service name .............LISTPE Date . ...................07/05/02 Ori in ...................STS Ree~ Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date . ...................07/05/02 Origin ...................STs Tape Name. .... ........UNKNOWN continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Comment Record TAPE HEADER Miline Point MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0004801118 J. BOBBITT LEWIS / VAUG SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD scientific Technical services Scientific Technical Services MPS-33A 500292312301 BP Exploration (Alaska) Inc. Sperry Drilling Services 02-MAY-07 12 12N 10E 3255 398 72.01 38.20 Page 1 • 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: mps-33a.tapx OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 2792.0 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELLBORE WAS EFFECTED BY DRILLING OFF OF A CEMENT PLUG, THE TOP OF WHICH WAS AT THE 9 5/8" CASING SHOE (2792'MD/2536'TVD) IN THE MPS-33 WELLBORE. 4. MWD RUN 1 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DG R) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED THERMAL NEUTRON POROSITY (CTN), AZIMUTHAL LITHO-DENSITY (ALD), ACOUSTIC CALIPER (ACAL), AND PRESSURE WHILE DRILLING (PWD). ROTATED ALD DATA OVER SLIDE INTERVALS BELOW ABOUT 4500'MD WERE ACQUIRED AFTER DRILLING THE INTERVALS. THESE MAD DATA WERE DEPTH CORRECTED (SHIFTED) T0, AND MERGED WITH, THE MWD DATA. GEOTAP FORMATION PRESSURE TESTER DATA WERE ACQUIRED WHILE POOH AFTER REACHING FINAL TD. 5. LOG AND DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER CASED- HOLE GAMMA RAY LOG RUN IN MPS-33A ON 31 JANUARY 2007. LOG HEADER DATA RETAIN ORIGINAL DEPTH REFERENCES. THESE PDC LOG DATA WERE PROVIDED BY D. DORTCH (SAIC/BP) ON 26 FEBRUARY 2007, QUOTING AUTHORIZATION FROM MIKIE WEEKS (BP GEOSCIENTIST). 6. MWD RUN 1 REPRESENTS WELL MPS-33A WITH API#: 50-029-23123-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 5500'MD/4432'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, ACAL-DERIVED Page 2 • • mps-33a.tapx HOLE SIZE). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. ALDSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR DEPTHS. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZES: ACAL-DERIVED (BIT SIZE 8.5") MUD WEIGHT: 8.8 - 9.3 PPG MUD SALINITY: 500 PPM CHLORIDES FORMATION WATER SALINITY: 21000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE File Header Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/02 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 2629.0 5461.0 CALA 2748.5 5409.5 FET 2767.5 5453.5 NPHI 2767.5 5406.5 PEF 2767.5 5419.5 RPx 2767.5 5453.5 RPM 2767.5 5453.5 RPD 2767.5 5453.5 DRHO 2767.5 5419.5 RHOB 2767.5 5419.5 NCNT 2767.5 5406.5 FONT 2767.5 5406.5 RPS 2767.5 5453.5 ROP 2790.0 5497.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 2629.0 2630.5 2629.5 2631.0 Page 3 C~ 2666.5 2668.0 2677.5 2677.5 2728.0 2729.5 2737.5 2739.0 2746.0 2748.0 2788.5 2791.0 2794.5 2798.0 2807.5 2810.0 2813.0 2816.5 2822.0 2825.0 2835.5 2838.0 2846.0 2848.5 2856.0 2859.0 2860.0 2863.0 2867.0 2870.0 2870.5 2873.5 2880.0 2882.0 2900.5 2903.0 2914.0 2918.0 2925.0 2928.0 2935.0 2938.0 2956.5 2959.0 2965.0 2966.0 2972.0 2973.5 2995.0 2998.0 3004.5 3007.0 3021.5 3025.0 3035.5 3037.5 3046.0 3048.5 3057.0 3058.5 3068.5 3070.5 3076.5 3079.0 3083.5 3086.0 3086.0 3088.5 3091.5 3093.5 3095.5 3097.0 3100.0 3101.5 3103.5 3106.5 3108.0 3110.5 3117.5 3120.0 3123.0 3125.0 3137.5 3139.5 3146.5 3148.5 3167.5 3169.5 3170.5 3173.0 3191.5 3194.5 3198.5 3201.0 3208.0 3211.0 3228.5 3231.0 3245.5 3247.0 3248.0 3249.5 3262.5 3265.5 3296.0 3299.5 3305.0 3309.5 3309.5 3313.5 3318.0 3321.0 3327.5 3330.0 3353.0 3355.5 3359.5 3362.0 3375.0 3377.0 3382.0 3384.0 3397.5 3399.0 3404.0 3405.0 mps-33a.tapx Page 4 • L~ 3424.5 3426.5 3447.5 3449.5 3477.0 3479.5 3485.5 3488.0 3497.0 3499.5 3518.0 3520.0 3525.0 3527.0 3539.0 3541.0 3552.5 3553.5 3586.0 3587.5 3588.0 3592.0 3599.0 3602.5 3609.5 3611.0 3625.0 3626.0 3656.5 3657.0 3679.0 3680.0 3691.5 3693.5 3699.5 3702.0 3709.0 3710.5 3711.5 3714.5 3733.5 3735.0 3751.5 3753.5 3767.0 3768.0 3775.5 3778.5 3779.5 3782.0 3797.5 3800.5 3813.5 3815.5 3900.5 3901.0 3909.5 3911.5 3925.5 3925.5 3936.0 3936.5 3954.0 3958.0 4009.0 4010.0 4020.5 4022.0 4045.5 4046.5 4052.0 4053.0 4068.0 4069.5 4073.0 4074.5 4076.0 4077.0 4115.5 4117.0 4126.5 4128.0 4132.5 4133.5 4137.0 4138.0 4174.5 4176.0 4178.0 4179.0 4191.5 4193.0 4194.0 4195.5 4228.5 4229.5 4255.0 4256.5 4260.0 4261.5 4263.0 4264.0 4280.0 4281.0 4282.0 4283.0 4307.5 4309.0 4310.0 4311.0 4311.5 4313.0 4323.5 4326.0 4331.5 4334.5 4338.0 4339.5 4360.0 4360.0 4366.5 4365.5 4373.0 4373.0 4382.0 4383.5 mps-33a.tapx Page 5 • • 4388.0 4389.5 4395.5 4396.5 4405.5 4407.0 4408.0 4408.5 4415.5 4415.5 4424.0 4424.5 4432.0 4433.0 4442.5 4444.0 4464.5 4465.0 4469.5 4470.5 4495.5 4496.0 4513.5 4514.5 4533.5 4535.0 4539.0 4539.5 4552.0 4553.0 4556.0 4557.0 4561.0 4562.0 4567.0 4567.0 4580.0 4582.0 4611.0 4611.0 4613.5 4614.0 4633.5 4634.5 4648.0 4648.5 4662.0 4663.5 4669.5 4671.0 4692.0 4692.0 4697.0 4699.0 4712.0 4712.5 4722.0 4723.0 4725.0 4726.0 4728.5 4730.0 4734.0 4734.0 4761.0 4760.5 4781.0 4780.5 4789.5 4790.5 4794.0 4796.0 4804.5 4806.0 4811.5 4813.0 4815.5 4816.5 4837.0 4837.5 4847.5 4847.5 4879.0 4879.5 4888.5 4889.0 4905.0 4906.5 4921.5 4924.0 4947.0 4948.5 4964.5 4966.5 4978.0 4979.5 4986.5 4987.5 4992.5 4993.5 4997.0 4998.5 5019.0 5020.5 5030.0 5030.5 5035.5 5037.0 5042.5 5043.0 5060.0 5061.5 5075.5 5075.0 5080.5 5080.5 5087.0 5088.0 5094.5 5095.5 5097.5 5097.5 5125.0 5126.5 5141.0 5142.5 mps-33a.tapx Page 6 ~1 U 5158.5 5161.5 5171.5 5189.5 5208.5 5210.5 5268.5 5275.5 5290.5 5299.0 5322.5 5497.5 MERGED PBU MWD REMARKS DATA SOURCE TOOL CODE 5160.5 5162.5 5172.5 5191.5 5210.5 5212.0 5270.0 5278.0 5293.5 5302.5 5325.0 5500.0 mps-33a.tapx BIT RUN NO MERGE TOP MERGE BASE 1 2630.5 5500.0 MERGED MAIN PASS. Data Format Specification Record Data Record Type... ..........0 Data specification Block Type.....0 Loging Di rection .................DOwn optical log depth units...........Feet Data Reference Point ..............Undefined Frame spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. .. ..... Datum Specification Block sub-type...0 Name service Order units size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 CALA MWD INCH 4 1 68 4 2 FCNT MWD CNTS 4 1 68 8 3 NCNT MWD CNTS 4 1 68 12 4 RHOB MWD G/CM 4 1 68 16 5 DRHO MWD G/CM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 RPM MWD OHMM 4 1 68 28 8 RPS MWD OHMM 4 1 68 32 9 RPX MWD OHMM 4 1 68 36 10 FET MWD HOUR 4 1 68 40 11 GR MWD API 4 1 68 44 12 PEF MWD BARN 4 1 68 48 13 ROP MWD FT/H 4 1 68 52 14 NPHI MwD PU-S 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2629 5497.5 4063.25 5738 2629 5497.5 GALA MWD INCH 8.27 12.65 9.12384 5323 2748.5 5409.5 FCNT MWD CNTS 442.9 2930.86 803.628 5279 2767.5 5406.5 NCNT MWD CNTS 104040 187662 125244 5279 2767.5 5406.5 RHOB MWD G/CM 0.596 3.069 2.15158 5305 2767.5 5419.5 DRHO MWD G/CM -2.589 0.325 0.0159131 5305 2767.5 5419.5 RPD MWD OHMM 0.15 2000 31.0943 5373 2767.5 5453.5 RPM MWD OHMM 0.19 2000 20.6171 5373 2767.5 5453.5 Page 7 • • mps-33a.tapx RPS MWD OHMM 0.13 1743.89 15.4009 5373 2767.5 5453.5 RPX MWD OHMM 0.14 1037.35 13.2436 5373 2767.5 5453.5 FET MWD HOUR 0.16 7.53 0.695349 5373 2767.5 5453.5 GR MwD API 5.65 134.59 68.6192 5665 2629 5461 PEF MWD BARN 0.67 12.64 2.41556 5305 2767.5 5419.5 ROP MWD FT/H 0.19 488.78 156.844 5416 2790 5497.5 NPHI MwD PU-S 13.01 93.25 39.3888 5279 2767.5 5406.5 First Reading For Entire File..........2629 Last Reading For Entire File...........5497.5 File Trailer Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/02 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLIB.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/02 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2630.5 5463.5 CALA 2750.5 5412.0 PEF 2770.0 5422.0 RPx 2770.0 5456.0 FET 2770.0 5456.0 RPS 2770.0 5456.0 NPHI 2770.0 5409.0 RPD 2770.0 5456.0 DRHO 2770.0 5422.0 RPM 2770.0 5456.0 RHOB 2770.0 5422.0 NCNT 2770.0 5409.0 FCNT 2770.0 5409.0 ROP 2792.5 5500.0 LOG HEADER DATA DATE LOGGED: Page 8 28-7AN-07 • SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 CTN ALD ACAL mps-33a.tapx BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 COMP THERMAL NEUTRON Azimuthal Litho-Dens Acoustic Caliper BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Di rection .................Down optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth units. .. .. ..... Datum Specification Block sub-type...0 • Insite 72.13 Memory 5500.0 2792.0 5500.0 27.2 50.8 TOOL NUMBER 536516 10505932 174114 188935 143795 8.500 2792.0 Fresh Water Gel 8.90 48.0 9.3 600 7.0 2.500 70.0 1.500 121.0 1.700 70.0 2.800 70.0 Name service Order Units Size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 Page 9 • • mps-33a.tapx CALA MWDO10 INCH 4 1 68 4 2 FCNT MWDO10 CNTS 4 1 68 8 3 NCNT MWDO10 CNTS 4 1 68 12 4 RHOB MwD010 G/CM 4 1 68 16 5 DRHO MWDO10 G/cM 4 1 68 20 6 RPD MWDO10 OHMM 4 1 68 24 7 RPM MWDO10 OHMM 4 1 68 28 8 RPS MWDO10 OHMM 4 1 68 32 9 RPX MWDO10 OHMM 4 1 68 36 10 FET MwD010 HOUR 4 1 68 40 11 GR MWDO10 API 4 1 68 44 12 PEF MwD010 BARN 4 1 68 48 13 ROP MWDO10 FT/H 4 1 68 52 14 NPHI MWD010 PU-S 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2630.5 5500 4065.25 5740 2630.5 5500 CALA MWDO10 INCH 8.27 12.65 9.12508 5324 2750.5 5412 FONT MWDO10 CNTS 441.5 2930.86 803.674 5279 2770 5409 NCNT MwD010 CNTS 104040 187662 125254 5279 2770 5409 RHOS MwD010 G/CM 0.596 3.069 2.15133 5305 2770 5422 DRHO MWDO10 G/CM -2.589 0.325 0.0157295 5305 2770 5422 RPD MwD010 OHMM 0.15 2000 31.3404 5373 2770 5456 RPM MWD010 OHMM 0.19 2000 20.8686 5373 2770 5456 RPS MWDO10 OHMM 0.13 1743.89 15.487 5373 2770 5456 RPX MWDO10 OHMM 0.14 1037.35 13.1942 5373 2770 5456 FET MWDO10 HOUR 0.16 7.53 0.695408 5373 2770 5456 GR MwD010 API 5.65 134.59 68.6079 5667 2630.5 5463.5 PEF MWDO10 BARN 0.67 12.64 2.41524 5305 2770 5422 ROP MWDO10 FT/H 0.19 488.78 156.999 5416 2792.5 5500 NPHI MwD010 Pu-s 13.01 93.25 39.374 5279 2770 5409 First Reading For Entire File..........2630.5 Last Reading For Entire File...........5500 File Trailer Service name... .......STSLI6.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/02 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.003 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................07/05/02 Origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Page 10 Reel Trailer Service name .............LISTPE Date . ...................07/05/02 Ori qin ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Physical EOF Physical EOF End Of LIS File mps-33a.tapx Writing Library. Page 11 Scientific Technical services