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Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: (907) 564-4891 02/09/2024 Mr. Mel Rixse Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Prudhoe Bay Surface Casing by Conductor Annulus Top-offs of Cement, Corrosion Inhibitor through 02/09/2024. Dear Mr. Rixse, Enclosed please find a copy of a spreadsheet with a list of Prudhoe Bay wells that were topped-off with cement, corrosion inhibitor in the surface casing by conductor annulus through 02/09/2024. Cement top-offs are executed as needed to mitigate the void space left at surface by minor cement fallback during the primary surface casing by conductor cement job. The remaining void space between the top of the cement and the top of the conductor is filled with a heavier than water corrosion inhibitor to reduce the risk of external surface casing corrosion. The attached spreadsheets include the well names, API and PTD numbers, treatment dates and volumes. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404 Report of Sundry Operations. If you have any additional questions, please contact me at 564-4891 or oliver.sternicki@hilcorp.com. Sincerely, Oliver Sternicki Well Integrity Supervisor Hilcorp North Slope, LLC Digitally signed by Oliver Sternicki DN: cn=Oliver Sternicki, c=US, o=Hilcorp North Slope LLC, ou=PBU, email=oliver.sternicki@hilcorp.com Date: 2024.02.09 11:15:58 -09'00' Oliver Sternicki Hilcorp North Slope LLC. Surface Casing by Conductor Annulus Cement, Corrosion Inhibitor Top-off Report of Sundry Operations (10-404) 02/09/2024 Well Name PTD # API # Initial top of cement (ft) Vol. of cement pumped (gal) Final top of cement (ft) Cement top off date Corrosion inhibitor (gal) Corrosion inhibitor/ sealant date L-293 223020 500292374900 30 8/29/2023 S-09A 214097 500292077101 2 9/19/2023 S-102A 223058 500292297201 2 9/19/2023 S-105A 219032 500292297701 10 9/19/2023 S-109 202245 500292313500 7 9/19/2023 S-110B 213198 500292303002 35 9/19/2023 S-113B 202143 500292309402 10 9/19/2023 S-115 202230 500292313000 4 9/19/2023 S-116A 213139 500292318301 4 9/19/2023 S-117 203012 500292313700 3 9/19/2023 S-118 203200 500292318800 9 9/19/2023 S-122 205081 500292326500 5 9/19/2023 S-125 207083 500292336100 2 9/19/2023 S-126 207097 500292336300 3 9/19/2023 S-134 209083 500292341300 35 9/19/2023 S-200A 217125 500292284601 7 9/19/2023 S-202 219120 500292364700 13 9/19/2023 S-210 219057 500292363000 10 9/19/2023 S-213A 204213 500292299301 4 9/19/2023 S-215 202154 500292310700 3 9/19/2023 S-216 200197 500292298900 4 9/19/2023 S-41A 210101 500292264501 3 9/19/2023 W-16A 203100 500292204501 2 9/23/2023 W-17A 205122 500292185601 3 9/23/2023 Well Name PTD #API # Initial top of cement (ft) Vol. of cement pumped (gal) Final top of cement (ft) Cement top off date Corrosion inhibitor (gal) Corrosion inhibitor/ sealant date W-19B 210065 500292200602 8 9/23/2023 W-21A 201111 500292192901 8 9/23/2023 W-32A 202209 500292197001 4 9/23/2023 W-201 201051 500292300700 44 9/23/2023 W-202 210133 500292343400 6 9/23/2023 W-204 206158 500292333300 3 9/23/2023 W-205 203116 500292316500 3 9/23/2023 W-207 203049 500292314500 3 9/23/2023 W-211 202075 500292308000 8 9/23/2023 W-213 207051 500292335400 3 9/23/2023 W-214 207142 500292337300 10 9/23/2023 W-215 203131 500292317200 2 9/23/2023 W-223 211006 500292344000 7 9/23/2023 Z-69 212076 500292347100 2.0 27 1.5 10/24/2023 S-128 210159 500292343600 11 12/27/2023 S-135 213202 500292350800 16 12/27/2023 V-113 202216 500292312500 24 12/31/2023 V-114A 203185 500292317801 5 12/31/2023 V-122 206147 500292332800 5 12/31/2023 V-205 206180 500292333800 2 12/31/2023 V-207 208066 500292339000 8 12/31/2023 V-214 205134 500292327500 5 12/31/2023 V-215 207041 500292335100 2 12/31/2023 V-218 207040 500292335000 5 12/31/2023 V-224 208154 500292340000 16 12/31/2023 V-225 209118 500292341900 6 12/31/2023 V-01 204090 500292321000 3 1/1/2024 V-02 204077 500292320900 5 1/1/2024 V-04 206134 500292332200 5 1/1/2024 V-102 202033 500292307000 8 1/1/2024 V-104 202142 500292310300 5 1/1/2024 V-220 208020 500292338300 4 1/1/2024 V-218 207040 500292335000 5 12/31/2023 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. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: WAG Injector V-218 (PTD #2070400) TxIA Communication Date:Tuesday, September 5, 2023 11:26:00 AM Attachments:image001.png From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, September 5, 2023 11:24 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: NOT OPERABLE: WAG Injector V-218 (PTD #2070400) TxIA Communication Mr. Wallace, On 08/28 Slickline installed a Water Flood Regulating Valve that was designed to regulate injection rate and allow sufficient backpressure on the tubing to monitor for IA re-pressurization. Initial tests indicated the regulator was working as designed. However, when operations attempted to put the well on injection, it locked up and would not take any fluid. At this time, the well will be classified as NOT OPERABLE and will remain shut-in. Slickline will return at a future date to troubleshoot the downhole problems. If they can sort out the injection problems, Hilcorp will seek AOGCC approval before re-starting injection. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Monday, August 14, 2023 12:25 PM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: RE: [EXTERNAL] Re: UPDATE UNDER EVALUATION: WAG Injector V-218 (PTD #207040) TxIA Communication Ryan, Thanks for the follow up call. Your request for an additional 28 days monitoring and diagnostics is approved. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privilegedinformation. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, August 11, 2023 8:13 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: RE: [EXTERNAL] Re: UPDATE UNDER EVALUATION: WAG Injector V-218 (PTD #207040) TxIA Communication Mr. Wallace, WAG Injector V-218 (PTD #207040) current 28 day under evaluation period expires on 08/14/23. The well was put on injection on 07/14 – 07/15, again with insufficient backpressure in the tubing to monitor IA re-pressurization. Slickline continued to troubleshoot WFR valves from 07/27 – 07/30 and 08/10 – present. With permission, I would like to extend the under evaluation period for an additional 28 days starting 08/14 for further slickline work / online monitoring. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Friday, July 14, 2023 1:17 PM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: Re: [EXTERNAL] Re: UPDATE UNDER EVALUATION: WAG Injector V-218 (PTD #207040) TxIA Communication Ryan, Your request of additional 28 days monitoring is approved. Regards, Chris From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, July 14, 2023 12:42:20 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: RE: [EXTERNAL] Re: UPDATE UNDER EVALUATION: WAG Injector V-218 (PTD #207040) TxIA Communication Mr. Wallace, WAG Injector V-218 (PTD #207040) remains under evaluation post passing AOGCC MIT-IA on 6/09/23 with the current previously approved 28 day period expiring on 7/17. During this time, the well was online from 6/28 – 7/6 however injection rate and pressure were not stable, and we suspect a water flood regulator is out of pocket or otherwise compromised. I would like to request an additional 28 day period starting 07/17 to continue troubleshooting injection valves with slickline and TxIA communication with the well online. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Friday, June 16, 2023 5:16 PM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: [EXTERNAL] Re: UPDATE UNDER EVALUATION: WAG Injector V-218 (PTD #207040) TxIA Communication Ryan, Your request for additional 28 days diagnostics and monitoring is approved. Regards, Chris From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, June 16, 2023 4:20:26 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UPDATE UNDER EVALUATION: WAG Injector V-218 (PTD #207040) TxIA Communication Mr. Wallace, WAG Injector V-218 (PTD #207040) passed AOGCC witnessed MIT-IA on 06/09/23. A dummy gas lift valve replaced a water flood regulator in station #4 to attempt to isolate injection into to a lower and separate zone below the packers set at 6574’, & 6687’ and behind station #2 on 06/15/23. The well is currently not taking fluid as we attempt to get it back on injection and determine if the DGLV in station #4 resolves the TxIA. The current 28 day under evaluation period expires on 06/19/23. I would like to request an additional 28 day period of monitoring to determine if the recent intervention resolves the previously identified TxIA and also to allow for submission and review of any AA request we may submit. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity Sent: Tuesday, May 23, 2023 6:29 PM To: 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov> Cc: 'Regg, James B (CED)' <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UPDATE UNDER EVALUATION: WAG Injector V-218 (PTD #207040) TxIA Communication Mr. Wallace, WAG Injector V-218 (PTD #207040) PPPOT-T passed to 5000 psi on 05/22/23 and MIT-IA passed while shut in to 3408 psi on 05/23/23. The evidence of recent bleeds with signs of TxIA pressure communication and passing MIT-IA suggests that there is a possible one-way TxIA or packer leak. I would like to request approval to put the well back on PWI injection for the remaining Under Evaluation period for additional pressure monitoring and online MIT to support a potential amended AA application. Plan Forward: 1. Operation: Put on injection w/ DHD support to bleed / monitor TxIA as needed 2. Fullbore: AOGCC MIT-IA 3. Well Integrity: Amend AA / Corrective action as required Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity Sent: Monday, May 22, 2023 10:30 AM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UNDER EVALUATION: WAG Injector V-218 (PTD #207040) TxIA Communication Mr. Wallace, WAG Injector V-218 (PTD #207040) is operating under AA AIO 26B.005 for slow IA pressure fall off. V-218 has been identified to have TxIA pressure communication during pressure bleeds conducted on 05/19 & 05/22. The well has been shut in as per AA AIO 26B.005, is now classified as UNDER EVALUATION and on a 28 day clock to be resolved. Plan Forward: 1. Fullbore: MIT-IA, LLR if fails 2. Well Integrity: Secure / further action as required Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Sent: Saturday, June 12, 2021 8:40 AM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Aras Worthington <Aras.Worthington@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com>; Leslie Reavis <lreavis@hilcorp.com>; Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Subject: OPERABLE: WAG Injector V-218 (PTD #207040) AA for continued WAG injection Mr. Wallace, WAG Injector V-218 (PTD #207040) Administrative Approval has been received for continued WAG injection (attached). The well is classified back to OPERABLE and now operates under AIO #26B.005 Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Sent: Tuesday, May 18, 2021 4:55 PM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Aras Worthington <Aras.Worthington@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com>; Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Subject: UNDER EVALUATION: WAG Injector V-218 (PTD #207040) possible IAxOA communication Mr. Wallace, WAG Injector V-218 (PTD #207040) has been identified as having possible IAxOA communication due to an anomalous decreasing trend of the IA pressure that is independent of temperature. The well is now classified as Under Evaluation and is on the 28-day clock for diagnostics. Plan Forward: 1. DHD/Fullbore: MIT-IA 2. Town Engineering: Pursue AA 3. Well Integrity: Additional diagnostics as needed Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considersappropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considersappropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considersappropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considersappropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: [EXTERNAL] Re: UPDATE UNDER EVALUATION: WAG Injector V-218 (PTD #207040) TxIA Communication Date:Monday, August 14, 2023 12:27:04 PM Attachments:image001.png From: Wallace, Chris D (OGC) Sent: Monday, August 14, 2023 12:25 PM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: RE: [EXTERNAL] Re: UPDATE UNDER EVALUATION: WAG Injector V-218 (PTD #207040) TxIA Communication Ryan, Thanks for the follow up call. Your request for an additional 28 days monitoring and diagnostics is approved. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privilegedinformation. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, August 11, 2023 8:13 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: RE: [EXTERNAL] Re: UPDATE UNDER EVALUATION: WAG Injector V-218 (PTD #207040) TxIA Communication Mr. Wallace, WAG Injector V-218 (PTD #207040) current 28 day under evaluation period expires on 08/14/23. The well was put on injection on 07/14 – 07/15, again with insufficient backpressure in the tubing to monitor IA re-pressurization. Slickline continued to troubleshoot WFR valves from 07/27 – 07/30 and 08/10 – present. With permission, I would like to extend the under evaluation period for an additional 28 days starting 08/14 for further slickline work / online monitoring. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Friday, July 14, 2023 1:17 PM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: Re: [EXTERNAL] Re: UPDATE UNDER EVALUATION: WAG Injector V-218 (PTD #207040) TxIA Communication Ryan, Your request of additional 28 days monitoring is approved. Regards, Chris From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, July 14, 2023 12:42:20 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: RE: [EXTERNAL] Re: UPDATE UNDER EVALUATION: WAG Injector V-218 (PTD #207040) TxIA Communication Mr. Wallace, WAG Injector V-218 (PTD #207040) remains under evaluation post passing AOGCC MIT-IA on 6/09/23 with the current previously approved 28 day period expiring on 7/17. During this time, the well was online from 6/28 – 7/6 however injection rate and pressure were not stable, and we suspect a water flood regulator is out of pocket or otherwise compromised. I would like to request an additional 28 day period starting 07/17 to continue troubleshooting injection valves with slickline and TxIA communication with the well online. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Friday, June 16, 2023 5:16 PM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: [EXTERNAL] Re: UPDATE UNDER EVALUATION: WAG Injector V-218 (PTD #207040) TxIA Communication Ryan, Your request for additional 28 days diagnostics and monitoring is approved. Regards, Chris From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, June 16, 2023 4:20:26 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UPDATE UNDER EVALUATION: WAG Injector V-218 (PTD #207040) TxIA Communication Mr. Wallace, WAG Injector V-218 (PTD #207040) passed AOGCC witnessed MIT-IA on 06/09/23. A dummy gas lift valve replaced a water flood regulator in station #4 to attempt to isolate injection into to a lower and separate zone below the packers set at 6574’, & 6687’ and behind station #2 on 06/15/23. The well is currently not taking fluid as we attempt to get it back on injection and determine if the DGLV in station #4 resolves the TxIA. The current 28 day under evaluation period expires on 06/19/23. I would like to request an additional 28 day period of monitoring to determine if the recent intervention resolves the previously identified TxIA and also to allow for submission and review of any AA request we may submit. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity Sent: Tuesday, May 23, 2023 6:29 PM To: 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov> Cc: 'Regg, James B (CED)' <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UPDATE UNDER EVALUATION: WAG Injector V-218 (PTD #207040) TxIA Communication Mr. Wallace, WAG Injector V-218 (PTD #207040) PPPOT-T passed to 5000 psi on 05/22/23 and MIT-IA passed while shut in to 3408 psi on 05/23/23. The evidence of recent bleeds with signs of TxIA pressure communication and passing MIT-IA suggests that there is a possible one-way TxIA or packer leak. I would like to request approval to put the well back on PWI injection for the remaining Under Evaluation period for additional pressure monitoring and online MIT to support a potential amended AA application. Plan Forward: 1. Operation: Put on injection w/ DHD support to bleed / monitor TxIA as needed 2. Fullbore: AOGCC MIT-IA 3. Well Integrity: Amend AA / Corrective action as required Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity Sent: Monday, May 22, 2023 10:30 AM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UNDER EVALUATION: WAG Injector V-218 (PTD #207040) TxIA Communication Mr. Wallace, WAG Injector V-218 (PTD #207040) is operating under AA AIO 26B.005 for slow IA pressure fall off. V-218 has been identified to have TxIA pressure communication during pressure bleeds conducted on 05/19 & 05/22. The well has been shut in as per AA AIO 26B.005, is now classified as UNDER EVALUATION and on a 28 day clock to be resolved. Plan Forward: 1. Fullbore: MIT-IA, LLR if fails 2. Well Integrity: Secure / further action as required Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Sent: Saturday, June 12, 2021 8:40 AM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Aras Worthington <Aras.Worthington@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com>; Leslie Reavis <lreavis@hilcorp.com>; Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Subject: OPERABLE: WAG Injector V-218 (PTD #207040) AA for continued WAG injection Mr. Wallace, WAG Injector V-218 (PTD #207040) Administrative Approval has been received for continued WAG injection (attached). The well is classified back to OPERABLE and now operates under AIO #26B.005 Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Sent: Tuesday, May 18, 2021 4:55 PM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Aras Worthington <Aras.Worthington@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com>; Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Subject: UNDER EVALUATION: WAG Injector V-218 (PTD #207040) possible IAxOA communication Mr. Wallace, WAG Injector V-218 (PTD #207040) has been identified as having possible IAxOA communication due to an anomalous decreasing trend of the IA pressure that is independent of temperature. The well is now classified as Under Evaluation and is on the 28-day clock for diagnostics. Plan Forward: 1. DHD/Fullbore: MIT-IA 2. Town Engineering: Pursue AA 3. Well Integrity: Additional diagnostics as needed Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considersappropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considersappropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considersappropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: [EXTERNAL] Re: UPDATE UNDER EVALUATION: WAG Injector V-218 (PTD #207040) TxIA Communication Date:Wednesday, July 26, 2023 9:38:50 AM Attachments:image001.png From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Friday, July 14, 2023 1:17 PM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: Re: [EXTERNAL] Re: UPDATE UNDER EVALUATION: WAG Injector V-218 (PTD #207040) TxIA Communication Ryan, Your request of additional 28 days monitoring is approved. Regards, Chris From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, July 14, 2023 12:42:20 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: RE: [EXTERNAL] Re: UPDATE UNDER EVALUATION: WAG Injector V-218 (PTD #207040) TxIA Communication Mr. Wallace, WAG Injector V-218 (PTD #207040) remains under evaluation post passing AOGCC MIT-IA on 6/09/23 with the current previously approved 28 day period expiring on 7/17. During this time, the well was online from 6/28 – 7/6 however injection rate and pressure were not stable, and we suspect a water flood regulator is out of pocket or otherwise compromised. I would like to request an additional 28 day period starting 07/17 to continue troubleshooting injection valves with slickline and TxIA communication with the well online. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Friday, June 16, 2023 5:16 PM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: [EXTERNAL] Re: UPDATE UNDER EVALUATION: WAG Injector V-218 (PTD #207040) TxIA Communication Ryan, Your request for additional 28 days diagnostics and monitoring is approved. Regards, Chris From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, June 16, 2023 4:20:26 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UPDATE UNDER EVALUATION: WAG Injector V-218 (PTD #207040) TxIA Communication Mr. Wallace, WAG Injector V-218 (PTD #207040) passed AOGCC witnessed MIT-IA on 06/09/23. A dummy gas lift valve replaced a water flood regulator in station #4 to attempt to isolate injection into to a lower and separate zone below the packers set at 6574’, & 6687’ and behind station #2 on 06/15/23. The well is currently not taking fluid as we attempt to get it back on injection and determine if the DGLV in station #4 resolves the TxIA. The current 28 day under evaluation period expires on 06/19/23. I would like to request an additional 28 day period of monitoring to determine if the recent intervention resolves the previously identified TxIA and also to allow for submission and review of any AA request we may submit. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity Sent: Tuesday, May 23, 2023 6:29 PM To: 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov> Cc: 'Regg, James B (CED)' <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UPDATE UNDER EVALUATION: WAG Injector V-218 (PTD #207040) TxIA Communication Mr. Wallace, WAG Injector V-218 (PTD #207040) PPPOT-T passed to 5000 psi on 05/22/23 and MIT-IA passed while shut in to 3408 psi on 05/23/23. The evidence of recent bleeds with signs of TxIA pressure communication and passing MIT-IA suggests that there is a possible one-way TxIA or packer leak. I would like to request approval to put the well back on PWI injection for the remaining Under Evaluation period for additional pressure monitoring and online MIT to support a potential amended AA application. Plan Forward: 1. Operation: Put on injection w/ DHD support to bleed / monitor TxIA as needed 2. Fullbore: AOGCC MIT-IA 3. Well Integrity: Amend AA / Corrective action as required Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity Sent: Monday, May 22, 2023 10:30 AM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UNDER EVALUATION: WAG Injector V-218 (PTD #207040) TxIA Communication Mr. Wallace, WAG Injector V-218 (PTD #207040) is operating under AA AIO 26B.005 for slow IA pressure fall off. V-218 has been identified to have TxIA pressure communication during pressure bleeds conducted on 05/19 & 05/22. The well has been shut in as per AA AIO 26B.005, is now classified as UNDER EVALUATION and on a 28 day clock to be resolved. Plan Forward: 1. Fullbore: MIT-IA, LLR if fails 2. Well Integrity: Secure / further action as required Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Sent: Saturday, June 12, 2021 8:40 AM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Aras Worthington <Aras.Worthington@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com>; Leslie Reavis <lreavis@hilcorp.com>; Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Subject: OPERABLE: WAG Injector V-218 (PTD #207040) AA for continued WAG injection Mr. Wallace, WAG Injector V-218 (PTD #207040) Administrative Approval has been received for continued WAG injection (attached). The well is classified back to OPERABLE and now operates under AIO #26B.005 Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Sent: Tuesday, May 18, 2021 4:55 PM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Aras Worthington <Aras.Worthington@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com>; Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Subject: UNDER EVALUATION: WAG Injector V-218 (PTD #207040) possible IAxOA communication Mr. Wallace, WAG Injector V-218 (PTD #207040) has been identified as having possible IAxOA communication due to an anomalous decreasing trend of the IA pressure that is independent of temperature. The well is now classified as Under Evaluation and is on the 28-day clock for diagnostics. Plan Forward: 1. DHD/Fullbore: MIT-IA 2. Town Engineering: Pursue AA 3. Well Integrity: Additional diagnostics as needed Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considersappropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considersappropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: [EXTERNAL] Re: UPDATE UNDER EVALUATION: WAG Injector V-218 (PTD #207040) TxIA Communication Date:Tuesday, July 18, 2023 8:48:56 AM Attachments:image001.png From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Friday, July 14, 2023 1:17 PM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: Re: [EXTERNAL] Re: UPDATE UNDER EVALUATION: WAG Injector V-218 (PTD #207040) TxIA Communication Ryan, Your request of additional 28 days monitoring is approved. Regards, Chris From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, July 14, 2023 12:42:20 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: RE: [EXTERNAL] Re: UPDATE UNDER EVALUATION: WAG Injector V-218 (PTD #207040) TxIA Communication Mr. Wallace, WAG Injector V-218 (PTD #207040) remains under evaluation post passing AOGCC MIT-IA on 6/09/23 with the current previously approved 28 day period expiring on 7/17. During this time, the well was online from 6/28 – 7/6 however injection rate and pressure were not stable, and we suspect a water flood regulator is out of pocket or otherwise compromised. I would like to request an additional 28 day period starting 07/17 to continue troubleshooting injection valves with slickline and TxIA communication with the well online. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Friday, June 16, 2023 5:16 PM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: [EXTERNAL] Re: UPDATE UNDER EVALUATION: WAG Injector V-218 (PTD #207040) TxIA Communication Ryan, Your request for additional 28 days diagnostics and monitoring is approved. Regards, Chris From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, June 16, 2023 4:20:26 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UPDATE UNDER EVALUATION: WAG Injector V-218 (PTD #207040) TxIA Communication Mr. Wallace, WAG Injector V-218 (PTD #207040) passed AOGCC witnessed MIT-IA on 06/09/23. A dummy gas lift valve replaced a water flood regulator in station #4 to attempt to isolate injection into to a lower and separate zone below the packers set at 6574’, & 6687’ and behind station #2 on 06/15/23. The well is currently not taking fluid as we attempt to get it back on injection and determine if the DGLV in station #4 resolves the TxIA. The current 28 day under evaluation period expires on 06/19/23. I would like to request an additional 28 day period of monitoring to determine if the recent intervention resolves the previously identified TxIA and also to allow for submission and review of any AA request we may submit. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity Sent: Tuesday, May 23, 2023 6:29 PM To: 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov> Cc: 'Regg, James B (CED)' <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UPDATE UNDER EVALUATION: WAG Injector V-218 (PTD #207040) TxIA Communication Mr. Wallace, WAG Injector V-218 (PTD #207040) PPPOT-T passed to 5000 psi on 05/22/23 and MIT-IA passed while shut in to 3408 psi on 05/23/23. The evidence of recent bleeds with signs of TxIA pressure communication and passing MIT-IA suggests that there is a possible one-way TxIA or packer leak. I would like to request approval to put the well back on PWI injection for the remaining Under Evaluation period for additional pressure monitoring and online MIT to support a potential amended AA application. Plan Forward: 1. Operation: Put on injection w/ DHD support to bleed / monitor TxIA as needed 2. Fullbore: AOGCC MIT-IA 3. Well Integrity: Amend AA / Corrective action as required Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity Sent: Monday, May 22, 2023 10:30 AM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UNDER EVALUATION: WAG Injector V-218 (PTD #207040) TxIA Communication Mr. Wallace, WAG Injector V-218 (PTD #207040) is operating under AA AIO 26B.005 for slow IA pressure fall off. V-218 has been identified to have TxIA pressure communication during pressure bleeds conducted on 05/19 & 05/22. The well has been shut in as per AA AIO 26B.005, is now classified as UNDER EVALUATION and on a 28 day clock to be resolved. Plan Forward: 1. Fullbore: MIT-IA, LLR if fails 2. Well Integrity: Secure / further action as required Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Sent: Saturday, June 12, 2021 8:40 AM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Aras Worthington <Aras.Worthington@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com>; Leslie Reavis <lreavis@hilcorp.com>; Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Subject: OPERABLE: WAG Injector V-218 (PTD #207040) AA for continued WAG injection Mr. Wallace, WAG Injector V-218 (PTD #207040) Administrative Approval has been received for continued WAG injection (attached). The well is classified back to OPERABLE and now operates under AIO #26B.005 Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Sent: Tuesday, May 18, 2021 4:55 PM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Aras Worthington <Aras.Worthington@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com>; Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Subject: UNDER EVALUATION: WAG Injector V-218 (PTD #207040) possible IAxOA communication Mr. Wallace, WAG Injector V-218 (PTD #207040) has been identified as having possible IAxOA communication due to an anomalous decreasing trend of the IA pressure that is independent of temperature. The well is now classified as Under Evaluation and is on the 28-day clock for diagnostics. Plan Forward: 1. DHD/Fullbore: MIT-IA 2. Town Engineering: Pursue AA 3. Well Integrity: Additional diagnostics as needed Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considersappropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considersappropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UPDATE UNDER EVALUATION: WAG Injector V-218 (PTD #207040) TxIA Communication Date:Tuesday, June 20, 2023 8:45:54 AM Attachments:image001.png From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Friday, June 16, 2023 5:16 PM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: Re: UPDATE UNDER EVALUATION: WAG Injector V-218 (PTD #207040) TxIA Communication Ryan, Your request for additional 28 days diagnostics and monitoring is approved. Regards, Chris From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, June 16, 2023 4:20:26 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UPDATE UNDER EVALUATION: WAG Injector V-218 (PTD #207040) TxIA Communication Mr. Wallace, WAG Injector V-218 (PTD #207040) passed AOGCC witnessed MIT-IA on 06/09/23. A dummy gas lift valve replaced a water flood regulator in station #4 to attempt to isolate injection into to a lower and separate zone below the packers set at 6574’, & 6687’ and behind station #2 on 06/15/23. The well is currently not taking fluid as we attempt to get it back on injection and determine if the DGLV in station #4 resolves the TxIA. The current 28 day under evaluation period expires on 06/19/23. I would like to request an additional 28 day period of monitoring to determine if the recent intervention resolves the previously identified TxIA and also to allow for submission and review of any AA request we may submit. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity Sent: Tuesday, May 23, 2023 6:29 PM To: 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov> Cc: 'Regg, James B (CED)' <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UPDATE UNDER EVALUATION: WAG Injector V-218 (PTD #207040) TxIA Communication Mr. Wallace, WAG Injector V-218 (PTD #207040) PPPOT-T passed to 5000 psi on 05/22/23 and MIT-IA passed while shut in to 3408 psi on 05/23/23. The evidence of recent bleeds with signs of TxIA pressure communication and passing MIT-IA suggests that there is a possible one-way TxIA or packer leak. I would like to request approval to put the well back on PWI injection for the remaining Under Evaluation period for additional pressure monitoring and online MIT to support a potential amended AA application. Plan Forward: 1. Operation: Put on injection w/ DHD support to bleed / monitor TxIA as needed 2. Fullbore: AOGCC MIT-IA 3. Well Integrity: Amend AA / Corrective action as required Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity Sent: Monday, May 22, 2023 10:30 AM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UNDER EVALUATION: WAG Injector V-218 (PTD #207040) TxIA Communication Mr. Wallace, WAG Injector V-218 (PTD #207040) is operating under AA AIO 26B.005 for slow IA pressure fall off. V-218 has been identified to have TxIA pressure communication during pressure bleeds conducted on 05/19 & 05/22. The well has been shut in as per AA AIO 26B.005, is now classified as UNDER EVALUATION and on a 28 day clock to be resolved. Plan Forward: 1. Fullbore: MIT-IA, LLR if fails 2. Well Integrity: Secure / further action as required Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Sent: Saturday, June 12, 2021 8:40 AM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Aras Worthington <Aras.Worthington@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com>; Leslie Reavis <lreavis@hilcorp.com>; Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Subject: OPERABLE: WAG Injector V-218 (PTD #207040) AA for continued WAG injection Mr. Wallace, WAG Injector V-218 (PTD #207040) Administrative Approval has been received for continued WAG injection (attached). The well is classified back to OPERABLE and now operates under AIO #26B.005 Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Sent: Tuesday, May 18, 2021 4:55 PM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Aras Worthington <Aras.Worthington@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com>; Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Subject: UNDER EVALUATION: WAG Injector V-218 (PTD #207040) possible IAxOA communication Mr. Wallace, WAG Injector V-218 (PTD #207040) has been identified as having possible IAxOA communication due to an anomalous decreasing trend of the IA pressure that is independent of temperature. The well is now classified as Under Evaluation and is on the 28-day clock for diagnostics. Plan Forward: 1. DHD/Fullbore: MIT-IA 2. Town Engineering: Pursue AA 3. Well Integrity: Additional diagnostics as needed Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considersappropriate. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 27, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC V-218 PRUDHOE BAY UN ORIN V-218 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/27/2023 V-218 50-029-23350-00-00 207-040-0 W SPT 4516 2070400 3200 1433 1507 1413 1402 113 116 120 122 OTHER P Sully Sullivan 6/9/2023 Well brought back online as water injection only and Performed flowing MIT for potential amended AA aplication Per Chris Wallace. AIO 26B.005 Tested to 3500 for 500psi dp 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN ORIN V-218 Inspection Date: Tubing OA Packer Depth 1396 3516 3407 3388IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS230609155534 BBL Pumped:1.6 BBL Returned:1.6 Thursday, July 27, 2023 Page 1 of 1 Test due 5/31/20234; MITIA pass 5/22/2023 (shut in; not witnessed) -- jbr 1 Regg, James B (OGC) From:PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent:Friday, June 2, 2023 12:33 PM To:Brooks, Phoebe L (OGC); Regg, James B (OGC); Wallace, Chris D (OGC) Cc:PB Wells Integrity Subject:Hilcorp (PBU) May 2023 MIT Forms Attachments:May 2023.zip All, AƩached are the completed AOGCC MIT forms for the tests performed in May 2023 by Hilcorp North Slope, LLC Well: PTD: Notes: 01‐31 1861320 MIT‐T & CMIT‐TxIA per Sundry #323‐075 04‐43 1940130 2‐year MIT‐IA & MIT‐T per AA AIO 4G.006 09‐10 1760820 2‐year MIT‐IA per AA AIO 4E.025 13‐01 1780600 MIT‐T per P&A sundry #323‐074 13‐19 1811800 2‐year MIT‐T per CO 736 13‐20 1820090 2‐year MIT‐T per CO 736 L‐119A 2191550 2‐year MIT‐IA per AA AIO 24B.007 LGI‐02 1861400 4‐year MIT‐IA LGI‐10 1860690 4‐year MIT‐IA NGI‐04 1860690 2‐year MIT‐IA for AA AIO 4E.024 P2‐15A 2070320 4‐year MIT‐IA P2‐16 1931230 4‐year MIT‐IA R‐03B 2101290 4‐year MIT‐IA S‐06 1821650 4‐year MIT‐IA S‐25A 1982140 2‐year MIT‐IA AA AIO 4F.005 V‐120A 2221210 IniƟal MIT‐IA post CTD sidetrack V‐121 2070360 4‐year MIT‐IA V‐218 2070400 2‐year MIT‐IA per AA AIO 26B.005 V‐218 2070400 Offline, non‐witnessed MIT‐IA aŌer well was made Under EvaluaƟon W‐20 1880460 MIT‐IA to inform AA applicaƟon W‐210 2061850 4‐year MIT‐IA WGI‐01 1790310 MIT‐T per Sundry #323‐036 Z‐12 1891020 4‐year MIT‐IA Please reply with quesƟons or concerns. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659‐5102 M: (307)399‐3816 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. PBU V-218PTD 2070400 Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 2070400 Type Inj N Tubing 0 0 0 0 Type Test P Packer TVD 4516 BBL Pump 3.0 IA 95 3480 3426 3408 Interval O Test psi 1500 BBL Return 2.9 OA 119 131 133 133 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: Notes: Notes: Hilcorp North Slope LLC Prudhoe Bay / PBU / V Pad Ryan Holt 05/23/23 Notes:Under Evaluation for TxIA MIT-IA Notes: Notes: Notes: V-218 Form 10-426 (Revised 01/2017)2023-0523_MIT_PBU_V-218 J. Regg CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UPDATE UNDER EVALUATION: WAG Injector V-218 (PTD #207040) TxIA Communication Date:Wednesday, May 24, 2023 10:17:43 AM Attachments:image001.png From: Wallace, Chris D (OGC) Sent: Wednesday, May 24, 2023 10:17 AM To: 'PB Wells Integrity' <PBWellsIntegrity@hilcorp.com> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: RE: UPDATE UNDER EVALUATION: WAG Injector V-218 (PTD #207040) TxIA Communication Ryan, Your request to continue water only injection for monitoring and diagnostics with the plan forward as below is approved. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, May 23, 2023 6:29 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UPDATE UNDER EVALUATION: WAG Injector V-218 (PTD #207040) TxIA Communication Mr. Wallace, WAG Injector V-218 (PTD #207040) PPPOT-T passed to 5000 psi on 05/22/23 and MIT-IA passed while shut in to 3408 psi on 05/23/23. The evidence of recent bleeds with signs of TxIA pressure communication and passing MIT-IA suggests that there is a possible one-way TxIA or packer leak. I would like to request approval to put the well back on PWI injection for the remaining Under Evaluation period for additional pressure monitoring and online MIT to support a potential amended AA application. Plan Forward: 1. Operation: Put on injection w/ DHD support to bleed / monitor TxIA as needed 2. Fullbore: AOGCC MIT-IA 3. Well Integrity: Amend AA / Corrective action as required Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity Sent: Monday, May 22, 2023 10:30 AM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UNDER EVALUATION: WAG Injector V-218 (PTD #207040) TxIA Communication Mr. Wallace, WAG Injector V-218 (PTD #207040) is operating under AA AIO 26B.005 for slow IA pressure fall off. V-218 has been identified to have TxIA pressure communication during pressure bleeds conducted on 05/19 & 05/22. The well has been shut in as per AA AIO 26B.005, is now classified as UNDER EVALUATION and on a 28 day clock to be resolved. Plan Forward: 1. Fullbore: MIT-IA, LLR if fails 2. Well Integrity: Secure / further action as required Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Sent: Saturday, June 12, 2021 8:40 AM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Aras Worthington <Aras.Worthington@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com>; Leslie Reavis <lreavis@hilcorp.com>; Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Subject: OPERABLE: WAG Injector V-218 (PTD #207040) AA for continued WAG injection Mr. Wallace, WAG Injector V-218 (PTD #207040) Administrative Approval has been received for continued WAG injection (attached). The well is classified back to OPERABLE and now operates under AIO #26B.005 Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Sent: Tuesday, May 18, 2021 4:55 PM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Aras Worthington <Aras.Worthington@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com>; Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Subject: UNDER EVALUATION: WAG Injector V-218 (PTD #207040) possible IAxOA communication Mr. Wallace, WAG Injector V-218 (PTD #207040) has been identified as having possible IAxOA communication due to an anomalous decreasing trend of the IA pressure that is independent of temperature. The well is now classified as Under Evaluation and is on the 28-day clock for diagnostics. Plan Forward: 1. DHD/Fullbore: MIT-IA 2. Town Engineering: Pursue AA 3. Well Integrity: Additional diagnostics as needed Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considersappropriate. Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 2070400 Type Inj N Tubing 0 0 0 0 Type Test P Packer TVD 4516 BBL Pump 3.0 IA 95 3480 3426 3408 Interval O Test psi 1500 BBL Return 2.9 OA 119 131 133 133 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: Hilcorp North Slope LLC Prudhoe Bay / PBU / V Pad Ryan Holt 05/23/23 Notes:Under Evaluation for TxIA MIT-IA Notes: Notes: Notes: V-218 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: Notes: Notes: Form 10-426 (Revised 01/2017)MIT PBU V-218 05-23-23 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: WAG Injector V-218 (PTD #207040) TxIA Communication Date:Tuesday, May 23, 2023 10:44:47 AM Attachments:image001.pngV-218 TIO & Inj plots.docx From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Monday, May 22, 2023 10:30 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UNDER EVALUATION: WAG Injector V-218 (PTD #207040) TxIA Communication Mr. Wallace, WAG Injector V-218 (PTD #207040) is operating under AA AIO 26B.005 for slow IA pressure fall off. V-218 has been identified to have TxIA pressure communication during pressure bleeds conducted on 05/19 & 05/22. The well has been shut in as per AA AIO 26B.005, is now classified as UNDER EVALUATION and on a 28 day clock to be resolved. Plan Forward: 1. Fullbore: MIT-IA, LLR if fails 2. Well Integrity: Secure / further action as required Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Sent: Saturday, June 12, 2021 8:40 AM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Aras Worthington <Aras.Worthington@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com>; Leslie Reavis <lreavis@hilcorp.com>; Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Subject: OPERABLE: WAG Injector V-218 (PTD #207040) AA for continued WAG injection Mr. Wallace, WAG Injector V-218 (PTD #207040) Administrative Approval has been received for continued WAG injection (attached). The well is classified back to OPERABLE and now operates under AIO #26B.005 Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Sent: Tuesday, May 18, 2021 4:55 PM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Aras Worthington <Aras.Worthington@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com>; Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Subject: UNDER EVALUATION: WAG Injector V-218 (PTD #207040) possible IAxOA communication Mr. Wallace, WAG Injector V-218 (PTD #207040) has been identified as having possible IAxOA communication due to an anomalous decreasing trend of the IA pressure that is independent of temperature. The well is now classified as Under Evaluation and is on the 28-day clock for diagnostics. Plan Forward: 1. DHD/Fullbore: MIT-IA 2. Town Engineering: Pursue AA 3. Well Integrity: Additional diagnostics as needed Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considersappropriate. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, June 16, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC V-218 PRUDHOE BAY UN ORIN V-218 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/16/2023 V-218 50-029-23350-00-00 207-040-0 W SPT 4516 2070400 3200 1542 1565 1548 1530 155 162 170 172 REQVAR P Adam Earl 5/7/2023 MIT-IA tested as per AIO 26B.005 to MAIP. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN ORIN V-218 Inspection Date: Tubing OA Packer Depth 689 3512 3390 3372IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE230510171157 BBL Pumped:2.5 BBL Returned:2 Friday, June 16, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 9 99 9 9 9 AIO 26B.005 James B. Regg Digitally signed by James B. Regg Date: 2023.06.16 12:32:01 -08'00' Wallace, Chris D (CED) From: Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity@hilcorp.com> Sent: Saturday, June 12, 2021 8:40 AM To: Wallace, Chris D (CED) Cc: Regg, James B (CED); Aras Worthington; Oliver Sternicki; John Condio - (C); Leslie Reavis; Alaska NS - PB - Field Well Integrity Subject: OPERABLE: WAG Injector V-218 (PTD #207040) AA for continued WAG injection Attachments: A1026B.005.pdf Mr. Wallace, WAG Injector V-218 (PTD #207040) Administrative Approval has been received for continued WAG injection (attached). The well is classified back to OPERABLE and now operates under AIO #2613.005 Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity/ Compliance andrew.or?r?C@hilcorD.com P: (907) 659-5102 M: (307)399-3816 From: Alaska NS - P -,,Field Well Integrity <PBFieldWelllntegrity@hilcorp.com> Sent: Tuesday, May 18, 20214:55 PM To: chris.wallace@alaska.gov, Cc: Regg, lames B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Aras Worthington <Aras.Worthington@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com>; Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity@hilcorp.com> Subject: UNDER EVALUATION: WAG Injector V,218 (PTD #207040) possible IAxOA communication Mr. Wallace, WAG Injector V-218 (PTD #207040) has been identified as having possible IAxOA communication due to an anomalous decreasing trend of the IA pressure that is independent of temperature. The well is now classified as Under Evaluation and is on the 28 -day clock for diagnostics. Plan Forward: 1. DHD/Fullbore: MIT -IA 2. Town Engineering: Pursue AA 3. Well Integrity: Additional diagnostics as needed Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.oRe(@hilcoro.com P: (907) 659-5102 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 61it I ZfIZf DATE: Wednesday, May 26, 2021 P.I. Supervisor ��� SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC V-218 FROM: Lou Laubenstein PRUDHOE BAY UN ORIN V-218 Petroleum Inspector Sre: Inspector Reviewed By: P.I. Suprv. NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UN ORIN V-218 API Well Number 50-029-23350-00-00 Inspector Name: Lou Laubenstein Permit Number: 207-040-0 Inspection Date: 5/25/2021 Insp Num: mitLOL210526080420 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1 V-218 .Tye nj W , TVD 4516 - Tubing 909 911 910 - 909 ' PTD 2070400 - Type Test SPT Test psi 3200 ^ IA 438 3347 - 3260 _ 3244 - BBL Pumped: 3.6 - BBL Returned: 3.6 OA 200 210 _ 217 220 Interval OTHER - P/F P Notes' MIT -IA to 3200 psi for AA application. Wednesday, May 26, 2021 Page I of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,November 08,2017 TO: im Re gg Wen a �/1241 P.I.Supervisor � PSUBJECT:Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. V-218 FROM: Bob Noble PRUDHOE BAY UN ORIN V-218 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry SBR--- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN ORIN V-218 API Well Number 50-029-23350-00-00 Inspector Name: Bob Noble Permit Number: 207-040-0 Inspection Date: 11/7/2017 v Insp Num: mitRCN171108054009 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well v-zls Type Inj w ,TVD 4516 Tubing 993 • 993 989 - 994 - PTD ,2070400 Type Test SPT Test psi 1500 IA 816 2005 ' 1961 - 1959 - 1 BBL Pumped: I , BBL Returned: 0.5 - OA 241 •I 243 'i 247 -I 247 - Interval 4YRTST P/F P Notes: Wednesday,November 08,2017 Page 1 of 1 • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator[AKDCWelllntegrityCoordinator @bp.com] Sent: Monday, October 28, 2013 1:42 PM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers;AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr;AK, OPS Well Pad LV; Chou, Irwin; Wallace, Chris D(DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; Climer, Laurie A Subject: RE: NOT OPERABLE: Injector V-218(PTD#2070400)Failing MIT-IA All, Correction:V-218(PTD#2070400) is a WAG injector, NOT a producer. Regards, Laurie Climer iter°ttate:.lack !)isl low) BP Alaska - Well Integrity Coordinator irj twif‘3 Urgan.zot 0,1 SCANNED DU t 2 32013 WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator(a@BP.com From: AK, D&C Well Integrity Coordinator Sent: Monday, October 28, 2013 1:28 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad LV; Chou, Irwin; 'chris.wallace @alaska.gov'; 'jim.regg @alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; Climer, Laurie A Subject: NOT OPERABLE: Producer V-102 (PTD #2070400) Failing MIT-IA All, Producer V-218(PTD#2070400)failed a screening MIT-IA on October 27,2013.The well was shut in,and reclassified as Not Operable. Further diagnostics will be performed to determine the source of the failure. 90 day TIO and injection plots along with the wellbore schematic have been included for reference. Please call with any questions. Thank you, Laurie Climer 1 ,1Iteielute:Jack!?isbromv) • • BP Alaska — Well Integrity Coordinator WIC Office: 907.659.5102 WIC Email: AKDCWeIIIntegrityCoordinator @BP.com 2 ■•■■■ • Injector V-218(PTD #2070400) 90 day TIO Plot 10/28/2013 -u-v-1111 MO• Tbc • 00CIA VO0 Ce103,13 0(91.0n3 08n/13 0e/i,013 1113.113 000.713 osiull 0E413 10403 10,12.13 10,19/13 MOi13 Injection Plot COO 1.600 Ana I IACO• ‘.3C0 1.200 4(0 300 , tan —%IV aro SCO ACO 500 300 ICO Cain] 1e00,13 [VMS 062'013 Oe.nin3 064/013 innari3 Min?, osaal, 7, • TREE= 4-1/16'CNV SAF TES:H2S READINGS AVERAGEI25 ppm WELLHEAD= FMC V-21 8 WHEN ON MI,WaL REQUIRES SSSV WHEN ON W. ACTUATOR= LEO OA CEMENTED TO SURFACE'**HES PKR @ 6574'IS KB.ELEV= 28.5' I ►4 ' I "FULL TO RELEASE BUT CAN ALSO BE RELEASED BY BF. ELEV= 53.5 / ,4 PRESSURE. DO NOT EXCEED 2000 PSI ON THE IA w LOUT KOP 300' ►j PERFORMING TBG MOVEMENT CALCULATION'S& Max Angle= 57"@ 3606 120 CONDUCTOR H 108' ■ DISCUSSING w/APE"' Datum NO 6521' �� i Datum TV D= 4400'SS D t 2491' H 3-1/2"HES X NIP,ID=2.813" 1 19-5/8"HES ES CEMENTER H 3010' GAS LIFT MANDRELS I9-518"CSG,40#,L-80 BTC,ID=8.835" H 3231' ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 6493 4465 in WC DMY RK 0 05/21/07 7"CSG,#26,L-80 TCII XO TO VAM TOP HC H 4727' x WATERFLOOD INJECTION MANDRELS 7"CSG,#26,L-80 VAM TOP HC XO TO BTC-M H 5251' x ST NO TVD DEV TYPE VLV LATCH PORT DATE 5 6599 4532 50 MMG-W DMY RK 0 04!13/07 4 6648 4563 50 MMG-W P-15XJR RK 9 04/06/11 3 6713 4605 49 MMG-W DMY RK 0 04/13/07 2 6801 4663 49 MMG-W P-1 5X/R RK 17 04/06/11 17"MARKER JOINT w/RA TAG H 5958' 1 6978 4781 48 MMG-W P-15XJR RK 8 04/06111 6553' —13-1/2"/2"HES X NIP,ID=2.813" 1 Minimum ID = 2.75" @ 7028' 3-1/2" HES XN NIPPLE Fq1 ( 6574' 1-{7"X 3-112"HES DUAL (FEEDTHRU PKR,ID=2.965" I8 1 6587' H PHOENIX PRES/TEMP SENSOR SUB,ID=2.992" MP 13-1/2"MARKER JOINT w/RA TAG H 6608' 1 U NIP ' I 6672' 1-13-1/2"HES X NIP,ID=2.813" 1 I=4 I2� 6687' 1-17"X 3-112"HES SINGLE I� FEEDTHRU PKR,ID=2.965" III- f 6701' IH PHOENIX SENSOR SUB,ID=2.992" 7"MARKER JOINT w/RA TAG II NIP R PERFORATION SUMMARY ��� z--1 6903' 117"X 3-1/2"HES SINGLE REF LOG:SLB USIT ON 04/11/07 I FEEDTHRU PKR,ID=2.965" ANGLE AT TOP PERF: 50*@ 6608' Note:Refer to Production DB for historical pert data I ( 6926' H 3-1/7'HES X NIP,ID=2.813" SIZE SPF ZONE INTERVAL Opn/Sqz DATE 4-1/2" 5 OA 6608-6653 0 04/11/07 NIP U 4-1/2" 5 OBa 6708-6753 0 04/11/07 4-1/2" 5 OBb 6773-6793 0 04/11/07 I ( 7007' 1-13-1/2"HES X NIP,ID=2.813" 1 4-1/7' 5 OBd 6926-6983 0 04/11/07 1111 1 7028' I-13-1/2"HES XN NIP,ID=2.75" 7028' —j3-1/2"HES PXN(05/19/07) I 13-1/2"TBG,9.2#,L-80 TCII,.0087 bpf,ID=2.992" H 7050' . { 7050' H 3-1/2"YVLEC,ID=2.992" --I ELMD NOT LOGGED ' PBTD 7186' #�����1�111�f1r��1�8 17"CSG,#26,L-80 BTC-M,.0383 bpf,ID=6.276" H 7273' 14.1.1.1.1.1.1.1.1.1 DATE REV BY COMMENTS I DATE REV BY COMMENTS ORION UNIT 04118107 N9ES ORIGINAL COMPLETION 1 07/28/10 SWC/AGR WFR C/O(07/06/10) WELL: V-218 05/19/07 ?/PJC SET PXN PLUG 'F' 7028' 102/16/11 MB/JMD ADDED SSSV SAFETY NOTE PERMIT No: 2070400 05/21/07 JLJ/TLH GLV C/O 02/26/11 MW/PJC SFTY NOTE(HES PKR) API No: 50-029-23350-00 06/02/07 DAV/PAG GLV C!0(05/29/07 0422/11 DAV/PJC WRF C/O(04/06/11) SEC 11,T11 N,R11 E,4889'FSL&1576'FEL 11/01/07 TW/PJC DRLG DRAFT CORRECTIONS 01/19/12 TNWJMD ADDED I-QS SAFETY NOTE 02/17/08 TW/PJC DRAWING CORRECTIONS E BP Exploratton(Alaska) • i ~~ ~ . ~~~ w _~ ~ -. ~. ~§ w ~ti ,; 4 , t X~ ~,: `` ~ ~~.}~~: ~~ ~.k 9~ ¢~ 6~. ~ ~ ~~ z~-. !'~"' ~ ~ ~~ 'f..' MICROF1LMEp 6/30/2410 DO NOT PLAC E ANY N EW MATERIAL .UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm Marker.doc OPERABLE: V-218 (PTD #20704) Tubing Ingtegrity Confirmed • Page 1 of 2 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.comj Sent: Monday, December 28, 2009 5:35 AM To: NSU, ADW Well Operations Supervisor; Regg, James B (DOA); Engel, Harry R; Rossberg, R Steven; GPB, GC2 Wellpad Lead; GPB, GC2 OTL; GPB, Area Mgr West (GC2/WRD); GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, Prod Controllers; GPB, Well Pad LV; Brooks, Phoebe L (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: Warren, Mike; NSU, ADW Well Integrity Engineer; Williams, Carrie; Winslow, Jack L. Subject: OPERABLE: V-218 (PTD #2070400) Tubing Ingtegrity Confirmed Attachments: V-218 TIO & Injection PIot.ZIP; MIT PBU V-218 12-19-09.x1s All, Well V-218 (PTD #2070400) passed a stated witnessed MIT-IA to 2400 psi on 12/19/09. The passing test , confirms that the well has tubing integrity. The well has been reclassified as Operable and may remain on injection as Operations sees fit. Included below are current TIO & Injection Plots, and a copy of the MIT-IA form. «V-218 TIO & Injection PIot.ZIP» «MIT PBU V-218 12-19-09.x1s» -~~ Please contact us if there are any questions or comments. Thank you, Taylor ~ ~(~'~ Taylor Wellman fil-ing in for Anna Dube/Torin Roschinger ~~~ Office: 659-5102 Pager: 659-5100 x 1154 From: NSU, ADW Well Integrity Engineer. Sent: Friday, December il, 2009 5:51 AM To: NSU, ADW Well Operations Supervisor; Regg, James B (DOA); Engel, Harry R; Rossberg, R Steven; GPB, GC2 Wellpad Lead; GPB, GC2 OTL; GPB, Area Mgr West (GC2/WRD); GPB, Welis Opt Eng; GPB, Optimization Engr; GPB, Prod Controllers; GPB, Well Pad LV; Brooks, Phoebe L (DOA); 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy (DOA) <guy.schwartz@alaska.gov>' Cc: Warren, Mike; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: V-218 (PTD #2070400) TxIA comm while on PWI AI I, Well V-218 (PTD #2070400) is a WAG injector currently on Droduced water infection. The IA was bled on 12/10/09 after the IA pressure was seen tracking the tubing pressure. The IA pressure built up to match the tubing pressure after a 30 minute monitor confirming TxIA communication. The well has been reclassified as Under Evaluation. We plan to keep the well on injection and perform further diagnostics. The plan forward is as follows: 1. DHD: Bleed IAP and monitor IA BUR -DONE 2. Fullbore: AOGCC MITIA 3. WIC: Eval for AA A wellbore schematic, TIO and injection plot have been included for your reference. « File: V-218.pdf» « File: V-218 TIO & Injection Plot.doc» Please call with any questions or concerns. 12/28/2009 OPERABLE: V-218 (PTD #20704) Tubing Ingtegrity Confirmed • Page 2 of 2 Thank you, Torin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 12/28/2009 V-218 TIO Plot: 12 month +TEp _t_ a a~ OOR • OOOA On ,~ „~ r_z~ .~r gem ~r roo i~ i:m ~:m +. xn t~ tiw t o00 eoo an nu soo wo auo mriz~os ounim cya~m oerzsvs -wHro - ~ - a~ - a. • V-218 Injection Plot: 12 month STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; phoebe brooks@alaska.gov; tom.maunder@alaska.gov; doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. Prudhoe Bay /PBU / V Pad 12/19/09 Anna Dube Bob Noble Packer Depth Pretest Initial 15 Min. 30 Min. Well V-218 Type Inj. W TVD 4,516` Tubing 1,000 1,000 .1,000 1,000 Interval O P.T.D. 2070400 Type test P Test psi 150 'Casing 0 2,490 2,430 2,410 P/F P Notes: MIT-IA to 2500 psi to demonstrate tubing integrity ,/ OA 0 0 0 0 Pumped 2.7 bbls MEOH Well Type Inj. TVD Tubin Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT PBU V-218 12-19-09.x1s U MEMORANDUM TO: Jim Regg `~ ~ /IZ~f /o P.I. Supervisor ~f • I FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, December 23, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC V-218 PRUDHOE BAY UN ORIN V-218 Src: Inspector NON-CONFIDENTIAL U Reviewed By: P.I. Suprv Comm Well Name: PRUDHOE BAY UN ORIN V-218 API Well Number: 50-029-23350-00-00 Inspector Name: Bob Noble lnsp Num: mitRCN091223075032 Permit Number: 207-040-0 Inspection Date: 12/19/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. -- 2410 YP J ~ i 2070400 ~ SP~ _ ~ 0 -~ 2490~~ 2430 + __ --- ~- - ---. ~ - 2490 ~ ~A 0 ~ 0 ~ 0 ~ r - - -- _ ,T eTest Test st _ ~ ~ - -- ~ -~--- ----- Well - T e In ~'~' ~TVD ~_ . -- -----~ A--_ _---- - ---- - --- - -_ - -- _ ~ looo laao looo 0 I t rllval _--'_ YP_.__ P/F- --p / Tubm ~- - -1- -- - -~ -- ~ - -- l- _ _- - ;- --- OTHER P g ~ ~ ~ 1000 ~ Notes: MIT-IA to 2500 psi to demonstrate tubing integrity / Wednesday, December 23, 2009 Page 1 of 1 C~ BP Exploration (Alaska) Inc. Attn: Well Integriry Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 August 14, 2009 •~ : '1~~, ~~~; -~i~. ~ :; ~vu~ ~ :~ ~;~~~~; . ~ .,~~,~ • • bp ~~~~f~~~ OCT 0 ~ 2Q09 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB V-Pad Dear Mr. Maunder, ~b~dt8 Oil & Ges Con3. ~umm~~s~on Anehorape ~,o~- d~a U ` ~Gg Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB V- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator . . BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) ~~ , Date V-pad 8/13/2009 Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al V-01 2040900 50029232100000 NA 2 NA 17 6/30/2009 V-02 2040770 50029232090000 NA 3 NA 43.4 7/11/2009 V-03 2022150 50029231240000 surface NA NA NA NA V-04 2061340 50029233220000 NA 1.5 NA 20.4 6/29/2009 V-05 2080930 50029233910000 NA 1.75 NA 20.4 5/10/2009 V-07 2071410 50029233720000 NA 0.25 NA 1.7 6/29/2009 V-100 2010590 50029230080000 NA 1.5 NA 20.4 5/9/2009 V-101 2020560 50029230740000 NA 3.75 NA 32.3 7/10/2009 V-102 2020330 50029230700000 NA 7.75 NA 98.2 8/7/2009 V-t03 2021860 50029231170000 NA 0.5 NA 9.4 7/12/2009 V-104 2021420 50029231030000 NA 1.5 NA 21.3 7/11/2009 V-105 2021310 50029230970000 NA 2.25 NA 23.8 6/29/2009 V-106A 2041850 50029230830100 NA 1.75 NA 17 6/29/2009 V-107 2021550 50029231080000 NA 1.75 NA 13.6 7/11/2009 V-108 2021660 50029231120000 NA 1.5 NA 14.5 7/10/2009 V-109 2022020 50029231200000 NA 12 NA 10.2 6/30/2009 V-111 2031030 50029231610000 NA 1.5 NA 11.9 7/12/2009 V-t12 2060200 50029233000000 NA 1.5 NA 15.3 5/10/2009 V-113 2022160 50029231250000 NA 2.5 NA 37.4 5/10/2009 V-114A 2031850 50029231780t00 NA 2.5 NA 34 6/30/2009 V-115 2040270 5002923t950000 NA 1.5 NA 13.1 5/9/2009 V-117 2030900 50029231560000 NA 1.25 NA 22.1 5/10/2009 V-119 2040410 50029232010000 NA 2 NA 18.7 6/30/2009 V-120 2041790 50029232250000 NA 1.5 NA 8.5 7/12/2009 V-121 2070360 50029233480000 NA 1.9 NA 17 6/30/2009 V-122 2061470 50029233280000 NA 1.5 NA 6.8 5/10/2009 V-2oi 2012220 5002923054000o SC leak NA 4 NA 90.6 8/7/2009 V-202 2030770 50029231530000 NA 1.75 NA 12.8 7/11/2009 V-203 2051680 50029232850000 NA 2 NA 12.8 7/10/2009 V-204 2041310 50029232170000 NA 2 NA 22.1 6/30/2009 V-205 2061800 50029233380000 NA 1.8 NA 13.6 6/30/2009 V-207 2080660 50029233900000 NA 1.75 NA 18.28 1/9/2009 V-210 2042100 50029232310000 NA 2 NA 18.7 7/11/2009 V-211 2042200 50029232320000 NA 1.5 NA t3.6 7/10/2009 V-212 2051500 50029232790000 NA 1.2 NA 11.9 6/29/2009 V-213 2041160 50029232130000 NA 1.75 NA 6.3 5/9/2009 V-214 2051340 50029232750000 NA 0.5 NA 9.4 7/11/2009 V-215 2070410 50029233510000 NA 2.8 NA 30.6 6/30/2009 V-216 2041300 50029232160000 NA 1.5 NA 13.6 6/29/2009 V-217 2061620 50029233340000 NA 2.3 NA 25.5 6/30/2009 V-218 2070400 50029233500000 NA 2 NA 17.9 7/12/2009 V-219 2081420 50029233970000 NA 1 NA 16.2 7/12/2009 ".-'~^ 2080200 50029233830000 NA 1.75 NA ~ 3/9/2008 V-221 2050130 50029232460000 NA 0.8 NA 8.5 6/29/2009 V-222 2070590 50029233570000 NA 2.5 NA 21.3 7/11/2009 V-223 2080220 50029233840000 NA 2 NA 20.5 9!7/2008 '~. JUN ~ ~ ~ 2OG9 5~~~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # al~ska qi! ~ Gas Cons. Coliurlissi®n Anchorage Log Description os~1 s~os N0.5279 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave> Suite 100 Anchorage, AK 99501 Date BL Color CD 1423A AYKP-00016 USIT 04/10/09 1 1 A-44 AP3O-00036 SCM 04/26/09 1 1 14-23A AYKP-00016 USIT 0 1 9 1 1 07-10A B1JJ-00022 MEM CN STP 05/26/09 1 1 07-146 AYQO-00029 LDL - L 05/26/09 1 1 12-09 AYTU-00038 PRODUCTION PROFILE ~ 05/31/09 1 1 V•218 AVY5.00048 INJECTION PROFILEIWFL J 0$J29/09 1 1 15-34A AWJI-00020 MCNL 040/09 1 1 A-44 AWLS-00017 CH EDIT PDCL-GR SCM - 05/25/09 1 o~ owcr wn~rw~nf~n cnnc nc nc.nr s .. ..............................~ ~~-.. -. _.. -_ BP Exploration (Alaska) Inc. . Petrotechnical Data Center LR2-1 900 E. Benson Blvd. ~- .: ~~4 ~~~~ ~; ~# Zan Alaska Data & Consulting Services 2625 GambeA Street, Suite 400 Anchorage, AK 99503-2838 • • ~ `~ M~ DATA SUBMITTAL COMPLIANCE REPORT 5/7/2009 Permit to Drill 2070400 Well Name/No. PRUDHOE BAY UN GRIN V-218 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23350-00-00 MD 7283 TVD 4990 Completion Date 4/14/2007 Completion Status WAGIN Current Status WAGIN UIC Y REQUIRED INFORMATION t~ ~Y Mud Log IVo Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: / GR, GR / RES / AZI-DENS / NEU / PWD, USIT Well Log Information: Log/ Electr Data Digital Dataset Ty Med/Fmtt Number Name -- - _. ~//D D Asc Directional Survey '~/2pt Directional Survey `Rpt Directional Survey ~ g Cement Evaluation og Temperature ~ ~ C Lis 15372 Gamma Ray i ED C Lis 15598 Induction/Resistivity Yxog Induction/Resistivity ~YLog Induction/Resistivity _ _ - - _ - Well Cores/Samples Information: (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments 0 7283 Open 4/19/2007 0 7283 Open 4/19/2007 0 7283 Open 4/19/2007 5 Col 0 7149 Case 5/16/2007 USIT, CBL, CEL, GPIT, CCL, GR 11-Apr-2007 25 Blu 1 1008 6979 Case 6/11/2007 Mem Temp Survey, Jewlery Log, GR, CCL, Temp, Pres 19-May-2007 1 68 7130 Case 8/27/2007 LIS Veri, GR, CCL w/PDS Graphics 90 7282 Open 1 012 6/2 0 0 7 LIS Veri, GR, ROP, FET, RPM, DRHO, NPHI w/PDS graphics 25 Btu 1 108 7283 Open 10/26/2007 MD Vision Service 7-Apr- 2007 25 Blu 1 108 7283 Open 10/26/2007 TVD Vision Service 7-Apr- 2007 Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 5/7/2009 Permit to Drill 2070400 Well Name/No. PRUDHOE BAY UN GRIN V-218 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23350-00-00 MD 7283 TVD 4990 ADDITIONAL INFORMATION Well Cored? Y I~ Chips Received? -Y'7-I~ Analysis l~'/'7a' Completion Date 4/14!2007 Completion Status WAGIN Daily History Received? Formation Tops Current Status WAGIN Y~N 1~/N UIC Y Received? Comments: Compliance Reviewed By: Date: ~ ~_ ~ _ Sc(damberger Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description NO. 4454 Company: Alaska Oi18 Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: polaris Orion Borealis Date BL Color CD W-213 V•215 Z-108 5-124 S-125P81 11661175 11594491 11212628 40014242 40015467 MEM TEMP/PRESS SURVEY CH EDIT PDC GR USI OH WIRELINE PEX EDIT ' OH MWDILWD EDIT OH MWDILWD EDIT 09/29107 04123107 02105/06 11/05/06 07/07/07 1 2 3 2 1 1 1 1 V-121 40015007 OH MWDA-WD EDIT ~ 03/24107 2 1 V-222 40015319 OH MWD/LWD EDIT 06108/07 2 1 W-210 40014642 OH MWD/LWD EDIT 02126/07 2 1 V-218 40015068 OH MWDILWD EDIT 04/07107 2 1 W-204 40014637 OH MWDILWD EDIT 01/29107 2 1 W-204PB1 40014637 OH MWD/LWD EDIT 01/24/07 2 1 W-204L1 40014637 OH MWD/LWD EDIT 02/07107 1 1 W-204L2 40014637 OH MWDILWD EDIT fd 02/20107 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-b 900 E Benson Blvd. - - Anchorage AK 99508-425q Date Delivered: ,y^af ^-~ e=~ ~~ii`I-" Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Belh Received by. lopslo7 08/15/07 • Schtumgerger Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description NO. 4372 Company: Alaska Oil 8: Gas Cons Comm ANn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Orion Aurora Date BL Color CD 5-121 40013524 OH EDIT MWDlLWD 05/26/06. 2 1 S-121P81 L-215 40013524 40012404 OH EDIT MWDILWD OH EDIT MWD/LWD 05/17106 09/22105 2 2 1 1 L-215P81 L-215PB2 40012404 40012404 OH EDIT MWD/LWD r) ~ OH EDIT MWD/LWD -) 09/09105 09117/05 2 2 1 1 V-218 L-215 11637325 10913049 CH EDIT PDC GR USIT CH EDIT PDC GR USIT 04/11/07 09/26105 i 1 PLEASE ACKNOWLEDGE RECEIPT BV SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. ~ ~ ~, ~ ~'.' - ~ ~ "^^'"~, Petrotechnical Data Center LR2~ 1 ~ ` ~ ~, ~ -. 900 E Benson Blvd .. ~ ~ -_-, ~ ~ ~ ,^' Anchorage AK 99508-4254 Date Delivered: ~1~ ~ '~ ~~)1.~~ ,. 4 . ` i" °S~di ti,-; '~ Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth w Received by: `_ ~Cj~~~~` • STATE OF ALASKA ~~~~ ALASKA~L AND GAS CONSERVATION COMNITSSION ~~~- ~ ZG07 WELL COMPLETION OR RECOMPLETION REPORT AND 1~~~~ ~;; Gas G~i~s• Cammis~ian Rev~Sed 07/17l~'~~~ In,~:ction 1a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended zoAAC zs.~os zoAAC zs.>>o ^ GINJ ^ WINJ ^ WDSPL ®WAG ^ Other No. of Completions One 1b. Well Class: ^ Development ^ Exploratory ®Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 4/14/2007 12. Permit to Drill Number 207-040 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 4/1/2007 13. API Number 50-029-23350-00-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 4/7/2007 14. Well Name and Number: PBU V-2181 4889 FSL, 1576 FEL, SEC. 11, T11 N, R11 E, UM Top of Productive Horizon: 4985' FSL, 2530' FEL, SEC. 12, T11 N, R11 E, UM ~ 8. KB (ft above MSL): 82' ~ Ground (ft MSL): 53.5' 15. Field /Pool(s): Prudhoe Bay Field !Orion Total Depth: 4954' FSL, 2032' FEL, SEC. 12, T11 N, R11 E, UM ~ 9. Plug Back Depth (MD+TVD) 7180 - 4919 - Schrader Bluff 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 590724 y- 5970138 Zone- ASP4 10. Total Depth (MD+TVD) 7283 - 4990 - 16. Property Designation: ADL 028240 TPI: x- 595048 y- 5970288 Zone- ASP4 Total Depth: x- 595547 y- 5970263 Zone- ASP4 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: 18. Directional Survey ®Yes ^ No Submit electronic and rinted information er 20 AAC 25.050 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1778' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): DIR / GR, GR / RES / AZI-DENS / NEU / PWD, USIT 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP 'BOTTOM TOP .BOTTOM SIZE CEMENTING RECORD PULLED 20" 215.5# A-53 Surface 108' Surface 108' 42" 260 sx Arctic Set A rox. 9-5/8" 40# L-80 29' 3321' 29' 2572' 12-1/4" 650 sxArctic Set Lite, 432 sx Class 'G' 7" 26# L-80 26' 7273' 26' 4983' 8-314" 328 LiteCrete 250 sx'G' 409 sx'G' 23. Open to production or inject ion? ®Yes ^ No 24. TueING RECORD If Yes, list each interval open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET MD PACKER SET MD 4-1/2" Gun Diameter, 5 spf 3-1/2", 9.2#, L-80 7050' 6574', 6687', 6903' MD TVD MD TVD 6608' - 6653' 4537 - 4566' 6708' - 6753' 4602' - 4632' Z5:- ACID, FRACTURE, CEMENT SQUEEZE, ETC. 6773' - 6793' 4645' - 4658' DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 6926' - 6983' 4746' - 4785' Freeze Protect w/ 117 Bbls of Diesel 26. PRODUCTION TEST Date First Production: June 11, 2007 Method of Operation (Flowing, Gas Lift, etc.): Water Injection Date Of Test: HOUfS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PreSS. C2SIng PreSS: CALCULATED 24-HOUR RATE OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Cores Ac wired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, phpotographs and laboratory analytical results per 20 AAC 250.071. None S ®F~, JUL ~ 3 207 Form 10-407 Revised 02/2007 ®(~' ~ ~ ~ /t goNTINUED ON REVERSE SIDE ~\ /'~~ ~/~O~ ("~ H L J'~- ~~~rlu, ~ 28. l~°`EOLOGIC MARKERS (LIST ALL FORMATIONS AN ERS ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD Well Tested? ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base 1965' 1778' detailed test information per 20 AAC 25.071. Top Ugnu 3,951' 2,934' None Ugnu MA 5,962' 4,138' Ugnu MB1 6,038' 4,184' Ugnu M62 6,144' 4,250' Ugnu MC 6,258' 4,319' Schrader Bluff NA 6,360' 4,382' Schrader Bluff NB 6,396' 4,404' Schrader Bluff NC 6,448' 4,437' Schrader Bluff NE 6,460' 4,444' Schrader Bluff NF 6,544' 4,497' Schrader Bluff OA 6,609' 4,538' Schrader OBa 6,707' 4,601' Schrader OBb 6,766' 4,640' Schrader OBc 6,856' 4,700' Schrader OBd 6,926' 4,746' Schrader OBe 7,025' 4,813' Schrader OBf 7,089' 4,856' Schrader OBf Base 7,062' 4,838' Formation at Total Depth (Name): Colville Mudstone 7062' 4838' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foreg 'ng is true and correct to the best of my knowledge. / / ~~ Signed Terrie Hubble ~1;,~~ Title Technical Assistant Date ` '~! PBU V-2181 207-040 Prepared By NameMumber.~ Terrie Hubble, 564-4628 Well Number Permit No. / A royal No. Dulling Engineer: Mark Staudinger, 564-4337 INSTRUCTIONS GeNreRa~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Irene 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Irene 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION s~~ EIVE~ ~E WELL COMPLETION OR RECOMPLETION REPORT AND LOG MAY 1 0 2007 ~I~~Itt3 ~I & Gas Cons. Cofnmissior 1a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ®WAG zoAACZS.~os zoaczs.~~o ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other 1b. Well Class Anc OfB~B ^ Development ^ Exploratory ^ Stratigraphic ®Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aba 4/14/2007 ~~ 12. Permit to Drill Number 207-040 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 4/1/2007 ~ 13. API Number 50-029-23350-00-00 4a. Location of Well (Governmental Section): Surface: 4889' FSL 76' EL 7. Date T.D. Reached 4Rl2007 14. Well Name and Number: PBU V-2181 , 15 F , SEC. 11, T11N, R11E, UM Top of Productive Horizon: 4985' FSL, 2530' FEL, SEC. 12, T11 N, R11 E, UM 8. KB Elevation (ft): 82' 15. Field /Pool(s): Prudhoe Bay Field / Orion Total Depth: 4954' FSL,' 2032' FEL, SEC. 12, T11 N, R11 E, UM 9. Piug Back Depth (MD+TVD) 7180 + 4919 Ft Schrader Bluff 4b. Location of Well (State Base Plane Coordinates): Surtace: x- 590724 y- 5970138 Zone- ASP4 10. Total Depth (MD+TVD) 7283 ~ + 4990 ~ Ft 16. Property Designation: ADL 028240 TPI: x- 595048 y- 5970288 Zone- ASP4 Total Depth: x- 595547 y- 5970263 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 1900' (Approx.) 21. Logs Run: DIR / GR, GR / RES / AZI-DENS / NEU / PWD, USIT 22. CASING, LINER AND CEMENTING RECORD CASING SETTING -0EPTH MD SETTING DEPTH TVD 'HOLE AMOUNT SIZE WT.' PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 215.5# A-53 Surtace 108' Surface 108' 42" 260 sx Arctic Set A rox. 9-5/8" 40# L-80 29' 3321' 29' 2572' 12-1 /4" 650 sx Arctic Set Lite, 432 sx Class 'G' 7" 26# L-80 26' 7 7 ' 26' 49 3' 8-3/4" Lite rte 250 sx' 4 9 sx'G' 0 23. Perforations open to Production (MD + ND of Top and 24. Tuawd RECORD Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET MD PACKER SET MD 4-1/2" Gun Diameter, 5 spf 3-1/2", 9.2#, L-80 7050' 6574', 6687', 6903' MD ND MD TVD 6608' - 6653' 4537 - 4566' 6708' - 6753' 4602' - 4632' 25_ ACID, FRACTURE, CEMENT SQUEEZE, ETC. 6773' - 6793' 4645' - 4658' DEPTH INTERVAL MD AMOUNT H~ KIND OF MATERIAL USED 6926' - 6983' 4746' - 4785' Freeze Protect w/ 117 Bbls of Diese! 26. PRODUCTION TEST Date First Production: Not on Injection Yet Method of Operation (Flowing, Gas Lift, etc.): N/A Date of Test Hours Tested PRODUCTION FOR TEST PERIOD OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO FIOW TUbing PreSS. CaSing PreSSUfe CALCULATED Z4-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 C`J~a'?i TiON ~~~ ~ ~ ~fl~~ ~ ~ None S-iFiF~~ Form 10-407 Revised 12/2003 ~~~~ CONTINUED ON REVERSE SIDE N ~ ... ~S~ is L~ 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". Top Ugnu 3,951' 2,934' None Ugnu MA 5,962' 4,138' Ugnu MB1 6,038' 4,184' Ugnu M62 6,144' 4,250' Ugnu MC 6,258' 4,319' Schrader Bluff NA 6,360' 4,382' Schrader Bluff NB 6,396' 4,404' Schrader Bluff NC 6,448' 4,437' Schrader Bluff NE 6,460' 4,444' Schrader Bluff NF 6,544' 4,497' Schrader Bluff OA 6,609' 4,538' Schrader OBa 6,707' 4,601' Schrader OBb 6,766' 4,640' Schrader OBc 6,856' 4,700' Schrader OBd 6,926' 4,746' Schrader OBe 7,025' 4,813' Schrader OBf 7,089' 4,856' Schrader OBf Base 7,062' 4,838' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. / / ~~ !'~` Signed Terrie Hubble ~ Title Technical Assistant Date PBU V-21$1 207-040 Prepared ByName/Number. Terrie Hubble, 564-4628 Well Number Permit No. / A royal No. Drilling Engineer: Mark Staudinger, 564-4337 INSTRUCTIONS GeNew-~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITeM 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). ITeM 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. ITeM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITeM 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. ITeM 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). ITeM 27: If no cores taken, indicate "None". ITeM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only BP EXPLORATION Page 1 of 1 Leak-Off Test Summary Legal Name: V-2181000 Common Name: V-218 - - -- Test Date Test Type 4/6/2007 I LOT Test Depth (TMD) ~ Test Depth (ND) AMW ~ Surtace Pressure Leak Off Pressure (BHP) 3,321.0 (ft) 2,571.0 (ft) ~ 8.80 (ppg) ~ 700 (psi) ~ 1,875 (psi) EMW 14.04 (ppg) Printed: 4/16/2007 11:26:09 AM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Date 3/31 /2007 14/1/2007 4/2/2007 From - T 00:00 - 01:3 01:30 - 02:3 02:30 - 03:3 03:30 - 04:3 04:30 - 05:3 05:30 - 07:3 07:30 - 10:0 10:00 - 11:0 11:00 - 12:0 12:00 - 13:0 13:00 - 18:0 V-2181000 V-218 DRILL+COMPLETE NABOBS ALAS KA DRILLING NABOBS 9ES ~ Hours ~ Task ~ Code NPT '~. _. ___1_.___-__-- ~-- --- 1.50 MOB P 1.00 MOB P 1.00 MOB P 1.00 MOB P 1.00 MOB P 2.00 DIVRTR P 2.50 MOB P 1.00 MOB P 1.00 RIGU P 1.00 RIGU P 5.00 DIVRTR P o 0 0 0 0 0 0 0 0 0 0 0 18:00 - 19:30 I 1.501 DIVRTR I P 19:30 - 23:00 I 3.501 RIGU I P 23:00 - 23:30 I 0.501 RIGU I P 23:30 - 00:00 I 0.501 DIVRTR I P 00:00 - 00:30 I 0.501 RIGU I P 00:30 - 02:00 1.50 DIVRTR P 02:00 - 03:00 1.00 RIGU P 03:00 - 04:00 1.00 RIGU P 04:00 - 08:30 4.50 RIGU P 08:30 - 09:30 1.00 RIGU P 09:30 - 11:00 1.50 RIGU P 11:00 - 14:30 3.50 RIGU P 14:30 - 15:00 0.50 RIGU P 15:00 - 19:00 4.00 DRILL P 19:00 - 20:00 1.00 DRILL P 20:00 - 00:00 4.00 DRILL P 00:00 - 01:00 I 1.001 DRILL I P Page 1 of 13 Spud Date: 4/1 /2007 Start: 3/31 /2007 End: 4/14/2007 I Rig Release: 4/14/2007 Rig Number: Phase ', Description of Operations PRE PJSM. Move mud pit complex away from sub. PRE Secure surface hydril and prepare cellar for rig move. PRE Jack rig up and remove matting boards. Move sub off V-121. PRE Nipple down V-121 diverter. Make 3 picks with crane. PRE Move rig around pad to V-218i. PRE Set in and nipple up diverter lines behind conductor. PRE Spot sub over conductor. Level rig. PRE Spot and level mud pits. PRE Rig up lines between complexes. PRE Berm cellar and flow line areas. Work on pre-spud checklist. PRE Nipple up diverter. **Accept rig for operations on V-2181 ~ 10:00 hr, 3/31/2007. Rolled back 3 hours due to diverter work on V-121 and pre rig spotting on V-218i. PRE Change out drilling nipple. Make up diverter riser and dresser sleeve. PRE Finish preparing drill pipe and BHA in pipe shed. *Note started taking on water @ 20:30 hr due to lack of truck availability. Only using one water truck. PRE Make up 2 drill collars in preparation for diverter test and drilling out ice in conductor. PRE Perform surface diverter function and accumulator tests. Witnessing of test waived by AOGCC rep Lou Grimaldi. Test witnessed by BP WSL R. French and NAD TP Randy Axness. PRE Fill high pressure circulating lines and pressure test to 3,000 psi - OK. *Note: Crew held Pre-Spud meeting during PTSM. PRE Fill conductor and repair leak in dresser sleeve on drilling riser. PRE Clean out ice plug from ground level to 95' using fresh water. PRE Laydown NB STAB and bit. Stand back 1 stand of drill collars. PRE Pick up 105 joints of 4" drill pipe and rack back stands in derrick. PRE Pick up 24 joints of 4" HWDP and rack back stands in derrick. PRE Pick up 2 joints of 5" HWDP and JAR. Stand back in derrick. PRE PJSM. Pick up and make up BHA #1: Used 12 1/4" HTC MXL-1X bit, 1.83 deg PDM, Lead NM DC, 8" NM STAB, MWD, 7.938" NM STAB, NM XO, Orient Sub, NM DC, 6.75" NM STAB, tea NM DCs. *Note: Crew held Pre-Spud meeting during PTSM. PRE PJSM. Rig up Gyro Data/Sperry equipment. SURF Spud well 2181 ~ 15:00 hr, 4/1/2007. Drill from 108' to 460'. 550 gpm, 845 psi on, 820 psi off, 65 rpm, 1 k TO. *Formation was thawed until -320'. Gyro Survey every 100', 30 ft wipes prior to connections. SURF POH from 460' to 171' to pick up JAR stand. Tight at 438'. Backreamed from 450' to 360' without problem, 485 gpm, 780 psi, 50 rpm, 3k TO. Pulled dry to 171' Pick up JAR stand and run back in hole. Washed last stand down, tagged fill @ 449'. SURF Directionally drill from 460' to 822'. 550 gpm, 1.350 psi on, 1,100 psi off, 65 rpm, 3k TO on, 1.5k TO off, WOB - 25k, PU - 69k, SO - 63k, RWT - 66k. Gyro Survey every 100' to 800'. 30 ft wipes prior to connections. ART - 1.43 hr, AST - 2.61 hr. SURF Directionally drill from 822' to 914'. 550 gpm, 1.350 psi on, Printed: 4/16/2007 11:26:15 AM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 4/2/2007 00:00 - 01:00 01:00 - 01:30 01:30 - 10:30 10:30 - 12:30 12:30 - 13:30 13:30 - 14:00 14:00 - 15:00 15:00 - 17:00 17:00 - 18:00 18:00 - 19:00 19:00 - 19:30 19:30 - 20:00 20:00 - 00:00 4/3/2007 00:00 - 02:30 02:30 - 03:00 03:00 - 05:00 V-2181000 V-218 DRILL+COMPLETE NABOBS ALASKA DRILLING NABORS9ES i Hours ; Task Code NPT ~- I` - hIi 1.001 DRILL P I I 0.50 DRILL P 9.00 DRILL P 2.00 DRILL P 1.00 DRILL P 0.50 DRILL P 1.00 DRILL P 2.00 DRILL P 1.00 DRILL P 1.00 DRILL P 0.50 DRILL P 0.50 DRILL P 4.00 DRILL P 2.501 DRILL I P Start: 3/31 /2007 Rig Release: 4/14/2007 Rig Number: i Page 2 of 13 Spud Date: 4/1 /2007 End: 4/14!2007 Phase Description of Operations SURF SURF SURF SURF SURF SURF SURF SURF SURF SURF SURF SURF SURF SURF 0.501 DRILL I N I DPRB I SURF 2.001 DRILL I N I DPRB I SURF 1,110 psi off, 65 rpm, 3k TO on, 1.5k TO off, WOS - 25k, PU - 69k, SO - 63k, RWT - 66k. 30 ft wipes prior to connections. Gyro single shot surveys from 800' to surface. Directionally drill from 914' to 1,866'. 700 gpm, 2,710 psi on, 2,590 psi off, 65 rpm, 5.2k TO on, 2.2k TO off, WOB - 30k, PU - 78k, SO - 60k, RWT - 68k, AST - 5.68 hrs, ART - 2.01 hrs. 30 ft wipes prior to connections. Circulate 3 times bottoms up @ 700 gpm, 2,590 psi, 60 rpm, 4k TO. Started changing traction blower motor. ~ approx. 11:00 hr a dropped object near miss occured. Secured area for preliminary investigation by BP WSL and NAD TP and personnel involved. (BP HSE rep Allen Graff and NAD HSE rep joined for full investegation later) See remarks. Monitor well. PU - 87k, SO - 65k. POH from 1,866' to 1,175' with minor intermittent overpull 10-15k. Overpull increased to 20-25k ~ 1,175'. Backream from 1,175' to 1,100' C~ 389 gpm, 700 psi, 65 rpm, 2k TO. POH dry from 1,100' to 360' with intermittent overpulls of 10-15k. Stand back BHA #1, change out bit to new Reed TCI IC. Change out motor to 1.5 deg. Bit #RR: 3-3-WT-A-E-I-RG-BHA Service topdrive and crown, change hyraulic hose service loop jumper hose. Run in hole from 78' to 1,198'. Set down. @ 1,198'. Ream from 1,198' to 1,230' @ 350 gpm, 720 psi, 50 rpm, 3k TO. Run in hole without problem from 1,230' to 1,766'. Wash last stand down to bottom @ 1,866'. No fill. Directionally drill from 1,866" to 2,524'. 700 gpm, 2,900 psi on, 2,720 psi off, 80 rpm, 6.5k TO on, 3.1 k TO off, WOB - 35k, PU - 86k, SO - 57k, RWT - 72k, AST - 1.25 hrs, ART - 1.00 hrs. 30 ft wipes prior to connections. Directionally drill from 2,524" to 3,177'. 700 gpm, 3,210 psi on, 3,020 psi off, 80 rpm, 6.4k TO on, 4.1k TO off, WOB - 30k, PU - 89k, SO - 58k, RWT - 63k, AST - .32 hrs, ART - 1.68 hrs. Hydrates to surface ~ 2,549'. 30 ft wipes prior to connections. Lost full returns C~? 3,177'. No pressure or torque spikes. No drag working pipe. MW - 9.5 ppg. When shut down, the mud level would go down to ground level then stay there. Attempt to regain circulation. Start mixing LCM pill. Got partial returns back - 24% (42% normal). Loss rate ~ 260 bph. Back down on pump to 3 bpm with mud level static at flowline. f~ 1 bpm, mud level dropped to 20' below flowline and remained static while pumping. Pump 46 bbls of 9.5 ppg, 15 ppb Mix II course LCM pill. (Only 15 ppb due to mud vis and hopper plugging up) Pump ~ 1 bpm, 230 psi with mud level staying static at 20' below surface. Clear bit and shut down pump with mud level dropping to ground level. Attempted to fill hole from the top with losses of 1 bbl pumped, 1 bbl lost. Shut down hole fill and observe mud level return to ground level. Printed: 4/16/2007 71:26:15 AM BP EXPLORATION Page 3 of 13 Operations Summary Report Legal Well Name: V-2181000 Common Well Name: V-218 Spud Date: 4/1/2007 Event Name: DRILL+COMPLETE Start: 3/31/2007 End: 4/14/2007 Contractor Name: NABOBS ALASKA DRI LLING I Rig Release: 4/14/2007 Rig Name: NABOBS 9ES Rig Number: Date From - To ~ Hours ~ Task Code NPT j 1 Phase Description of Operations 4/3/2007 05:00 - 06:00 1.00 DRILL N DPRB SURF POH, pumping out 5 stands from 3,177' to 2,725' ~ 1 bpm, 175 psi, with mud remaining level @ 20' below surface. 06:00 - 06:30 0.50 DRILL N DPRB SURF Circulate and monitor dynamic losses G 3 and 4 bpm - 205 bph initial losses. Static losses 85 bph. 06:30 - 09:30 3.00 DRILL N DPRB SURF Monitor well while building mud volume. Static losses @ 85 to 40 bph. 09:30 - 12:30 3.00 DRILL N DPRB SURF POH, pumping out 1 bpm, 225 psi from 2,725' to 1,004'. PU - 12:30 - 13:00 0.50 DRILL N DPRB SURF 13:00 - 14:00 1.00 DRILL N DPRB SURF 14:00 - 15:30 1.50 DRILL N DPRB SURF 15:30 - 16:30 1.00 DRILL N DPRB SURF 16:30 - 17:30 1.00 DRILL N DPRB SURF 17:30 - 18:00 0.50 DRILL N DPRB SURF 18:00 - 20:30 2.50 DRILL N DPRB SURF 20:30 - 21:30 1.00 DRILL N DPRB SURF 21:30 - 23:00 1.50 DRILL P SURF 23:00 - 00:00 I 1.001 DRILL I P I I SURF 4/4/2007 00:00 - 00:30 0.50 DRILL P SURF 00:30 - 02:00 1.50 DRILL P SURF i 02:00 - 03:00 1.00 DRILL P SURF 03:00 - 04:30 1.50 DRILL P SURF 04:30 - 06:30 2.00 DRILL P SURF 06:30 - 07:30 1.00 DRILL P SURF ', 07:30 - 09:30 2.00 CASE P SURF 09:30 - 18:30 9.00 CASE P SURF 95k, SO - 63k. Increased pump rate to 3 bpm, 425 psi as needed through tight spots. Monitor static loss rate - 40 to 80 bph. Circulate and monitor dynamic losses ~ 1 bpm, 170 psi - 60 bph. 2 bpm, 195 psi - 88 bph. 3 bpm, 215 psi - 88 bph. 4 bpm, 245 psi - 60 bph. Pump 100 bbl 8.8 ppg, 40 ppb LCM pill ~ 2 bpm, 130 psi. Circulate pill out of bit. Monitor well for static loss rate - 4 bph. Circulate and monitor dynamic losses @ 2 bpm, 200 psi - 72 bph. 4 bpm, 360 psi - 72 bph. 6 bpm, 565 psi - 192 bph loss with majority of losses due to LCM going over shakers. Monitor well for static loss rate - 6 bph. Run in hole from 1,004' to 2,700'. Work through and re-wipe tight spots as neccessary. Pumped through tight spot at 2,047' C~ 4 bpm, 400 psi with loss rate of 60 bph. Set down at 2,700'. Ream from 2,700' to bottom @ 3,177' ~ 3.5 bpm, 600 psi, 40 rpm, 4.6k TO. Directionally drill from 3,177' to TD C~ 3,332 MD, 2,577' TVD. 530 gpm, 2,230 psi on, 2,060 psi off, 80 rpm, 7k TO on, 4.5k TO off, WOB - 30k, PU - 105k, SO - 60k, RWT - 74k, AST - 0.00 hrs, ART - 0.65 hrs. Loss rate at 60 bph. Building mud at 80 bph. Circulate 3/4 bottoms up @ 530 gpm, 2,175 psi - 60 bph loss rate. Increase pump rate for remainder of first bottoms up to 600 gpm, 2,500 psi - no change in loss rate. Increase rate to 700 gpm, 3,130 psi - no change in loss rate. 'Total mud loss for today - 712 bbls. Continue circulating for total of 3 1/2 times bottoms up ~ 700 gpm, 3,090 psi. Loss rate slowed to 40 bph. Monitor well -static. POH to run casing from 3,332' to 2,010'. Tight at 2,030' with 35k overpull. Backream from 2,030 to 1,840' ~ 240 gpm, 530 psi, 40 rpm, 4-7k TO. No mud loss. Continue POH without problem from 1,840' to 268'. Loss rate - 4 bph. Stand back JAR stand. Laydown BHA #2. Bit #2: 0-0-BC-A-E-I-NO-TD Clean and clear rig floor of BHA equipment. PJSM. Make dummy run with 9 5/8" casing hanger and landing joint. Rig up to run casing. PJSM. Pick up and make up 9 5/8" 80' shoe track. Baker-Lok connections. Check floats - OK. Continue running in hole with 9 5/8" 40# L-80 BTC casing to planned casing depth ~ 3,321' without pipe displacement, filling annulus with hole fill pump. Filled every joint with casing fill-up tool. Make up TO - 9,000 Printed: 4/16/2007 7126:75 AM BP EXPLORATION Page 4 of 13 Operations Summary Report Legal Well Name: V-2181000 Common Well Name: V-218 Spud Date: 4/1/2007 Event Name: DRILL+COMPLETE Start: 3/31/2007 End: 4/14/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/14/2007 Rig Name: NABOBS 9ES Rig Number: Date From - To Hours Task !Code' NPT Phase Description of Operations - _ __ 4/4/2007 09:30 - 18:30 9.00 CASE ~ P SURF ft/Ibs. Used BOL 2000 NM pipe lubricant. Broke circulation 2,312' with minimal returns. 'Lost total of 304 bbls of mud on casing trip in hole. Halliburton 9 5/8" Float Shoe Bottom @ 3,321'. 2 Jts 9 5/8" 40# L-80 BTC Casing (#1- #2) Halliburton 9 5/8" Float Collar ~ 3,235'. 1 Jt 9 5/8" 40# L-80 BTC Casing (#3) tea 9 5/8" 40# L-80 BTC Pup Jts (4.86' & 19.98') 53 Jts 9 5/8" 40# L-80 BTC Casing (#4- #56) 9 5/8" Tam Port Collar C~ 1,009' 24 Jts 9 5/8" 40# L-80 BTC Casing (#57-#80) 9 5/8" 40# Hanger Pup Jt Casing hanger (10 3/4" LH Acme top conn) 9 5/$" Landing Ring to Rotary table - 28.60' Up weight = 175K, Down Weight = 84K Baker-Lock Shoe-track Jts #1-3 Bowsprings Centralizers: 1 on stop ring 5-10' above shoe on jt #1 1 on stop ring 5-10 ft. above float collar 23 on collars on jts #3-25 1 on stop ring 5' on each side of Tam Collar 27 Total Centralizers, 4 Stop Rings 18:30 - 19:00 0.50 CASE P 19:00 - 22:00 3.00 CEMT P 22:00 - 00:00 2.00 CEMT P 4/5/2007 100:00 - 00:30 I 0.501 CEMT I P SURF Laydown Frank's tool. Blowdown topdrive. Make up double plug cementing head. SURF Stage pumps up to 8 bpm, 515 psi ICP incrementally. Initial losses C~ 100+ bph, slowing to 40 bph after 1st complete circulation. Continue circulating and conditioning mud to a 63 viscosity and 15 YP ~ 8 bpm, 425 psi with losses increasing to 80 bph prior to switching to Dowell. Reciprocated casing 15 ft strokes, PU - 151 k, SO - 96k. Lost 160 bbls of mud while circulating. Held cementing PJSM while circulating. SURF Switch over to Dowell. Pump 5 bbls of water. Pressure test lines to 3,500 psi - OK. Pump 74 bbls of 10.1 ppg of MudPush II ~ 5.6 bpm, 175 psi ICP, 130 psi, FCP. Shut down and release bottom plug. Pump 520 bbls of 10.7 ppg Arctic Set Lite lead cement @ 6.4 bpm, 150 psi ICP, 440 psi FCP. *Note: Spacer observed at surface at end of lead cement pumping. Pump 65.5 bbls of 15.8 ppg Class "G" tail cement Cul 3.6 bpm, 300 psi ICP, 225 psi FCP. Pump 23.8 bbls of Class "G" tail cement with DuraSTONE ~ 3.6 bpm, 160 psi ICP, 140 psi FCP. 'Note all cement had 1.5 ppb CemNET added except the DuraSTONE mix. Lost 142 bbls out of 595 bbls pumped. 'Lost total of 1,395 bbls total for the day. SURF Continue 9 5/8" surface cement job. Pump 65.5 bbls of 15.8 ppg Class "G" tail cement ~ 3.6 bpm, 300 psi ICP, 225 psi FCP. Pump 23.8 bbls of Class "G" tail cement with DuraSTONE ~ 3.6 bpm, 160 psi ICP, 140 psi FCP. 'Note all cement had 1.5 ppb CemNET added except the DuraSTONE mix. Shut down and drop top plug and kick out with 10 bbls of Printed: 4/16/2007 11:26:15 AM i ~ BP EXPLORATION Page 5 of 13 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 4/5/2007 4/6/2007 V-2181000 V-218 Spud Date: 4/1 /2007 DRILL+COMPLETE Start: 3/31/2007 End: 4/14/2007 NABOBS ALASKA DRILLING I Rig Release: 4/14/2007 NABOBS 9ES Rig Number: From - To ;Hours 1 Task 00:00 - 00:30 1 0.50 CEMT 00:30 - 01:30 I 1.00 CEMT 01:30 - 05:30 ~ 4.00 ~ CEMT Code ~ NPT ~ Phase Description of Operations P SURF water. Reciprocated casing during cement pumping. P SURF Switch over to rig pumps and displace cement with 236 bbls of 9.2 ppg mud ~ 5 bpm, 165 psi ICP, 730 psi FGP. Slow pump to 2 bpm 7 bbls prior to bumping plug, 585 psi ICP, 610 psi FCP. Bumped plug C~3 calculated strokes (95.5% efc) with 1,200 psi. CIP ~ 01:30 hr. Bleed off pressure and check floats - OK. Clabbered cement with red dye CQ? surface 57 bbls of displacement away Landed casing on ring with 175 bbls of displacement away due to low slack off weight. PU - 150k, SO - 40k prior to landing casing. Returned all of spacer. Returned 180 bbls of "Sidewalk Cement" P SURF Laydown landing joint. Flush flowline and riser. Rig down casing and cementing equipment. Start nipple down of diverter lines. Clean out from under rotary table 05:30 - 08:30 3.00 DIVRTR P SURF Nipple down diverter riser and change out drilling nipple adapter from 20" to 16". Move surface hydril off of conductor and secure same in cellar. 08:30 - 10:30 2.00 WHSUR P SURF Bring casing head and tubing spool into cellar and nipple up same. Test metal to metal seals to 1,000 psi - 10 min - OK. 10:30 - 13:30 3.00 BOPSU P SURF Nipple up BOPE. 13:30 - 14:30 1.00 BOPSU P SURF Jet and flush BOP stack for BOPE test. 14:30 - 15:00 0.50 BOPSU P SURF Rig up to test BOPE. 15:00 - 19:00 4.00 BOPSU P SURF Pressure test BOPE to 250 psi/4,000 psi for 5 min each test. 250 psi/3,500 psi on annular preventer for 5 min each. Perform Accumulator test. Witnessing of test waived by AOGCC rep John Crisp. Test witnessed by BP WSLs B. Buzby, R. French, NAD TPs B. Tiedemann, R. Hunt, R. Axness. 19:00 - 19:30 0.50 BOPSU P SURF Rig down BOPE test equipment. Slowdown lines. 19:30 - 20:00 0.50 CEMT P SURF Hold rig evacuation drill and post drill discussion. 20:00 - 22:00 2.00 CEMT P SURF Pick up 39 joints of 4" drill pipe to 1,230'. 22:00 - 23:00 1.00 CEMT P SURF Stand back 13 stands of drill pipe. 23:00 - 00:00 1.00 CEMT P SURF PJSM. Cut and slip drilling line 85'. 00:00 - 00:30 0.50 CEMT P SURF Finish cut and slip of drilling line. Inspect brakes. 00:30 - 01:00 0.50 CEMT P SURF Service topdrive, drawworks, and crown. 01:00 - 03:00 2.00 DRILL P PROD1 Pick up and make up BHA #3: New 8.75" HTC HCM506ZX bit, 1.15 deg XP-PDM, NM STAB, LWD/CDR, MWD, LWD/ADN, tea NM DCs, saver sub, 5" HWDP, JAR, 5" HWDP, XO to 4" HWDP 03:00 - 04:00 1.00 DRILL P PROD1 Run in hole with 8 stands of HWDP to 992'. Shallow hole test MWD - OK. 04:00 - 06:30 2.50 DRILL P PROD1 Pick up 30 joints of 4" drill pipe, Ghost Reamer @ 1,945', plus 36 joints of 4" drill pipe to 3,100'. 06:30 - 07:30 1.00 DRILL P PROD1 Circulate air out of system for 15 min. Pressure test 9 5/8" casing to 3,500 psi for 30 min - 0 psi loss. 07:30 - 09:30 2.00 DRILL P PROD1 POH 3 stands. Make up TIW and IBOP valves on string and conduct D6 Stripping Drill into hole. Stripped in 2 stands allowing crew members to take turns on choke. Rig down safety valves and run in hole 2 stands. 09:30 - 10:45 1.25 DRILL P PROD1 Wash and clean out cement to Float collar (tagged 4' high). Drill out Float collar, cement, Float Shoe (4' high), and rat hole Printed: 4/16/2007 17:26:15 AM BP EXPLORATION Operations Summary Report Page 6 of 13 Legal Well Name: V-2181000 Common Well Name: V-218 Spud Date: 4/1/2007 Event Name: DRILL+COMPLETE Start: 3/31/2007 End: 4/14/2007 Contractor Name: NABOBS ALASKA DRILLING 1 Rig Release: 4/14/2007 Rig Name: NABOBS 9ES Rig Number: Date 4/6/2007 4/7/2007 From - To I Hours Task Code NPT 09:30 - 10:45 1.251 DRILL P 10:45 - 11:00 0.25 DRILL P 11:00 - 12:00 1.00 DRILL P 12:00 - 12:30 I 0.501 DRILL I P 12:30 - 00:00 1 11.501 DRILL I P 00:00 - 16:00 I 16.001 DRILL I P 16:00 - 18:00 18:00 - 21:00 21:00 - 22:00 2.00 DRILL P 3.00 DRILL P 1.00 DRILL P 22:00 - 23:00 23:00 - 00:00 4/8/2007 00:00 - 03:00 03:00 - 04:00 1.00 DRILL P 1.00 DRILL P 3.00 DRILL P 1.00 DRILL P 04:00 - 05:30 1.50 DRILL P 05:30 - 07:00 1.50 DRILL P 07:00 - 07:30 0.50 DRILL P 07:30 - 08:30 1.00 BOPSU P 08:30 - 09:30 1.00 BOPSU P 09:30 - 10:00 0.50 BOPSU P ~hase Description of Operations 1 _ --- -_- PROD1 to 12.25" rathole on depth @ 3,332'. 550 gpm, 2,115 psi off, 2,195 psi on, 50 rpm, 5.7k TO off, 5.9k TO on, PU - 104k, SO - 60k, RWT - 76k, WOB - 5-10k. PROD1 Drill 20' of new 8 3/4" hole from 3,332' to 3,352'. PROD1 Displace wellbore from 9.2 ppg mud to 8.8 ppg LSND mud. 565 gpm, 1,265 psi, 60 rpm, 5.7k TO. PROD1 Pull up into casing. Perform 9 5/8" LOT: MD - 3,321', TVD - 2,571', MW - 8.8 ppg, LOP - 700 psi = EMW - 14.04 ppg. Obtain benchmark ECDs: No rotation - 9.17 ppg, 100 rpm - 9.28 PPg• PROD1 Directionally drill from 3,352" to 5,398'. 585 gpm, 2,350 psi on, 2,160 psi off, 100 rpm, 7-9k TO on, 5.7k TO off, WOB - 5-15k, PU - 125k, SO - 75k, RWT - 95k, AST - 0.30 hrs, ART - 5.31 hrs, CECD - 9.61 ppg, AECD - 10.28 ppg. Moderate hydrates to surface G 3,700', depleted by 3,950'. Pumped a 30 bbl, 2.5 ppb SAPP, 13 ppb Nut Plug Med sweep for balled bit ~ 3,337'. ROP picked back up with sweep going around bit. Pumped a 25 bbl high viscosity sweep fp? 4,251' with a 50% increase in cuttings seen at surface. PROD1 Directionally drill from 5,398" to TD ~ 7,283' MD, 4,990' TVD. 585 gpm, 3,275 psi on, 2,985 psi off, 100 rpm, 9.2k TO on, 8k TO off, WOB - 5-15k, PU - 135k, SO - 96k, RWT - 113k, CECD - 9.68 ppg, AECD - 10.31 ppg, AST - 1.68 hrs, ART - 9.75 hrs. Survey every stand, backream 60' prior to connections. MadPassed from 6,308' to 6,259'. PROD1 Circulate bottoms up Q 585 gpm, 3,045 psi, 100 rpm, 8k TO. CECD 9.68 ppg, initial AECD - 10.30 ppg, final AECD - 10.15 ppg. PU - 146k, SO - 100k (without pumps). PROD1 Backream from 7,283' to 5,276' adjusting pulling speeds for ECDs as needed. 585 gpm, 2,950 psi, 100 rpm, 6k TO. PROD1 Continue backreaming from 5,276' to 5,111, with Ghost Reamer in casing, bringing a bottoms up to surface. 585 gpm, 2,595 psi, 100 rpm, 5k TO. IECD - 10.32 ppg, FECD - 10.11 PPg• PROD1 Attempt to POH dry, pulling from 5,111' to 4,950' with overpulls of 35k. Run back in hole to 5,111'. PROD1 Continue backreaming from 5,111' to 4,636'. 585 gpm, 2,595 psi, 100 rpm, 5k TO. PROD1 Continue backreaming from 4,636' to 3,500' attempting to pull dry every 5 stands without overpulls and swabbing -No Go. 585 gpm, 2,300 psi, 100 rpm, 4.5k TO. Slow reaming speed at 4,070' due to packing off. Cleaned up when stand was out. Pulled last 2 stands into 9 5/8" shoe without rotation to 3,321' PROD1 Circulate bottoms up plus additional time until shakers cleaned up. 590 gpm, 1,800 psi, 115 rpm, 4k TO. Had large clayballs to surface. Observe well - OK. MW - 9.3 ppg. Pump dry job. PROD1 POH from 3,321 to BHA (~ 256' PRODi PJSM. Laydown BHA #3. Bit grade: 2-3-WT-S-X-1-BU-TD PROD1 Clean and clear rig floor of drilling tools. RUNPRD Pull wear bushing, flush BOP stack and install BOPE test plug. RUNPRD Change out upper pipe rams from 3.5" x 6" VBRs to 7". RUNPRD Rig up and test 7" rams to 4,000 psi - OK. Rig down test equipment. Printed: 4/16/2007 11:26:15 AM BP EXPLORATION Operations Summary Report Page 7 of 13 Legal Well Common W Event Nam Contractor Rig Name: Date ; Name: ell Name: e: Name: From - To j V-21810 V-218 DRILL+C NABOB NABOB Hours: 00 OMPLE S ALASK S 9ES Task __ TE A DRI Code - - LING NPT Start I Rig Rig Phase Spud Date: 4/1/2007 : 3/31/2007 End: 4/14/2007 Release: 4/14/2007 Number: Description of Operations - - 4/8/2007 10:00 - 11:00 1.00 _ CASE P - RUNPRD _ Make dummy run with 7" hanger and landing joint. Rig up to run casing. 11:00 - 15:30 4.50 CASE P RUNPRD PJSM. Pick up and make up (Baker Lok) 7" shoe track. Check floats - OK. Continue running in hole ~ 1.5 minutes per joint with 7" 26# L-80 BTC-M casing to 2,021'. Fill each joint and break circulation every 15 joints for 3 minutes. Make up casing to mark with average make-up torque of 8,600 fVlbs. Used BOL-2000 M pipe lubricant. 48 total joints of BTC-M casing. 15:30 - 17:00 1.50 CASE P RUNPRD Rig up Torque turn equipment for Vam Top and TCII casing. 1st set of tongs would not bite. Change out tongs - OK. 17:00 - 18:30 1.50 CASE P RUNPRD Continue running in hole C~3 1.5 minutes per joint with 7" 26# L-80 Vam Top casing from 2,021' to 2,585'. Fill each joint and break circulation every 15 joints for 3 minutes. Torque Turn casing to make-up torque of 11,950 fUlbs. Used JetLube Seal Guard pipe lubricant. 13 total joints of Vam Top casing. 18:30 - 19:00 0.50 CASE P RUNPRD Continue running in hole ~ 1,5 minutes per joint with 7" 26# L-80 TCII casing from 2,585' to 3,197'. Fill each joint and break circulation every 15 joints for 3 minutes. Torque Turn casing to make-up torque of 10,100 fUlbs. Used JetLube Seal Guard pipe lubricant. 13 total joints of Vam Top casing. 19:00 - 20:00 1.00 CASE P RUNPRD Circulate 1 1/2 bottoms up @ 5 bpm, 275 psi. PU - 98k, SO - 79k. 20:00 - 00:00 4.00 CASE P RUNPRD Continue running in hole @ 1.5 minutes per joint with 7" 26# L-80 TCII casing from 3,197' to 4,919'. Fill each joint and break circulation every 10 joints for 5 minutes. 'No mud losses for casing run to midnight. 4/9/2007 00:00 - 04:00 4.00 CASE P RUNPRD Continue running in hole ~ 1.5 minutes per joint with 7" 26# L-80 TCII casing from 4,919' to 7,244'. Fill each joint and break circulation every 10 joints for 5 minutes. Pick up 7" hanger, landing joint and land casing on depth ~ 7,273', Up wt 175k Dn Wt115k HES Float Shoe - Bottom C 7,273' 1 Jt 7", 26#, L-80 BTC-Mod (#1) HES Float Collar - Top ~ 7,228' 1 Jt 7", 26#, L-80 BTC-Mod (#2) HES Landing Collar - Top ~ 7,185' 6 Jts 7", 26#, L-80 BTC-Mod (#3-8) 7", 26#, L-80 BTC-Mod Marker Pup Jt. w/ RA ~ 6,921' 23 Jts 7", 26#, L-80 BTC-Mod (#9- 31) 7", 26#, L-80 BTC-Mod Marker Pup Jt. w/ RA @ 5,958' 17 Jts 7", 26#, L-80 BTC-Mod (#32- 48) 7", 26#,L-80 Vam Top HC X BTC-Mod Crossover Pup. 13 Jts 7", 26#, Vam Top HC (#49-61) 1 Jt 7", 26#, L-80 TC-II X Vam Top HC Crossover jt. 41 Jts 7", 26#, L-80 TC-II (#62 - 102) 7" 26# L-80 BTC-M X TC-II crossover pup 7" HES ES Cementer ~ 3,010' 7" 26# L-80 TC-II X BTC-M crossover pup 73 Jts 7", 26#, L-80 TC-II (#103 - 175) 7" 26# L-80 TC-II Pup Jt. FMC Hanger Printed: 4/16/2007 11:26:15 AM BP EXPLORATION Operations Summary Report Page 8 of 13 Legal Well Name: V-2181000 Common Well Name: V-218 Spud Date: 4/1/2007 Event Name: DRILL+COMPL ETE Start: 3/31/2007 End: 4/14/2007 Contractor Name: NABOBS ALAS KA DRILLING I Rig Release: 4/14/2007 Rig Name: NABOBS 9ES Rig Number: Date ~ From - To ~ Hours Task ~ Code ~ NPT Phase ~ Description of Operations 4/9/2007 00:00 - 04:00 4.00 CASE P RUNPRD 7 1/8" x 8 1/4" Rigid Straight Blade Centralizers: 04:00 - 04:30 0.50 CEMT P RUNPRD Rig down Frank's tool. Make up cementing head. 04:30 - 07:00 2.50 CEMT P RUNPRD Break circulation. Stage pumps up to 5 bpm, 485 psi. Condition mud for 1st stage cement. Held cementing PJSM while circulating. Reciprocate casing 15 ft strokes. PU - 175k, SO - 175k. 07:00 - 08;00 1.00 CEMT P RUNPRD Switch to Dowell. Pump 5 bbls water. Pressure test lines to 4,000 psi - OK. Pump 31 bbls 10.2 ppg of MudPush II viscosified spacer @ 5 bpm, 385 psi. Mix on the fly and pump 100 bbls of 11.5 ppg LiteCrete lead cement @ 5.4 bpm avg, 347 max psi, followed by 52 bbls of Class "G" 15.8 ppg tail cement C 5.2 bpm avg, 238 psi. Drop plug and kick out with 10 bbls of water. 08:00 - 09:30 1.50 CEMT P RUNPRD Switch to rig and displace cement with 265 bbls of 9.3 ppg mud. 1st 198 bbls ~ 5 bpm, 275 psi ICP, 1,160 psi FCP. Stopped reciprocating and landed casing with 209 bbls away. PU - 145k, SO - 80k. Last 67 bbls C~3 2 bpm, 1,130 psi ICP, 1,360 psi FCP. Bumped plug at calculated strokes with 95% pump efficiency to 1,610 psi. CIP C~ 09:13 hr. Bleed off pressure, check for flowback - OK. *Mudpush C~ surface when plug bumped. 09:30 -.10:00 0.50 CEMT P RUNPRD Load and lock-in closing plug in cement head. Pressure up and shear ES Cementer ~ 3,475 psi. 10:00 - 15:45 5.75 CEMT P RUNPRD Circulate through ES Cementer @ 3 bpm, 550 psi. Returned 30 bbls of MudPush and 50 bbls of cement to surface. Continue circulate and condition mud back to 9.0 ppg @ 6 bpm, 300 psi. Reduce rate to 3 bpm, 165 psi while waiting for 100 be thickening time. 15:45 - 16:30 0.75 CEMT P RUNPRD Switch to Dowell. Pump 5 bbls water. Pressure test lines to 4,000 psi - OK. Pump 33 bbls 10.0 ppg of MudPush II viscosified spacer ~ 5 bpm, 187 psi. Mix on the fly and pump 86 bbls of Class "G" 15.8 ppg tail cement ~ 5 bpm avg, 200 psi. Drop closing plug and kick out with 10 bbls of water. 16:30 - 17:00 0.50 CEMT P RUNPRD Switch to rig and displace cement with 105 bbls of 9.0 ppg mud ~ 6 bpm, 140 psi ICP, 1,145 psi FCP. Last 3 bbls @ 2 bpm, 990 psi. Bumped plug at calculated strokes with 95% pump efficiency to 1,875 psi. CIP ~ 16:53 hr. Bleed off pressure, check for flowback - OK. '10 bbls of cement returned to surface. 17:00 - 18:00 1.00 CEMT P RUNPRD Rig down cement head. Laydown landing joint and rig down casing equipment. 18:00 - 19:30 1.50 CEMT P RUNPRD Rig up and jet BOP stack with ported sub. Function BOP's and jet again. Jet flowline. 19:30 - 20:30 1.00 WHSUR P RUNPRD Install 7" x 9 5/8" packoff and test same to 5,000 psi - 15 min - OK. 20:30 - 21:30 1.00 BOPSU P RUNPRD Change top pipe rams from 7" to 3.5" VBRs. 21:30 - 23:00 1.50 BOPSU P RUNPRD Rig up and pressure test top VBRs to 250 psi / 4,000 psi for 5 minutes each test. Rig down test equipment and install wear bushing. 23:00 - 00:00 1.00 CLEAN P CLEAN Pick up and make up cleanout BHA #4: Used 6 1/8" insert bit, 2 junk baskets, bit sub, 1 4 3/4" DC, Csg scraper, 2 4 3/4" DCs, xo 5 stands 4" HWDP, JAR, 3 stands HWDP. 4/10/2007 00:00 - 00:30 0.50 CLEAN P CLEAN Finish making up BHA and run in hole on HWDP to 874'. Printed: 4/16/2007 11:26:15 AM ! • BP EXPLORATION Operations Summary Report Legal Well Name: V-2181000 Common Well Name: V-218 Event Name: DRILL+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 9ES Date From - To Hours Task ~ Code NPT~ Start: 3/31 /2007 Rig Release: 4/14/2007 Rig Number: Phase 4/10/2007 00:30 - 02:00 1.50 CLEAN P CLEAN 02:00 - 03:00 1.00 CLEAN P CLEAN 03:00 - 05:00 2.00 CLEAN P CLEAN 05:00 - 05:30 0.50 CLEAN P CLEAN 05:30 - 06:00 ~ 0.501 CLEAN P CLEAN 06:00 - 07:00 I 1.001 CLEAN I P I I CLEAN 07:00 - 10:00 3.00 CLEAN P C LEAN 10:00 - 10:30 0.50 CLEAN P C LEAN 10:30 - 11:00 0.50 CLEAN P CLEAN 11:00 -12:00 1.00 PERFO P OTHCMP 12:00 - 12:30 0.50 PERFO P OTHCMP 12:30 - 13:30 1.00 PERFO P OTHCMP 13:30 - 15:00 1.50 PERFO P OTHCMP 15:00 - 15:30 I 0.501 PERFOBI P I I OTHCMP 15:30 - 16:00 0.50 PERFO P OTHCMP 16:00 - 16:30 0.50 PERFO P OTHCMP 16:30 - 17:00 0.50 PERFO P OTHCMP 17:00 - 19:30 2.50 PERFO P OTHCMP 19:30 - 21:00 I 1.501 PERFOBI P I I OTHCMP 21:00 - 22:00 I 1.001 PERFOBI P I I OTHCMP 22:00 - 23:00 1.001 PERFOB P I ~ OTHCMP 23:00 - 00:00 I 1.001 PERFOBI P I I OTHCMP 4/11/2007 00:00 - 00:30 0.50 PERFOB~ P OTHCMP 00:30 - 01:15 0.75 PERFO P OTHCMP 01:15 - 04:00 2.75 PERFO~ P OTHCMP 04:00 - 06:00 2.00 PERFO P OTHCMP Page 9 of 13 Spud Date: 4/1 /2007 End: 4/14/2007 Description of Operations Run in hole with cleanout assembly from 874' to 2,950' Wash down and tag up on ES Cementer on depth @ 3,010'. Drill out cementer with 250 gpm, 750 psi, 60 rpm, 2-3k TO, 10-18k WOB, PU - 74k, SO - 60k, 68k RWT. Circulated bottoms up ~ 540 gpm, 2,515 psi. Run in hole from 3,012' to 6,995'. Precautionary wash from 6,970' to top of cement CQ3 7,172'. Clean out cement to 7,180'. 380 gpm, 2,510 psi, 60 rpm, 6-7k TO Circulate bottoms up C~2 385 gpm, 2,430 psi, 60 rpm, 6-7k TO, PU - 140k, SO- 74k, RWT - 93k. Displace from 9.0 ppg mud to 9.0 ppg brine. 380 gpm, 2,380 psi, 60 rpm, 7.5k TO. Clean out from under shakers. Clean mud troughs and trip tank. Monitor well - OK. POH from 7,180' to BHA. PJSM. Laydown cleanout BHA. Junk baskets were empty. Clear and clean rig floor. Rig up to pick up DPC pert guns. Service topdrive, crown and drawworks. Pressure test 7" casing to 4,000 psi - 30 min. Good test. PJSM. Pick up and make up 4.5" HSD Power Jet Omega 4505 5 SPF DPC perforating guns, XO, bumper sub, MWD, XO, 1 stand of 4" HWDP, 10 tt pup joint. Run in hole with DPC pert assembly from 566' to 1,209'. *Note all depths reported are to bottom nose. G/R sensor is 443 ft up from bottom nose. Attempt to test MWD ~ 290 gpm, 480 psi. No test. Continue running in hole from 1,209' to 2,166'. Test MWD @ 290 gpm, 585 psi - OK. Continue running in hole from 2,166' to 6,471' @ 1 stand per minute running speed. Log 1 stand with MW D from 6,471' to 6,375' to confirm RA tag 5,958'. RA tag correlated 2 ft deep to original logs. No correction in depths at this time. Continue running in hole from 6,375' to PBTD C~3 7,180' ~ 1 stand per minute running speed. PU - 160k, SO - 75k. Stand 1 stand back to 7,140'. Log up from 7,140' to 6,949'. Run in hole to 7,045'. Make confirmation log pass from 7,045' to 6,985'. MWD logs correlated exactly to original logs. No corrections. PJSM. Initial firing sequence and wait 5 minutes for guns to fire. Had positive indication of guns firing. Observed initial foss of 8 bbls. Guns fired ~ 00:00 hr. Perf Intervals: 6,610' to 6,655' 6,710' to 6,755' 6,775' to 6,795' 6,928' to 6,985' POH 5 stands from 6,985' to 6,566'. No excess drag. Circulate 2 bottoms up ~ 280 gpm, 930 psi. Loss rate C 12 bph. POH from 6,566' to 464'. Loss rate @ 3 bph. Laydown MWD, bumper sub. Laydown DPC pert gun Printed: 4/16/2007 11:26:15 AM • i BP EXPLORATION Page 10 of 13 ~ Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: ell Name: e: Name: From - To V-21810 V-218 DRILL+C NABOB NABOB Hours ~ 00 OMPLE S ALASK S 9ES Task TE A DRI Code i LING NPT Start I Rig Rig Phase Spud Date: 4/1/2007 : 3/31/2007 End: 4/14/2007 Release: 4/14/2007 Number: Description of Operations 4/11/2007 04:00 - 06:00 2.00 PERFO P OTHCMP assembly. All guns fired. Loss rate ~ 3 bph. 06:00 - 06:30 0.50 PERFO P OTHCMP Clean and clear rig floor of pert tools. 06:30 - 07:30 1.00 PERFO P OTHCMP Slip and cut drilling line 77 ft. 07:30 - 08:00 0.50 PERFO P OTHCMP Service topdrive, crown, blocks and drawworks. 08:00 - 10:30 2.50 EVAL N WAIT OTHCMP Wait on SLB E-line. Contacted SLB ~ 02:30 hr. Crew was going to yard from previous job. Had to get tools ready and checked out. Crew was then put to bed and fresh crew came out. 10:30 - 11:30 1.00 EVAL P OTHCMP PJSM. Rig up SLB E-line. *Lost 32 bbls of 9.0 ppg brine to perfs from midnight to noon. 11:30 - 14:00 2.50 EVAL P OTHCMP Run in hole with 5.95 gauge ring and junk basket to PBTD 7,180'. POH. 14:00 - 15:00 1.00 EVAL P OTHCMP Rig down gauge ring and junk basket. Junk basket was empty. Rig up USIT tools. 15:00 - 21:30 6.50 EVAL P OTHCMP Run in hole with USIT logging tools to PBTD ~ 7,180'. Log up from 7,150' to surface. Logs indicated top of good cement C~ 3,070'. Perforation intervals matched up with MW D formation log depths. 21:30 - 22:30 1.00 EVAL P OTHCMP Rig down SLB E-line. 22:30 - 23:00 0.50 CLEAN P CLEAN Pick up BHA tools to rig floor. 23:00 - 00:00 1.00 CLEAN P CLEAN Pick up and make up cleanout BHA: Used 6 1/8" insert bit, 2 junk baskets, bit sub, 1 3.5" HWDP, Csg scraper, XO, 5 stands 4" HWDP, JAR, 3 stands HWDP. *Lost 22 bbls of 9.0 ppg brine to perfs from noon to midnight. *Lost 54 bbls total for the day. 4/12/2007 00:00 - 02:30 2.50 CLEAN P CLEAN Run in hole from 814' to 7,140'. Worked scraper through pert intervals. Wash down to PBTD ~ 7,180'. 02:30 - 03:30 1.00 CLEAN P CLEAN Cycle pumps on and off several times to attempt to catch any debris in junk baskets. Circulate bottoms up @ 394 gpm, 2,100 psi. Had fine sand, and small pieces of metal in returns. 9.0 PP9 MW. 03:30 - 09:00 5.50 CLEAN P CLEAN Monitor well -static. POH laying down drill pipe from 7,180' to cleanout BHA. 09:00 - 09:30 0.50 CLEAN P CLEAN Laydown cleanout BHA. cleanout junk baskets. Recovered 1/3 of a 5 gal bucket of cement chunks and small pieces of metal. 09:30 - 10:00 0.50 CLEAN P CLEAN Clean and clear rig floor of cleanout tools. 10:00 - 10:30 0.50 BUNCO RUNCMP Pull wear bushing. Make dummy run with tubing hanger and landing joint. 10:30 - 11:30 1.00 BUNCO RUNCMP Pick up tubing running equipment, SWS and HES equipment to rig floor. *Lost 38 bbls of 9.0 ppg brine to perfs from midnight to noon. 11:30 - 13:30 2.00 BUNCO P RUNCMP Rig up to run completion. 13:30 - 19:00 5.50 BUNCO RUNCMP PJSM. Pick up and make up 3.5" 9.2# L-80 TCII Tri-HES packer, Dual I-wire completion jewelry and tubing to #3 packer C~ 477'. Torque turn and make up connections to 2,300 ft/Ibs TO. Used JetLube Seal Guard pipe lubricant. *All connections below bottom packer were Baker-Lok'd. Installed 2 Phoenix pressure sensors, splicing I-wires at packers. Test I-wire lines and connections to 5,000 psi - OK. 19:00 - 00:00 5.00 BUNCO RUNCMP Continue running in hole with completion assembly from 477' to 3,100'. Check I-wire integrity every 1,000'. *Lost 6 bbls of 9.0 ppg brine to perfs from noon to midnight. Printed: 4/16/2007 11:26:15 AM • • BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: .Rig Name: Date I From - To ''4/12/2007 19:00 - 00:00 4/13/2007 00:00 - 06:00 06:00 - 10:00 10:00 - 10:30 10:30 - 13:00 13:00 - 13:30 13:30 - 15:00 15:00 - 15:30 V-2181000 V-218 DRILL+COMPLETE NABOBS ALASKA DRILLING I NABOBS 9ES Hours I Task ~ Code . NPT Start: 3/31 /2007 Rig Release: 4/14/2007 Rig Number: Phase Page 11 of 13 Spud Date: 4/1 /2007 End: 4/14/2007 Description of Operations 5.00 BUNCO RUNCMP *Lost 44 bbls for the day. *Lost 98 bbls total to perfs. 6.00 BUNCO RUNCMP Continue running in hole with 3.5" completion assembly from 3,100' to 5,615'. Tested I-wire integrity every 1,000'. *Top packer set down on HES Cementer ~ 3,010'. Turned string 1/4 tum and went through cementer with 5-6k. Checked I-wire integrity - OK. 4.00 BUNCO RUNCMP Continue running in hole with 3.5" completion assembly from 5,615' to 7,021'. Tested I-wire integrity every 1,000'. Space out and position tubing per plan ~ 7,050'. 0.50 BUNCO RUNCMP PJSM. Rig up SLB E-line. 2.50 BUNCO RUNCMP Run in hole with GR/CCL tools to 7,000' and log up. Tie in tubing to perfs. No depth or pipe tally corrections. POH. 0.50 BUNCO RUNCMP Rig down SLB E-line. 1.50 BUNCO P RUNCMP Laydown 1 joint of tubing. Pick up landing joint and tubing hanger. Terminate I-wire equipment. 0.50 BUNCO RUNCMP Land tubing. PU - 90k, SO - 55k. Run in lock-down screws on tubing spool ITEM 3.5" 9.2 # W LEG, 3.5" TC-II -Bottom @ 7,050'. Tops: 3.5" HES 'XN' Nipple: ID 2.750 No-Go @7,028'. 3.5" HES 'X' Nipple: 2.813" ID RHC-M Plug @ 7,007'. GLM #1 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch 6,978'. 1 jt 3.5" 9.2# L-80 TC-II Tubing (# 1) 3.5" HES 'X' Nipple: 2.813" ID @ 6,926'. 3.5" x 7" HES single feedthru Packer (1 port) #1 packer ~ 6,903'. 2 jts 3.5" 9.2# L-80 TC-II Tubing (# 2 - 3) GLM #2 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch Ca3 6,801'. 1 jt 3.5" 9.2# L-80 TC-II Tubing (# 4) GLM #3 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch ~ 6,713'. Phoenix Sensor sub @ 6,701'. 3.5" x 7" HES single feedthru Packer (2 ports) # 2 packer 6,687'. 3.5" HES 'X' Nipple: 2.813" ID ~ 6,672'. GLM #4 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch @ 6,648'. 3.5" 9.2# L-80 TC-II Pup RA TAG in Centralizer @ 6,609'. GLM #5 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch ~ 6,599'. Phoenix Sensor sub ~ 6,587'. 3.5" x 7" HES Dual feedthru Packer (2 ports) # 3 packer ~ 6,574'. 3.5" HES 'X' Nipple: 2.813" ID ~ 6,553'. 1 jt 3.5" 9.2# L-80 TC-II Tubing (# 5) GLM #6 - 3.5" x 1.5" MMG w/ RD Dummy- RK latch ~ 6,493'. 126 jts 3.5" 9.2# L-80 TC-II Tubing (# 6 - 131 ) 3.5" HES 'X' Nipple: 2.813" ID ~ 2,491'. Printed: 4/16/2007 71:26:15 AM • • BP EXPLORATION Operations Summary Report Legal Well Name: V-2181000 Common Well Name: V-218 Event Name: DRILL+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 9ES Date From - To ~ Hours Task Code NPT 4/13/2007 ~ 15:00 - 15:30 ~ 0.501 BUNCO 15:30 - 17:30 17:30 - 19:00 19:00 - 21:00 21:00 - 00:00 i 4/14/2007 100:00 - 01:30 01:30 - 03:30 03:30 - 06:00 06:00 - 06:30 06:30 - 07:00 07:00 - 07:30 07:30 - 08:30 08:30 - 11:30 2.00 1.50 BUNCO 2.00 BUNCO 3.00 BUNCO 1.50 BUNCO 2.00 BUNCO 2.50 BUNCO 0.50 BUNCO 0.50 BUNCO 0.50 BUNCO 1.00 BOPSU P 3.00 WHSUR P 11:30 - 12:00 0.50 WHSUR P 12:00 - 12:30 0.50 WHSUR P 12:30 - 13:30 1.00 WHSUR P 13:30 - 14:00 0.50 BUNCO 14:00 - 16:00 2.00 BUNCO 16:00 - 18:00 2.00 BUNCO 18:00-18:30 0.50 WHSUR P Start: 3/31 /2007 Rig Release: 4/14/2007 Rig Number: Phase Page 12 of 13 Spud Date: 4/1/2007 End: 4/14/2007 Description of Operations RUNCMP 76 jts 3.5" 9.2# L-80 TC-II Tubing (# 132 - 207 ) 2 ea Space out pup jts 3.5" 9.2# L-80 TC-II (14.77' - 2.04') 1 jt 3.5" 9.2# L-80 TC-II Tubing (# 208 ) 3.5" 9.2# L-80 TC-II Hanger Pup 4.5" X 3.5" TC-II Crossover FMC Tubing Hanger w/4 1/2" TC-II Lifting Threads Nabors 9-ES RKB - 23.77' Up wt 90k Dn wt 55k Ran a total of 115 full cannon clamps, 13 Half clamps RUNCMP PJSM. Drop 1 5/16" rod and ball assembly, laydown landing joint. Pressure up tubing to 4,000 psi to set packers. Hold pressure for tubing test - 30 min - OK. Bleed tubing pressure to 2,200 psi. (Simulating test as if shear valve in top mandrel) Pressure up annulus to 4,000 psi. Tubing pressure started tracking annulus pressure ~ 2,700 psi to 4,000 psi. Hold annulus test for 30 minutes - OK. Bleed tubing pressure to 2,000 psi. Annulus pressure bled down to 3,600 psi and held. Bleed annulus to 0 psi, bleed tubing pressure to 0 psi. Open blind rams and pressure up on annulus to check for communication to tubing. OK - No communication. Bleed off pressure to 0 psi. RUNCMP PJSM. Rig up SLB slickline. RUNCMP Slick line run #1: Ran in hole to 6,572' and set slip-lock catcher. POH. RUNCMP Slick line run #2: Ran in hole to 6,497' to pull dummy valve in top mandrel. POH without dummy valve. Redress tools. RUNCMP Slick line run #3: Ran in hole to 6,497' to pull dummy valve in top mandrel. POH with dummy valve. RUNCMP Slick line run #4: Ran in hole to 6,497' to set flow sleeve in top mandrel. POH. RUNCMP Slick line run #5: Ran in hole to 6,572' to pull slip-lock catcher. POH with catcher. RUNCMP Confirm circulation through flow sleeve both ways @ 3 bpm, 150 psi - OK. RUNCMP Rig down SLB slick line. RUNCMP Set 2-way check valve with T-bar. Test valve from below to 1,000 psi - OK. RUNCMP Nipple down ROPE. Set stack on pedestal. RUNCMP Bring tree adapter and double master valve tree into cellar. Install SBMS. Nipple up adapter, terminate I-wires. Test I-wire integrity and adapter to 5,000 psi - 10 min - OK. RUNCMP Nipple up double master valve. RUNCMP Test master valve to 5,000 psi - OK. RUNCMP Rig up Drill Site Maintenance lubricator. Pull 2-way check valve. RUNCMP Rig up to reverse circulate and U-tube. RUNCMP Reverse circulate 227 bbls of clean 9.0 ppg brine, followed by 87 bbls of corrosion inhibited brine @ 3 bpm, 350 psi. RUNCMP PJSM with LRHOS. Pressure test lines to 3,500 psi - OK. Reverse circulate 117 bbls of 70 deg diesel @ 3 bpm, 600 psi ICP, 700 psi FCP. U-tube diesel back to tubing. 0 psi SIP on tubing and inner annulus. RUNCMP Install BPV with lubricator. Test valve from below to 1,000 psi - Printed: 4/16/2007 11:26:15 AM ' ~ • • BP EXPLORATION Page 13 of 13 Operations Summary Report Legal Well Name: V-2181000 Common Well Name: V-218 Spud Date: 4/1/2007 Event Name: DRILL+COMPLETE Start: 3/31/2007 End: 4/14/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/14/2007 Rig Name: NABOBS 9ES Rig Number: Date From - To ~~ Hours Task ~ Code NPT Phase Description of Operations ',,4/14/2007 18:00 - 18:30 0.50 WHSUR P RUNCMP OK. Install VR plugs in IA. 18:30 - 19:00 0.50 WHSUR P RUNCMP Rig down DSM and LRHOS. 19:00 - 20:00 1.00 WHSUR P RUNCMP Remove secondary annulus valves. Secure double valve tree. 20:00 - 21:00 1.00 RIGD P RUNCMP Rig down 16" drilling nipple adaptor. Rig down floor. 21:00 - 00:00 3.00 RIGD P RUNCMP Remove remaining fluid in mud pits. *Release rig for move to V-2151 ~ 23:59 hr, 4/14/2007. Printed: 4/16/2007 11:26:15 AM by 1'~0} ,iii Ip V-218 Su Report Schlumberger Client: BP Exploration Alaska Field: Prudhoe Bay Unit • WOA Structure /Slot: V-Pad /Plan V-218 (N-V) Well: V-218 Borehole: V-218 UWVAPI#: 500292335000 Survey Name /Date: V-218 /April 8, 2007 Tort /AHD / DDI / ERD ratio: 107.772° / 4889.86 ft / 5.886 / 0.980 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location LaVlong: N 70.32814847, W 149.26421454 Location Grid NIE Y/X: N 5970138.470 ftUS, E 590723.980 ftUS Grid Convergence Angle: +0.69284644° Grid Scale Factor: 0.99990935 Survey / DLS Computation Method: Minimum Curvature / Lubinski Vertical Section Azimuth: 89.620° Vertical Section Origin: N 0.000 ft, E 0.000 ft TVD Reference Datum: Rotary Table TVD Reference Elevation: 82.00 ft relative to MSL Sea Bed /Ground Level Elevation: 53.50 ft relative to MSL Magnetic Declination: 23.722° Total Field Strength: 57635.283 nT Magnetic Dip: 80.894° Declination Date: April 04, 2007 Magnetic Declination Model: BGGM 2006 . North Reference: True North Total Corr Mag North -> True North: +23.722° Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de n n ft tt ft ft tt de 00 ft ftUS ftUS RTE 0.00 0.00 0.00 -52.00 U.OU U.00 OAU O.UU O.UU U.UU U.UU b9/U13tt.4/ byU/2a.ytS N /U.;i1ti14tS4/ W 14y.Lt)4'L74b4 GYD GC MS 100.00 0.13 152.58 18.00 100.00 0.05 0.11 0.11 -0.10 0.05 0.13 5970138.37 590724.03 N 70.32814819 W 149.26421411 200.00 0.26 136.17 118.00 200.00 0.26 0.45 0.45 -0.37 0.26 0.14 5970138.11 590724.25 N 70.32814747 W 149.26421242 300.00 0.39 63.29 218.00 300.00 0.72 0.95 0.81 -0.38 0.72 0.40 5970138.10 590724.71 N 70.32814744 W 149.26420868 400.00 4.66 1.76 317.88 399.88 1.18 5.22 4.01 3.84 t .15 4.49 5970142.32 590725.09 N 70.32815896 W 149.26420520 500.00 8.43 8.12 417.21 499.21 2,41 16.60 15.34 15.16 2.31 3.83 5970153.66 590726.11 N 70.32818989 W 149.26419579 600.00 10.75 19.76 515.82 597.82 6.71 33.20 31.87 31.20 6.50 3.01 5970169.74 590730.10 N 70.32823370 W 149.26416181 700.00 11.59 36.39 613.95 695.95 15,94 52.45 50.54 48.07 15.62 3.32 5970186.72 590739.01 N 70.32827978 W 149.26408790 Last GYD GC MS 800.00 13.65 44.28 711.54 793.54 30.24 74.26 71.15 64.60 29.82 2.68 5970203.42 590753.01 N 70.32832496 W 149.26397274 First MWD+IFR+MS 854.81 15.08 52.32 764.64 846.64 40.46 87.84 83.75 73.59 39.98 4.47 5970212.53 590763.06 N 70.32834952 W 149.26389036 946.23 16.37 58.23 852.64 934.64 60.92 112.59 106.41 87.65 60.34 2.25 5970226.83 590783.25 N 70.32838791 W 149.2637 1042.50 19.61 65.14 944.20 1026.20 87.22 142.29 133.45 101.59 86.55 4.02 5970241.09 590809.28 N 70.32842599 W 149.2635 1138.24 21.97 71.83 1033.71 1115.71 118.90 176.24 164.13 113.93 118.15 3.49 5970253.81 590840.73 N 70.32845971 W 149.26325645 1233.98 25.49 75.85 1121.35 1203.35 155.98 214.75 198.96 124.55 155.15 4.04 5970264.88 590877.60 N 70.32848873 W 149.26295635 1329.28 28.58 80.15 1206.23 1288.23 198.39 258.04 238.38 133.47 197.51 3.83 5970274.31 590919.84 N 70.32851309 W 149.26261286 1424.79 31.83 83.22 1288.77 1370.77 245.97 306.08 282.39 140.35 245.05 3.77 5970281.76 590967.29 N 70.32853189 W 149.26222739 1520.57 35.95 87.46 1368.27 1450.27 299.20 359.46 331.44 144.58 .298.24 4.96 5970286.64 591020.43 N 70.32854344 W 149.26179599 1615.91 39.89 90.10 1443.47 1525.47 357.76 418.03 385.43 145.77 356.80 4.47 5970288.53 591078.96 N 70.32854668 W 149.26132113 1711.43 43.69 91.06 1514.68 1596.68 421.39 481.67 444.78 145.11 420.44 4.03 5970288.64 591142.59 N 70.32854486 W 149.26080507 1807.33 44.67 90.47 1583.46 1665.46 488.21 548.50 508.16 144.22 487.27 1.11 5970288.56 591209.42 N 70.32854241 W 149.26026315 1899.96 44.33 90.93 1649.52 1731.52 553.12 613.43 570.51 143.42 552.19 0.51 5970288.55 591274.34 N 70.32854024 W 149.25973669 1995.58 44.05 89.78 1718.09 1800.09 619.77 680.08 635.14 143.01 618.83 0.89 5970288.94 591340.98 N 70.32853909 W 149.25919623 2091.89 48.64 89.79 1784.55 1866.55 689.43 749.74 703.24 143.27 688.50 4.77 5970290.04 591410.63 N 70.32853979 W 149.25863132 SurveyEditor Ver SP 2.1 Bld( doc40x_100) Plan V-218 (N-V)\V-218\V-218\V-218 Generated 5/2/2007 1:08 PM Page 1 of 3 Comments Measured Inclination Azimuth SulrSea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft ft ft de 100 ft ftUS ftUS LltS/.li:i 5:t.4tf tits./:i 1ii44./1 ly1(i./1 /tiJ.iS/ t5L4.ly //ti.45 144.1(1 /(iL.y:S 5.13 5y/ULyl.y~ 5y14t55.U4 N /U.:iLi554'L4ti W 14y.15tSUL/Eiy 2283.38 54.41 87.60 1901.07 1983.07 841.25 901.59 853.01 146.74 840.30 1.36 5970295.35 591562.36 N 70.32854922 W 149.25740030 2379.58 56.17 89.11 1955.84 2037.84 920.31 980.67 931.34 149.00 919.34 2.24 5970298.56 591641.37 N 70.32855537 W 149.25675932 2475.15 55.58 88.30 2009.46 2091.46 999.41 1059.78 1009.75 150.78 998.43 0.93 5970301.30 591720.42 N 70.32856022 W 149.25611793 2570.90 54.92 88.59 2064.04 2146.04 1078.07 1138.46 1087.88 152.92 1077.08 0.73 5970304.39 591799.03 N 70.32856602 W 149.25548019 2666.47 54.51 88.64 2119.24 2201.24 1156.07 1216.47 1165.39 154.81 1155.07 0.43 5970307.22 591876.98 N 70.32857114 W 149.25484774 2761.36 55.37 89.13 2173.75 2255.75 1233.73 1294.14 1242.59 156.32 1232.72 1.00 5970309.66 591954.61 N 70.32857523 W 149.25421800 2857.72 55.09 88.93 2228.70 2310.70 1312.88 1373.29 1321.30 157.66 1311.87 0.34 5970311.96 592033.72 N 70.32857886 W 149.25357620 2953.21 54.73 88.75 2283.60 2365.60 1391.01 1451.43 1399.07 159.24 1389.98 0.41 5970314.49 592111.81 N 70.32858314 W 149.25294271 3049.00 56.53 89.84 2337.67 2419.67 1470.07 1530.49 1477.75 160.20 1469.04 2.10 5970316.41 592190.84 N 70.32858573 W 149.25230163 3143.91 56.29 90.43 2390.18 2472.18 1549.13 1609.55 1556.35 160.02 1548.10 0.58 5970317.18 592269.89 N 70.32858518 W 149.25166Q,~0 3239.39 56.10 90.33 2443.30 2525.30 1628.46 1688.89 1635.23 159.49 1627.44 0.22 5970317.61 592349.22 N 70.32858370 W 149.2510 3272.36 55.81 90.27 2461.76 2543.76 1655.77 1716.21 1662.41 159.35 1654.75 0.89 5970317.80 592376.53 N 70.32858329 W 149.25079560 3349.77 54.79 89.85 2505.83 2587.83 1719.41 1779.85 1725.76 159.28 1718.39 1.39 5970318.50 592440.16 N 70.32858307 W 149.25027952 3413.31 54.45 90.59 2542.62 2624.62 1771.22 1831.66 1777.33 159.08 1770.20 1.09 5970318.93 592491.96 N 70.32858249 W 149.24985941 3509.89 55.97 90.64 2597.72 2679.72 1850.52 1910.97 1856.27 158.23 1849.51 1.57 5970319.03 592571.27 N 70.32858011 W 149.24921627 3606.42 56.72 89.98 2651.22 2733.22 1930.86 1991.32 1936.30 157.80 1929.86 0.96 5970319.57 592651.61 N 70.32857888 W 149.24856470 3702.52 54.44 88.90 2705.54 2787.54 2010.13 2070.59 2015.37 158.56 2009.12 2.55 5970321.30 592730.85 N 70.32858091 W 149.24792193 3798.10 53.66 89.21 2761.65 2843.65 2087.50 2147.96 2092.60 159.84 2086.48 0.86 5970323.51 592808.19 N 70.32858434 W 149.24729456 3894.16 53.83 88.83 2818.46 2900.46 2164.96 2225.42 2169.93 161.16 2163.93 0.36 5970325.77 592885.61 N 70.32858790 W 149.24666648 3989.76 53.80 88.73 2874.90 2956.90 2242.11 2302.58 2246.98 162.81 2241.08 0.09 5970328.35 592962.72 N 70.32859232 W 149.24604090 4085.60 53.44 89.20 2931.74 3013.74 2319.26 2379.74 2324.03 164.20 2318.23 0.54 5970330.67 593039.84 N 70.32859607 W 149.24541528 4180.65 53.40 89.53 2988.39 3070.39 2395.59 2456.07 2400.23 165.05 2394.55 0.28 5970332.44 593116.14 N 70.32859832 W 149.24479636 4277.04 53.40 89.78 3045.86 3127.86 2472.97 2533.46 2477.46 165.51 2471.93 0.21 5970333.84 593193.50 N 70.32859952 W 149.24416884 4372.76 53.52 89.75 3102.85 3184.85 2549.88 2610.36 2554.22 165.83 2548.83 0.13 5970335.09 593270.39 N 70.32860031 W 149.24354519 4468.52 53.51 90.48 3159.79 3241.79 2626.87 2687.35 2631.05 165.67 2625.83 0.61 5970335.86 593347.37 N 70.32859982 W 149.24292084 4564.06 53.61 90.28 3216.54 3298.54 2703.72 2764.21 2707.73 165.16 2702.68 0.20 5970336.28 593424.22 N 70.32859835 W 149.24229758 4660.32 52.95 90.63 3274.09 3356.09 2780.87 2841.37 2784.71 164.55 2779.84 0.75 5970336.61 593501.37 N 70.32859660 W 149.24167190 4755.31 54.32 90.47 3330.41 3412.41 2857.35 2917.86 2861.02 163.82 2856.33 1.45 5970336.80 593577.85 N 70.32859452 W 149.241 4850.67 54.79 90.37 3385.72 3467.72 2935.03 2995.55 2938.55 163.25 2934.01 0.50 5970337.17 593655.53 N 70.32859288 W 149.2404 4946.06 53.77 89.05 3441.41 3523.41 3012.47 3072.99 3015.89 163.64 3011.45 1.55 5970338.49 593732.95 N 70.32859385 W 14923979369 5041.73 53.69 89.42 3498.00 3580.00 3089.60 3150.12 3092.96 164.67 3088.58 0.32 5970340.45 593810.05 N 70.32859658 W 149.23916825 5137.34 53.26 89.49 3554.91 3636.91 3166.43 3226.96 3169.72 165.40 3165.41 0.45 5970342.11 593886.86 N 70.32859849 W 149.23854522 5232.85 53.07 89.51 3612.17 3694.17 3242.88 3303.40 3246.10 166.06 3241.85 0.20 5970343.70 593963.28 N 70.32860023 W 149.23792534 5328.70 52.59 89.55 3670.08 3752.08 3319.25 3379.78 3322.40 166.69 3318.22 0.50 5970345.25 594039.63 N 70.32860185 W 149.23730599 5424.40 53.15 91.21 3727.85 3809.85 3395.54 3456.07 3398.58 166.18 3394.51 1.50 5970345.67 594115.92 N 70.32860036 W 149.23668732 5520.33 52.53 90.86 3785.79 3867.79 3471.97 3532.52 3474.86 164.80 3470.95 0.71 5970345.21 594192.36 N 70.32859649 W 149.23606746 5615.98 53.06 93.10 3843.64 3925.64 3548.08 3608.70 3550.78 162.16 3547.08 1.95 5970343.49 594268.51 N 70.32858919 W 149.23545012 5711.71 52.59 92.93 3901.48 3983.48 3624.22 3684.98 3626.70 158.15 3623.25 0.51 5970340.40 594344.72 N 70.32857813 W 149.23483244 5807.91 51.93 93.28 3960.36 4042.36 3700.15 3761.05 3702.42 154.03 3699.21 0.74 5970337.20 594420.72 N 70.32856677 W 149.23421645 5903.62 51.48 95.74 4019.68 4101.68 3774.99 3836.16 3776.99 148.13 3774.09 2.07 5970332.21 594495.65 N 70.32855055 W 149.23360930 SurveyEditor Ver SP 2.1 Bld( doc40x_100) Plan V-218 (N-V)\V-218\V-218\V-218 Generated 5/2/2007 1:08 PM Page 2 of 3 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure n de de n n n n n ft n de 00 n ftUS ftUS 5yyy.y(i 5L.:iy y(i.l'L 4U/y.Uts 41(i1.Uts ~tsSU.:i/ 3y1L.UI :itSbl.Uts 14U.1y :itf4y. b~ U.yy 5y/U:t'Lb .LtS 6095.55 51.96 96.30 4137.70 4219.70 3925.38 3987.52 . 3926.81 132.12 3924. 59 0.47 5970318 .02 6190.22 52.30 95.60 4195.81 4277.81 3999.66 4062.25 4000.85 124.38 3998. 92 0.69 5970311 .18 6285.99 52.18 95.11 4254.46 4336.46 4074.99 4137.96 4075.99 117.31 4074. 30 0.42 5970305 .02 6381.93 51.78 94.98 4313.55 4395.55 4150.23 4213.55 4151.07 110.66 4149. 59 0.43 5970299 .29 6476.62 51.40 95.15 4372.38 4454.38. 4224.10 4287.74 4224.78 104.11 4223. 50 0.43 5970293 .63 6572.95 50.57 93.88 4433.03 4515.03 4298.67 4362.59 4299.23 98.22 4298. 11 1.34 5970288 .64 6668.59 49.58 93.86 4494.40 4576.40 4371.81 4435.93 4372.28 93.27 4371. 29 1.04 5970284 .58 6764.43 48.73 94.12 4557.09 4639.09 4444.10 .4508.43 4444.49 88.22 4443. 61 0.91 5970280 .41 6859.32 48.40 93.61 4619.88 4701.88 4515.04 4579.57 4515.36 83.43 4514. 59 0.53 5970276 .47 6955.07 47.79 93.53 4683.83 4765.83 4586.14 4650.83 4586.39 78.99 4585. 71 0.64 5970272 .89 7050.55 47.35 93.70 4748.25 4830.25 4656.44 4721.31 4656.64 74.55 4656. 05 0.48 5970269 .30 7145.77 46.62 93.43 4813.21 4895.21 4725.90 4790.93 4726.05 70.22 4725. 53 0.79 5970265 .81 Last MWD+IFR+MS 7212.44 45.97 92.82 4859.27 4941.27 4774.00 4839.13 4774.14 67.59 4773. 66 1.18 5970263 .77 TD (Projected) 7283.00 45.97 92.82 4908.32 4990.32 4824.65 4889.86 4824.77 65.09 4824. 33 0.00 5970261 .88 Survey Type: Definitive Survey NOTES: GYD CT DMS - ( Gyrodata -cont. d rillpipe m/s -- Gyrodata pump-down multishot surveys with continuous tool (RGS-CT) in drill-pipe.) MWD +IFR + MS - (In-field referenced MWD w ith mull-station analysis and correction applied in post-processin g. Assumes a BHA sag correction is appl ied to enhance inclination accuracy. ) Legal Description: Northing (Y) [ftUS] Easting (X) [ftUS] Surface : 4889 FSL 1576 FEL S11 T11 N R11 E UM 5970138.47 590723.98 BHL : 4952 FSL 2032 FEL S12 T11 N R11 E UM 5970261.88 595546.72 5y45/1.1 / N /U.:i1t35LyU:i W 14y.1:iLyy/55 594646.32 N 70.32850661 W 149.23238888 594720.73 N 70.32848535 W 149.23178615 594796.19 N 70.32846593 W 149.23117488 594871.55 N 70.32844766 W 149.23056438 594945.52 N 70.32842965 W 149.22996507 595020.19 N 70.32841343 W 149.22936006 595093.41 N 70.32839979 W 149.22876668 595165.79 N 70.32838589 W 149.22818020 595236.81 N 70.32837267 W 149.22760465 595307.98 N 70.32836043 W 149.2270 595378.35 N 70.32834818 W 149.2264 595447.88 N 70.32833623 W 149.22589412 595496.03 N 70.32832896 W 149.22550389 595546.72 N 70.32832206 W 149.22509301 r ~ SurveyEditor Ver SP 2.1 Bld( doc40x_100) Plan V-218 (N-V)\V-218\V-218\V-218 Generated 5/2/2007 1:08 PM Page 3 of 3 TREE = 4178" ELLHI"-AC1= FMC ACTUATOR = Leo Ke_ ELEV = ~a_~' BF. ELEV = _ 53.5 KC7P = 300' Max Angle = __ 57" ~ 3006' Datum MD = 6521' Datum TVD - 4480' SS """" ~ ~ AF~TY P(OT~ES; GLM's ~ STA #1-#5 Afi -tfZ X 1-iJ2" tv1M("rW V1~t-lit:! AID LG wATe~cx~Q MaNO~s. 20" GSG, 21 S,5#, A-53. WLC? 7 0$' 290' ~ 3-1I~ iiES X NIP, ID - 2813" 9 SJ8 TAM Part Catar, ID=8-835 7" HES, ES Cemer~er, ID= B.17t" 95J8" CSG, 40#, L-80, ID = 8.835" XCl From Vam Tap HC to TG-11 ~-~ 1 Q(18, , 3{309,,.._ ^^~ 3321.'_ ,r~87' Minimum ID = .75" ~ 7f}29' -112" H'ES XN NIPPLE XO From BTG-M to Vam Tap HC ~~~~' - - - 7" i1MRt<ER JtlINT W! RA TACK $~~$$' Ptx~enix Sensar Sub, 12992" --~-- ~~$~' ~ 3-112" T#3G RA Tag In ~ttatizer ~ MARKER JOINT Wl RA TAG ~ s608' ~ ~~~~' PERFCaRAT}ON SUMMARY REI= LOG. SLB USfT' ON 04111107 ANGLE ATTOP PEf2F: Nate: SIZE SPF INT82VAL" OpnJSt~Z DATE. 4.5'" 5 OA 66D8 - 6653 O 04/f 1107 ~ A.S" 5 C3Ba fi708 - 6753 q 0411 L~O~ 4 5" 5 OBb 6773 - B793 Q D4,~11IQ7 ~t_5" S OQd 6926 - 6983 C1 D4111 tD7 `"' N AL P@ ~F t3Ef~THS GO~ G'i°~ A12i 107 P~'t A~ ~ 3-112" TBG, 9.2#, L-80, TGp, .0087 bpf, ~ = 2.892" I PBTD I ~~.. cs~, zfi#, L-aa, ~~~, ID= s.27s' 7180' _ ~v 7273'... GAS LIFT MANDRELS ~T MD TVD DEt! -TYPE VlV LATCI-i PDRT DATE 6 6992 4469 51 MMG FS RK 0 tkitf 3707 WATER 1NJECl7G1N MANPREt.S ~T MD TVD DEV TYPE. VLV LATGti PART DATE 5 6599 4532 50 NTMGW DUM RK 0 04J13ID7 4 6647 4562 50 MMC'xW DUM RtC 0 DM13,'07 3 6712 46i~ 49 MMGL'V DUM FtK (! Q4713lg7 2 6800 4662 98 MMG-W DUM RK 4 D4,'13,~D7 1 6978 4781 47 MMG-W DU~A FtK 4 R4l13l07 s~.~ 3-112" HES X NIP, ifl = ~:~~ ~° 6573' 1-I 7" Xa-1t2' wES AHa p~~x~r, ti3 ~ s,ass° 667`'1' --~ 6$87' 3-itz" HES X ~J~'. ID = 2.813' ~ T' X3xi2" HES AHR Packer, ID = 2.965" 67p~3' _ -_ 6902' E'tiflBRt)f Sensar Stlt), ~ - ~ 9g2" . ~~ ~. 7"X3-t tz' HE~a AWR Packer, ID = 2 9EiS,~ 692°5' _ 3-t/2'" HES X NIP, ID = 2.813" 7{3{37' 31i2" HES X NIP, IQ = 2813" w/RHC-m dug 7027' 700#1' DATE REV BY COMMENTS DATE REV BY COMMENTS D41t~lID7 BJB Original Lkill & Compete 04!21 J67 TWITCH PERF DEPTH CORRECTt4NS ~ 3112" HES XN NlP, iD = 2.75" ~ I 3'{12" WLEG, 1p = 3.fJCY" 1 ORiON UNft" WELL; V-218i PEE~fu11T No: 207-040 A Pl Na: 50-029-23350-£#}-00 4885' t=SL, 1576'F)3, 5ec;11, T11 N, R11 E, t~/I E'xptn~ratinn (Alaska3 ~' Q d SCHLUI"lBERGER Survey report Client .................... BP Exploration (Alaska) Inc. Field ....................: Orion Well .....................: V-218 API number...............: 50-029-23350-00 Engineer .................: St. Amour Rig :.....................: Nabors 9ES State :.................... Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ---- Permanent datum..........: Depth reference..........: GL above permanent.......: KB above permanent.......: DF above permanent.......: ------------------ Mean Sea Level Driller's Pipe Tally 53.40 ft N/A (Topdrive) 82.00 ft ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: -999.25 ft Departure (+E/W-)........: -999.25 ft Azimuth from Vsect Origin to target: 89.62 degrees 8-Apr-2007 10:39:19 Page 1 of 4 Spud date ................: 1-Apr-07 Last survey date.........: 08-Apr-07 Total accepted surveys...: 79 MD of first survey.......: 0.00 ft MD of last survey........: 7283.00 ft ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2006 Magnetic date ............: 01-Apr-2007 Magnetic field strength..: 57635.68 GAMA Magnetic dec (+E/W-).....: 23.73 degrees Magnetic dip .............: 80.89 degrees ----- MWD survey Reference Criteria -- ------- Reference G ..............: 1002.68 meal Reference H ..............: 57636.00 GAMA Reference Dip ............: 80.90 degrees Tolerance of G...........: (+/-) 2.50 meal Tolerance of H...........: (+/-)300.00 GAMA Tolerance of Dip.........: (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 23.71 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 23.71 degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type .... I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction • SCHLUA'IBERGER Survey Report 8-Apr-2007 10:39:19 Page 2 of 4 Seq Measured Intl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 1 0.00 0.00 10.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP None 2 100.00 0.13 152.58 100.00 100.00 0.05 -0.10 0.05 0.11 152.58 0.13 BP _GYD GC MS 3 200.00 0.26 136.17 100.00 200.00 0.2b -0.37 0.26 0.45 144.38 0.14 BP _GYD GC MS 4 300.00 0.39 63.29 100.00 300.00 0.72 -0.38 0.72 0.81 117.47 0.40 BP _GYD GC MS 5 400.00 4.66 1.76 100.00 399.88 1.18 3.84 1.15 4.01 16.70 4.49 BP GYD GC MS 6 7 500.00 600.00 8.43 10.75 8.12 19.76 100.00 100.00 499.21 597.82 2.41 6.71 15.16 31.20 2.31 6.50 15.34 31.87 8.67 11.77 3.83 3.01 BP BP _GYD GC MS _GYD GC MS • 8 700.00 11.59 36.39 100.00 695.95 15.94 48.07 15.62 50.54 18.00 3.32 BP _GYD GC MS 9 800.00 13.65 44.28 100.00 793.54 30.24 64.60 29.82 71.15 24.78 2.68 BP _GYD GC MS 10 854.81 15.08 52.32 54.81 846.64 40.46 73.59 39.98 83.75 28.51 4.47 BP MWD+IFR+MS 11 946.23 16.37 58.23 91.42 934.64 60.92 87.65 60.34 106.41 34.55 2.25 BP _MWD+IFR+MS 12 1042.50 19.61 65.14 96.27 1026.20 87.22 101.59 86.55 133.45 40.43 4.02 BP _MWD+IFR+MS 13 1138.24 21.97 71.83 95.74 1115.71 118.90 113.93 118.15 164.13 46.04 3.49 BP _MWD+IFR+MS 14 1233.98 25.49 75.85 95.74 1203.35 155.98 124.55 155.15 198.96 51.24 4.04 BP _MWD+IFR+MS 15 1329.28 28.58 80.15 95.30 1288.23 198.39 133.47 197.51 238.38 55.95 3.83 BP MWD+IFR+MS 16 1424.79 31.83 83.22 95.51 1370.77 245.97 140.35 245.05 282.39 60.20 3.77 BP _MWD+IFR+MS 17 1520.57 35.95 87.46 95.78 1450.27 299.20 144.58 298.24 331.44 64.14 4.96 BP _MWD+IFR+MS 18 1615.91 39.89 90.10 95.34 1525.47 357.76 145.77 356.80 385.43 67.78 4.47 BP _MWD+IFR+MS 19 1711.43 43.69 91.06 95.52 1596.68 421.39 145.11 420.44 444.78 70.96 4.03 BP _MWD+IFR+MS 20 1807.33 44.67 90.47 95.90 1665.46 488.21 144.22 487.27 508.16 73.51 1.11 BP MWD+IFR+MS 21 1899.96 44.33 90.93 92.63 1731.52 553.12 143.42 552.19 570.51 75.44 0.51 BP _MWD+IFR+MS • 22 1995.58 44.05 89.78 95.62 1800.09 619.77 143.01 618.83 635.14 76.99 0.89 BP _MWD+IFR+MS 23 2091.89 48.64 89.79 96.31 1866.55 689.43 143.27 688.50 703.24 78.24 4.77 BP _MWD+IFR+MS 24 2187.63 53.48 88.73 95.74 1926.71 763.87 144.26 762.93 776.45 79.29 5.13 BP _MWD+IFR+MS 25 2283.38 54.41 87.60 95.75 1983.07 841.25 146.74 840.30 853.01 80.09 1.36 BP MWD+IFR+MS 26 2379.58 56.17 89..11 96.20 2037.84 920.31 149.00 919.34 931.34 80.79 2.24 BP _MWD+IFR+MS 27 2475.15 55.58 88.30 95.57 2091.46 999.41 150.78 998.43 1009.75 81.41 0.93 BP _MWD+IFR+MS 28 2570.90 54.92 88.59 95.75 2146.04 1078.07 152.92 1077.08 1087.88 81.92 0.73 BP _MWD+IFR+MS 29 2666.47 54.51 88.64 95.57 2201.24 1156.07 154.81 1155.07 1165.39 82.37 0.43 BP _MWD+IFR+MS 30 2761.36 55.37 89.13 94.89 2255.75 1233.73 156.32 1232.72 1242.59 82.77 1.00 BP MWD+IFR+MS SCHLUMBERGER Survey Report 8-Apr-2007 10:39:19 Page 3 of 4 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 31 2857.72 55.09 88.93 96.36 2310.70 1312.88 157.66 1311.86 1321.30 83.15 0.34 BP _MWD+IFR+MS 32 2953.21 54.73 88.75 95.49 2365.59 1391.01 159.24 1389.98 1399.07 83.46 0.41 BP _MWD+IFR+MS 33 3049.00 56.53 89.84 95.79 2419.67 1470.07 160.20 1469.04 1477.75 83.78 2.10 BP_MWD+IFR+MS 34 3143.91 56.29 90.43 94.91 2472.18 1549.13 160.02 1548.10 1556.35 84.10 0.58 BP _MWD+IFR+MS 35 3239.39 56.10 90.33 95.48 2525.30 1628.46 159.49 1627.44 1635.23 84.40 0.22 BP _MWD+IFR+MS 36 3272.36 55.81 90.27 32.97 2543.76 1655.77 159.35 1654.75 1662.41 84.50 0.89 BP _MWD+IFR+MS 37 3349.77 54.79 89.85 77.41 2587.83 1719.41 159.28 1718.39 1725.76 84.70 1.39 BP _MWD+IFR+MS • 38 3413.31 54.45 90.59 63.54 2624.62 1771.22 159.08 1770.20 1777.33 84.86 1.09 BP _MWD+IFR+MS 39 3509.89 55.97 90.64 96.58 2679.72 1850.52 158.23 1849.51 1856.26 85.11 1.57 BP _MWD+IFR+MS 40 3606.42 56.72 89.98 96.53 2733.22 1930.86 157.80 1929.86 1936.30 85.33 0.96 BP MWD+IFR+MS 41 3702.52 54.44 88.90 96.10 2787.54 2010.13 158.56 2009.12 2015.37 85.49 2.55 BP _MWD+IFR+MS 42 3798.10 53.66 89.21 95.58 2843.65 2087.50 159.84 2086.48 2092.60 85.62 0.86 BP _MWD+IFR+MS 43 3894.16 53.83 88.83 96.06 2900.46 2164.96 161.16 2163.93 2169.93 85.74 0.36 BP _MWD+IFR+MS 44 3989.76 53.80 88.73 95.60 2956.90 2242.11 162.81 2241.08 2246.98 85.84 0.09 BP _MWD+IFR+MS 45 4085.60 53.44 89.20 95.84. 3013.74 2319.26 164.20 2318.23 2324.03 85.95 0.54 BP MWD+IFR+MS 46 4180.65 53.40 89.53 95.05 3070.39 2395.59 165.05 2394.55 2400.23 86.06 0.28 BP _MWD+IFR+MS 47 4277.04 53.40 89.78 96.39 3127.86 2472.97 165.51 2471.93 2477.47 86.17 0.21 BP _MWD+IFR+MS 48 4372.76 53.52 89.75 95.72 3184.85 2549.88 165.83 2548.83 2554.22 86.28 0.13 BP _MWD+IFR+MS 49 4468.52 53.51 90.48 95.76 3241.79 2626.87 165.67 2625.83 2631.05 86.39 0.61 BP _MWD+IFR+MS 50 4564.06 53.61 90.28 95.54 3298.54 2703.72 165.16 2702.68 2707.73 86.50 0.20 BP MWD+IFR+MS 51 4660.32 52.95 90.63 96.26 3356.09 2780.87 164.55 2779.84 2784.71 86.61 0.75 BP _MWD+IFR+MS • 52 4755.31 54.32 90.47 94.99 3412.41 2857.35 163.82 2856.33 2861.02 86.72 1.45 BP _MWD+IFR+MS 53 4850.67 54.79 90.37 95.36 3467.71 2935.03 163.25 2934.01 2938.55 86.82 0.50 BP _MWD+IFR+MS 54 4946.06 53.77 89.05 95.39 3523.41 3012.47 163.64 3011.45 3015.89 86.89 1.55 BP_MWD+IFR+MS 55 5041.73 53.69 89.42 95.67 3580.00 3089.60 164.67 3088.58 3092.96 86.95 0.32 BP MWD+IFR+MS 56 5137.34 53.26 89.49 95.61 3636.91 3166.43 165.40 3165.41 3169.72 87.01 0.45 BP _MWD+IFR+MS 57 5232.85 53.07 89.51 95.51 3694.17 3242.88 166.06 3241.85 3246.10 87.07 0.20 BP _MWD+IFR+MS 58 5328.70 52.59 89.55 95.85 3752.08 3319.25 166.69 3318.22 3322.40 87.12 0.50 BP _MWD+IFR+MS 59 5424.40. 53.15 91.21 95.70 3809.85 3395.54 166.18 3394.51 3398.58 87.20 1.50 BP _MWD+IFR+MS 60 5520.33 52.53 90.86 95.93 3867.79 3471.97 164.80 3470.95 3474.86 87.28 0.71 BP MWD+IFR+MS i SCHLUMBERGER Survey Report 8-Apr-2007 10:39:19 Page 4 of 4 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 61 5615.98 53.06 93.10 95.65 3925.63 3548.08 162.16 3547.08 3550.78 87.38 1.95 BP _MWD+IFR+MS 62 5711.71 52.59 92.93 95.73 3983.48 3624.22 158.15 3623.25 3626.70 87.50 0.51 BP _MWD+IFR+M5 63 5807.91 51.93 93.28 96.20 4042.36 3700.15 154.03 3699.21 3702.42 87.62 0.74 BP _MWD+IFR+MS 64 5903.62 51.48 95.74 95.71 4101.68 3774.99 148.13 3774.09 3776.99 87.75 2.07 BP _MWD+IFR+MS 65 5999.96 52.39 96.12 96.34 4161.08 3850.37 140.29 3849.53 3852.08 87.91 0.99 BP MWD+IFR+MS 66 6095.55 51.96 96.30 95.59 4219.70 3925.38 132.12 3924.59 3926.81 88.07 0.47. BP _MWD+IFR+MS 67 6190.22 52.30 95.60 94.67 4277.81 3999.66 124.38 3998.92 4000.85 88.22 0.69 BP • _MWD+IFR+MS 68 6285.99 52.18 95.11 95.77 4336.46 4074.99 117.31 4074.30 4075.99 88.35 0.42 BP _MWD+IFR+MS 69 6381.93 51.78 94.98 95.94 4395.55 4150.23 110.66 4149.59 4151.07 88.47 0.43 BP _MWD+IFR+MS 70 6476.62 51.40 95.15 94.69 4454.38 4224.10 104.11 4223.50 4224.78 88.59 0.43 BP MWD+IFR+MS 71 6572.95 50.57 93.88 96.33 4515.02 4298.67 98.22 4298.11 4299.23 88.69 1.34 BP _MWD+IFR+MS 72 6668.59 49.58 93.86 95.64 4576.40 4371.81 93.27 4371.29 4372.28 88.78 1.04 BP _MWD+IFR+MS 73 6764.43 48.73 94.12 95.84 4639.08 4444.10 88.22 4443.61 4444.49 88.86 0.91 BP _MWD+IFR+MS 74 6859.32 48.40 93.61 94.89 4701.88 4515.04 83.43 4514.59 4515.36 88.94 0.53 BP _MWD+IFR+MS 75 6955.07 47.79 93.53 95.75 4765.83 4586.14 78.99 4585.71 4586.39 89.01 0.64 BP MWD+IFR+MS 76 7050.55 47.35 93.70 95.48 4830.25 4656.44 74.55 4656.05 4656.64 89.08 0.48 BP_MWD+IFR+MS 77 7145.77 46.62 93.43 95.22 4895.21 4725.90 70.22 4725.53 4726.05 89.15 0.79 BP _MWD+IFR+MS 78 7212.44 45.97 92.82 66.67 4941.27 4774.00 67.59 4773.66 4774.14 89.19 1.18 BP _MWD+IFR+MS 79 7283.00 45.97 92.82 70.56 4990.31 4824.65 65.09 4824.33 4824.77 89.23 0.00 Projected to TD [(c)2007 IDEAL ID12_OC_01] ~J MEMORANDUM To: Jim Regg P.LSupervisor ~ ~~f~j ~~~Z~~~ FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska OiI and Gas Conservation Commis un DATE: Wednesday, June 20, 2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC V-218 PRUDHOE BAY UN ORIN V-218 Src: Inspector NON-CONFIDENTIAL Reviewed BZ: P.I. Suprv =~~~ Comm Welt Name: PRUDHOE BAY UN GRIN V-218 Insp Num: mitCS070617101330 Rel Insp Num: API Well Number: 50-029-23350-00-00 Permit Number: 207-040-0 Inspector Name: Chuck Scheve Inspection Date: 6/16/2007 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well v-z1x Type Inj. ~'~' TVD ~ asls IA s7o zzto zlao zlao P.T.D zo7oaoo TypeTest SPT Test psi 150o pA o 0 0 0 Interval ~T~- P/F P / Tubing Joao Ilzo 11zo Ilzo NOtes' Pretest pressures observed and found stable. Wednesday, June 20, 2007 Page I of 1 p{~~ y1~{ €( ld 4" ~9 ~~~ \' 1/ 7 kl Sc~lum~erger r ~ ~'",~ ~, ~~i~~ Ib~ Schlumberger-DCS ~~ ~ r e 2525 Gambell St, Suite 400 ~ t ~ _ Anchorage, AK 99503-2838 .. ATTN: Beth WeII Job # Log Description NO- 4292 Company: Alaska Oil 8 Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Orion Borealis Date BL Color CD V-218 11661147 MEMORY TEMP SURVEY 05/19107 1 Z-102 V-04 V-214 11637725 40014377 40014206 CEMENT IMAGEIBOND LOG OH EDIT MWDILWD OH EDIT MWDILWD 05116107 11/28/06 10130106 2 2 1 1 1 L-250 V-122 V-122P81 40012593 40014531 40014531 OH EDIT MWDILWD OH EDIT MWDILWD OH EDIT MWDILWD 11/09105 12/30/06 12/16106 2 2 2 1 1 1 V-122PB2 L-250L1 L-250PB1 40014531 40012593 40012593 OH EDIT MWDILWD OH EDIT MWDILWD OH EDIT MWDILWD 12/28107 11/15/05 10/26105 1 1 2 1 1 1 L-04 40014142 OH EDIT MWDILWD 10/09106 2 1 OWDW-NW 11477941 RST 11/14/06 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACIi TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered: UzC o~0~ - (~l ~ Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: 06/07/07 ~I J • 0~ Schfumherger Sehlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503.2838 ATTN: Beth Well Job # Log Description NO.4256 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Orion Date BL Color CD osnsia~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 ~ ~ ~ ~~ i 900 E Benson Blvd. ~l ~ pp 'is ' ~ Anchorage AK 99508-425A ~r~ I~ .*, f'., f f3 Date Delivered. ~`_ ~. ~0~ " 0~~~ Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: • MEC:3AA_..tZICAL INTEGRITY REPORT _~i~~ ~~--- `~Ir-o~ OPER ~ ~ GELD ~~ ~~~-~n©v~ _-_C rte:.. _. r_:, :. ~ \~~~~~~ }~:-.LL NUL11]t.R ~ ~ (~ _N ~ L L D AT ~_ TD : '•1~~53 . ?~.. ~\~~. ~l TVD ; ? B TD : '~,~~® ?rID_ C\~~TD Casing: '1 Shoe:'~a~~ y~~'3 TVD; liV: X010 ?"ID I'~~i _==,er . ~.lD. Shoe . `~ '?'`1T ; =0~ '_•~ 'iJ _ ~ b ; ~ V • t~ ~ ~_P a C !C e r (p~_ T'~i. Set a t ole Site y and Perfs ~~~ to ~•~~- 6'~'~ 3 ~ ~ ~ 3-~~-c~So3 ~Cc.~?~~C~_:_, INTEGRITY - ??.RT #? 6ct a-Cv 6~1~3 Anr:ulus ?ress Test: _~ 15 min ~0 min Coc~ents . '~'CHpNIC?...1, INTEGRTTY - PART # 2 Cement Voltmmes :~ A.mt. Liner Csg ~~ bb\ DV ~s 4~ Cmt -JOl to cover- ner_s c ~ ~-~~C~i _ ~c ~ ~. S _::eoretical TOC ~~~~ ~ Cement Bond Log Yes r No) ~" ~ In AOGCC File C3L Evaluation, tone above per*s `~~- ~S~~i~~-_ ~_ _ C~ Production 'Log: Type Evaluation CONCLJSIONS: Part #1: ?ar~ 12: ~ ~ Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Christine Mahnken Well No V-218 Date Dispatched: 13-Apr-07 Installation/Rig Nabors 9ES Dispatched By: Nate Rose LWD Log Delivery V1.1,10-02-03 Data No Of Prints No of Floppies Surveys 2 1 Received By: Please sign and return to: q Drilling & Measurements LWD Division `Q ~ ~^~ 2525 Gambell Street, Suite 400 ' Anchorage, Alaska 99501 nroselC~slb.com Fax:907-561-8317 • C®1~TSER~A~`IO1~T C®1-II1'II~SIOI~T .'~ Robert Tirpack Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 SARAH P.4LlN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Orion Oil Pool, PBU V-2181 BP Exploration (Alaska) Inc. Permit No: 207-040 Surface Location: 4889' FSL' 1576' FEL, SEC. 11, T 11 N, R 11 E, UM Bottomhole Location: 4920' FSL, 2029' FEL, SEC.12, T11N, R11E, UM Dear Mr. Tirpack: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05. and Title 20, Chapter 25 of the Alaska Administrative Code unless the -Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (9079-3607 (pager). DATED this ~~of March, 2007 cc: Department of Fish 8v Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. - ~ STATE OF ALASKA `~~G~~ ALAS OIL AND GAS CONSERVATION COMM ,~' PERMIT TO DRILL ~~ ' I ~ 1 a. Type of work ® Drill ^ Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ®Service ^ Multiple Zone ^ Stratigraphic Test ^ Development Oil ^ Single Zone 1 c. Specify if well is prop ^ 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: PBU V-2181 ~ 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: ~ MD 7273' ~ TVD 4973' 12. Field /Pool(s): Prudhoe Bay Field / Orion 4a. Location of Well (Governmental Section): Surface: 4889' FSL 1576' FEL 11 SEC T11N R11E UM ' 7. Property Designation: ADL 028240 Schrader Bluff ~ , , . , , , Top of Productive Horizon: 4982' FSL, 2533' FEL, SEC. 12, T11 N, R11 E, UM ~ 8. Land Use Permit: 13. Approximate Spud Date: March 26, 2007 ~ Total Depth: 4920' FSL, 2029' FEL, SEC. 12, T11 N, R11 E, UM _ 9. Acres in Property: 2560 ~ 14. Distance to Nearest Property: 11025' ~ 4b. Location of Well (State Base Plane Coordinates): Surface: x-590724 y-5970138 Zone-ASP4 10. KB Elevation Planned (Height above GL): 28.5 feet 15. Distance to Nearest Well Within Pool: 1190' 16. Deviated Wells: Kickoff Depth: 300, feet Maximum Hole An Ie: 54 , de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 2224 - Surface: 1727 1 a in Pr ram: cficatio n T 'n" h - Bo tt m u t' of Cem M c.f. or cks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 42" 20" 215.5# A-53 WLD 108' Surface Surface 108' 108' 260 sx Arcti Set A rox. 12-1 /4" 9-5/8" 40# L-80 BTC 3730' Surface Surface 3730' 2822' 570 sx Arctic Set Lit 411 sx Class 'G' _ /4~~ 7~~ 26# L_g TC-II /BTC-M 7273' Surface Surta 727 ' 4 73' 54 LiteCret 28 x las 'G' 1'9. PRESE NT WELL CONDITION SUMMARY (To be completed fof Redrilf-and Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): Casing Length - ize ement Volume MD D Conductor /Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments ®Filing Fee, $100 ^ BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ® Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Mark Staudinger, 564-4337 Printed Name Robert Tirpack Title Senior Drilling Engineer Prepared By Name/Number: Si nature ~~~~' `~; Phone ~~ e/~%/,?~ Date ~ ~/ (.~~ Sondra Stewman, 564-4750 ' Commission Use Onl Permit To Drill Number: o?O O O API Number: 50-oa9-®R~,~SO0000 Permit Approval Da e: See cover letter for other r uirements Conditions of Approval If box is checked, well may not be used to explore for, test, or produce coalbed me~~th~~ane, gas hydrates, or gas contained shales: ,® \'~~ ~o~Ccs~~LXa~\~`~. Samples Req'd: ^ Yes U~No d Log Req'd: ,^~/Yes Lt7 No ~ ` H S Measures: Il7~' Yes o Survey Req'd: L10 Yes ^ No ~ ~``'na.C~~Q O~XcC'~.2TtC5rSf~C3 L~~~ ~J~\lO~-lo ~ l , Other: 4KYJd~S~ ~~ ~s~- .~O~W`<.'aS.03~`L~`3~vxw~ ` hS ~ ~v <<c ~L `~~CJ PPRO BY THE COMMISSION Date ,.. 1,,,~,~ ,COMMISSIONER Form 10-401 Revised 12/2005 ~ ~I Q ~~t ~..`~tY/ 1~ MAa 1 6 2007 20 AAC 25.005 ~ Alaska Oil & Gas Cons. C ~ • p Submit In Duplicate • • Well Name: V-218i Drill and Complete Plan Summary T e of Well service / roducer / in'ector : Injector Tar et X Y Z TVDss Townshi Ran a Section FSL FEL Surface Location 590724 5970138 53.5 11 N 11 E 11 4888 1576 T t1: To OA 595045 5970285 4455 11 N 11 E 12 4982 2533 T t2: 250' below OBe 595550 5970229 4891 11 N 11 E 12 4920 2029 AFE Number: API Number: 50-029-xxxxx Estimated Start Date: March 26, 2007 O eratin da s: 14 Ri Nabors 9ES TMD 7,273' TVD rkb: 4,973' RKB/GL 28.5'/53.5' RTE 82.0' Well Design: USH Grassroots Schrader Bluff Injector 3-'/z", L-80, TC-II, multi acker, zonal in'ection, and zonal monitorin com letion Current Status: New drill General Well Information: Estimated BHP: 2145 psi (8.6 pp EMW) at 4973' TVD Estimated BHT: 105 de Fat 4973' TVD Formation Markers: Est. Formation Tops Est. Formation Tops Uncertainty Commercial Hydrocarbon Bearing Est. pore press. Est. Pore Press. Formation MD (TVDss) (feet) (Yes/No) (Psi) EMW G1 322 -240 +/-50' No 108 8.7 SV6 994 -900 +/-50' No 405 8.7 SV5 1794 -1580 +/-50' No 711 8.7 Base Permafrost 1971 -1700 +/-50' No 765 8.7 SV4 1994 -1715 +/-50' Gash drates 772 8.7 Fault 1 (V-Pad Fault 2368 -1940 +/- 100' M.D. SV3 2539 -2040 +/-50' Gas h drates 918 8.7 SV2 2802 -2195 +/-50' Gas h drates 988 8.7 SV1 3381 -2535 +/-50' Gash drates 1139 8.7 UG4 3866 -2820 +/-50' Thin Coal 1269 8.7 UG4A 3926 -2855 +/-50' Heav Oil 2855'-3080' SS .1285 8.7 UG3 4590 -3245 +/-50' Thin Coals 1456 8.7 UG1 5508 -3785 +/-50' Hea Oil 3900'-3980' SS 1703 8.7 UG Ma 5941 -4045 +/- 30' No wet 1820 n/a V-218i Permit to Drill Page 1 • • UG_Mbi 6040 -4105 +/- 30' No wet 1845. n/a UG_Mb2 6129 -4160 +/- 30' No wet 1872 8.7 UG_Mc 6259 -4240 +/- 30' No wet 1906 8.7 SB_Na 6348 -4295 +/- 30' No 1931 8.7 SB_Nb 6388 -4320 +/- 30' No 1950 8.7 SB_Nc 6436 -4350 +/- 30' No, ti ht 1955 8.7 SB_Ne 6450 -4359 +/- 30' No, ti ht 1959 8.7 SB_OA 6604 -4455 +/- 30' Yes 1870- 1940 8.1-8.4 6706 1930- SB_OBa -4520 +/- 30' Yes 2000 8.2-8.5 6761 1950- SB_OBb -4555 +/- 30' No -wet 2020 8.2-8.5 6855 ' 20 l o- SB_OBc -4615 +/- 30 Yes 2070 8.4-8.5 6932 ' 1970- SB_OBd -4665 +/- 30 No -wet 2040 8.1-8.4 SB_OBe 7023 -4725 +/- 30' No 2103 8.6 SB_OBf 7092 -4770 +/- 30' No 2123 8.6 Base _SB_OBf 7166 -4820 +/- 30' No 2145 8.6 T.D. in Colville Shale 7273 -4891 No 8.6 Wells within a'/a mile of this injection well, scanned from the top of the reservoir to TD Well Name Distance ft Annulus Inte rit Comments V-205L1 1270' Offset Producer. Distance to OBa lateral. V-205L2 1190' Offset Producer. Distance to OA lateral Both of the wellbores that are within a'/a mile of V-218 are the 2 laterals for V-205, which is the offset producer of this injection well. CasinglTubing Program: Hole Size Csg/ Tbg O.D. Wt/Ft Grade Connection Length (ft) Top MD/TVD RTE ft Btm MD/TVD RTE ft 42" Insulated 20" 215.5 A-53 WLD 108 GL 108/108 12-~/a" 9-5/8" 40 L-80 BTC 3730 GL 3730/2822 8-3/a" 7" 26 L-80 TC-II 5230 GL 5230/3703 8-3/a" 7" 26 L-80 BTC-M 7273 5230/3703 7273/4973 Tubin 3-ih" 9.2 L-80 TC-II 6911 GL 6911/4734 Directional: Directional Plan: Schlumber er Feasibilit Stud P5b Ref Elev: 82.0' MD KOP: 300' MD, be in 1.5/100 build Close A roach Wells: All Wells ass Ma'or Risk Scan, reference anti-collision re ort Surve Pro ram: GYD-GC-SS 1000' , MWD + IFR + MS 7273' Maximum Hole An le: 54.0 de rees tan ent section Distance to Nearest Pro ert Line: 11025' from PBU bounda Distance to Nearest Well in Pool: 1190' from V-205L2 V-2181 Permit to Drill Page 2 • • Mud Program: 12-~/a" Surface Hole Mud Pro erties Spud -Freshwater Mud Interval Densit PV YP PH Funn Vis FL 0-1971' BPRF 8.8-9.2 30-55 50 - 70 9.0 - 9.5 300-400 NC - 8 1971'-3730' SV1 9.2-9.5 30-55 45 - 60 9.0 - 9.5 250-300 < 8.0 8-3/a" Intermediate Hole Mud Pro erties Freshwater Mud (LSND) Interval Densit PV YP PH API Filtrate MBT 3730'-7273' OBf Base 8.8-9.3 8-14 18-24 9.0-9.5 4 - 7 < 15 Survev and Loaaina Program: 12-~/a" Hole Section: Surface Gyro until MWD surveys are clean. MWD /LWD: Dir/GR O en Hole: None Cased hole: None 8-3/a" Hole Section: Sample as required by well site Geologist MWD /LWD: GR/RES/Azi-Dens/Neu/PWD real time and recorded O en Hole: None Cased Hole: USIT in primary depth control mode Cement Calculations: Casin Size Surface Casing - 9 s/8" 40 Ib/ft L-80 BTC -Single Stage Basis Lead: Open hole volume + 250% excess in permafrost and 40% excess below permafrost. TOC at surface Tail: O en hole volume + 40% excess + 80' shoe track. TOC 1000' MD above shoe 2730' MD . Fluid Sequence and Tam Port collar may be located at 1,000' as a contingency for cement to surface if Volume: conditions warrant Wash None S acer 50 bbls of MudPush II wei hted to 10.3 Lead 450 bbls 570 sks 10.7 Ib/ al Arctic Set Lite cement - 4.49 cuft/sk Tail 85 bbls (411 sks) 15.8 Ib/gal Class G + Durastone - 1.16 cuft/sk Temp I BHST = 55° F from SOR In the event that cement is not circulated to surface during the initial surface casing cement job, notify the AOGCC of the upcoming remedial cement work for possible witness of cement to surface. Casin Size Intermediate Casing - 7" 26 Ib/ft L-80 BTC-M x TC-II -Single Stage Basis Lead: Open hole volume + 30%. TOC 1000' below surface shoe. Tail: O en hole volume + 30% excess + 80' shoe track. TOC 500' above Ma 5400' MD . Fluid Sequence and This cement job is planned for one stage using two slurries. Volume: Wash 40 bbl of CW100 wash wei hted to 8.33-Ib/ al S acer 40 bbl of MUDPUSH XL S acer wei hted to 10.5-Ib/ al Lead 24 bbl 54 sks 12.0 LiteCRETE Lead - 2.46 cuft/sk Tail 69 bbl (328 sks) 15.8 ooa Class G cement + Latex - 1.17 cuft/sk Temp I BHST- 105° F from SOR V-218i Permit to Drill Page 3 • • Centralizer Recommendations: 9-5/8" Casing Centralizer Placement: a) Run (25) 9 5/8" Bow-spring centralizers attached over the collar of each joint of casing from the casing shoe up to 1,000' MD above the shoe. b) Run 2Bow-spring centralizers on either side of the TAM Port Collar (if run). c) This centralizer program is subject to change due to actual hole conditions. 7" Casing Centralizer Placement: a) Run two floating straight blade centralizers and a stop ring centered on every joint of casing from TD to 500' over the Ma sands. b) Above the Ma, run one centralizer per joint, floating across the entire joint up to 1000' below the surface casing shoe. Surface and Anti-Collision Issues: • Surface Shut-in Wells: The closest existing surface wells are V-03 (15' away), V-111 (15'), V-120 (30'), and V216i (30'). • Close Approach Shut-in Wells: All wells have passed the major risk scan. No wells will require subsurface shut-in during drilling operations. Reference the Anti-collision report in the directional plan for a full list of offset well paths. V-2181 Permit to Drill Page 4 • Well Control Surface hole will be drilled with a diverter. The production hole section will be drilled with well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer. This equipment is capable of handling maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 4,000 psi. Anticipated surface pressures will not exceed 3,OOOpsi, therefore it will not be necessary to have two sets of pipe rams installed at all times. BOP regular test frequency will be 4 days, with a function test every 7 days. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Surface Section • BOPE: • Maximum anticipated BHP: • Maximum surface pressure • Planned BOP test pressure • 9-5/8" Casing Test: • Kick Tolerance: Intermediate Section Kick Toler • BOPE: • Maximum anticipated BHP: • Maximum surface pressure: • Planned BOP test pressure: • 7" Casing Test: • ~ Integrity Test - 8-314" hole: • Kick Tolerance: • Planned completion fluid: Variance Request • To avoid the risk of plugging the flow line with large rocks and wood encountered while drilling surface hole, it is requested to drill without a flow paddle for the first portion of the surface hole. After drilling past the larger rocks and wood sections, the flow paddle will be put back in the flow line. • To mitigate any risk involved with no flow paddle, the following steps will be taken while the flow paddle is removed from the flow line. Ensure PVT alarms are used and the pit levels are accurately monitored for any pit gain. Visually look down the riser during connections to ensure the well is not flowing. Disposal • No annular disposal in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for disposal. Haul all Class I wastes to Pad 3 for disposal. Hydril GK, 21-1/4", 2000 psi 1184 psi - SV1 (8.7 ppg EMW @ 2617' TVD) 922 psi -Based on a full column of gas @ 0.10 psi/ft Function Test 3,500 psi surface pressure test NA once and Integrity Testing Hydril, 13-5/8", 5000 psi 2224 psi - OBf Base (8.6 ppg EMW @ 4973' TVD) 1727 psi -Based on a full column of gas @ 0.10 psi/ft 4,000 psi/250 psi Rams and 2,500 psi/250 psi Annular 4,000 psi surface pressure test LOT 20' - 50' from 9-5/8' shoe 51.0 bbl KT with a 9.0 ppg mud and a 10.8 ppg LOT Estimated 9.0 ppg Brine / 6.8 ppg Diesel V-2181 Permit to Drill Page 5 r Well Control • Surface hole will be drilled with a diverter. The production hole section will be drilled with well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer. This equipment is capable of handling maximum potential surface pressures. Based upon calculations below, BOP equipment will be tes d to .4,000 psi. Anticipated surface pressures will not exceed 3,OOOpsi, therefore it will not be necessary to ve two sets of pipe rams installed at all times. BOP regular to frequency will be 14 days, with a function test every 7 days. Diverter, BOPE an drilling fluid system schematics on file with the AOGCC. Surface Section • BOPE: Hydril GK, 21-1/4", 2000 psi • Maximum anticipate HP: 1184 psi - SVi (8.7 ppg EMW C«3 2617' TVD) • Maximum surface pres ure: 922 psi -Based on a full column of gas C~ 0.10 psi/ft • Planned BOP test press e: Function Test • 9-5/8" Casing Test: 3,500 psi surface pressure test • Kick Tolerance: NA Intermediate Section Kick Toler • BOPE: • Maximum anticipated BHP: • Maximum surface pressure: • Planned BOP test pressure: • 7" Casing Test: • Integrity Test - 8-3/4" hole: • Kick Tolerance: • Planned completion fluid: nd Integrity Testing ydril, 13-5/8", 5000 psi 2 4 psi - OBf Base (8.6 ppg EMW C«~ 4973' TVD) 172 si -Based on a full column of gas @ 0.10 psi/ft 4,000 si/250 psi Rams and 2,500 psi/250 psi Annular 4,000 p 'surface pressure test LOT 20' - 0' from 9 $/a" shoe 51.0 bbl KT ith a 9.0 ppg mud and a 10.8 ppg LOT Estimated 9.0 g Brine / 6.8 ppg Dies 5 ~~~( ~j~~ Variance Reque • To avoid the risk of plugging the flow line with large rocks and wo encountered while drilling surface hole, it is requested to drill without a flow paddle for the first portion of the urface hole. After drilling past the larger rocks and wood sections, the flow paddle will be put back in th low line. Disposal .~ • No annular disposal in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grin nd inject at DS-04. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to S-04 for disposal. Haul all Class I wastes to Pad 3 for disposal. V-2181 Permit to Drill Page 5 • Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE I. Well Control /Reservoir Pressures: The Schrader Bluff sands are expected to be pressured at 8.1-8.7 ppg EMW. II. Hydrates and Shallow gas: ~ Gas hydrates and/or free gas may be present on V-pad in the SV5 through SV1 surface hole interval below base the base of Permafrost. Recommended practices and precautions for drilling hydrates should be followed in the surface hole. Setting the surface casing below the deepest SV1 sand hydrate zone will isolate gas bearing intervals behind cemented pipe in the surface hole. III. Lost Circulation /Breathing: Lost circulation is considered low at the faults in the surface hole section. Seepage losses could occur in the Schrader O-sands./ IV. Kick Tolerance /Integrity Testing: Production Section Kick Tolerance and Integrity Testing • Integrity Test - 8-3/4" hole: LOT 20' - 50' from 9 5/s" shoe • Kick Tolerance: 51.0 bbl KT w/ 9.0 ppg mud, a 10.8 ppg LOT, and 8.6 ppg pore pressure. v. Stuck Pipe There could be slight differential sticking across the open hole while running the 7" casing. Keep the casing moving as much as possible and follow the centralizer program to help with standoff. VI. Hydrogen Sulfide ,~ V Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. H2S levels across the pad are typically in the '~ 10 ppm range based on the latest samples taken. V-03 has read 20 ppm and V-111 30 ppm. VII. Faults There is a low risk of losses incurred when crossing the fault in the 12-1/4" hole section. Formation Where Encounter Fault MD Intersect TVDSS Intersect Est. Throw Throw Direction Uncertaint Fault 1 V-Pad Fault 2368 -1940 -115' Southwest +/- 100' MD CONSULT THE V PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION V-2181 Permit to Drill Page 6 r V-218i Operations Summary Pre-Rig Work: 1. Weld an FMC landing ring for the FMC Gen 5 Wellhead on the 20" conductor. 2. Prepare pad and neighboring wells for the rig move and sim-ops production. Shut in nearby wells, bleed off process lines, and remove well houses as necessary. Rig Operations: 1. MIRU Nabors 9ES. Nipple up diverter spool and function test diverter. PU 4" DP as required and stand back in derrick. 2. MU 12-'/a" drilling assembly with MWD/GR and directionally drill surface hole to TD with one BHA. Conduct a short trip at the BPRF. The actual surface hole TD will be 200' TVD below the top of the SVi sands. CBU, short trip, RIH to TD, CBU, then POOH and lay down BHA. 3. Run and cement the 9-g/e", 40.0 Ib/ft. surface casing back to surface. A TAM Port Collar may be run at 1000' MD as a contingency if hole conditions dictate. Use Durastone in the last 15 bbls of tail cement. 4. ND diverter spool and NU and test casing/tubing head. NU BOPE and test to 4000 psi / 2500 psi annular. PU 4" DP as needed. 5. MU 8-3/a" drilling assembly with MWD/GR/Res/Azi-Den/Neu/PWD and RIH to float collar. Confirm 1,000 psi cement compressive strength prior to testing casing. Test the 9 6/e" casing to 3,500 psi for 30 minutes. 6. Drill shoe track and displace over to new 8.8 ppg LSND mud. Drill new formation to 20' below 9-s/8" shoe and perform LOT. 7. Drill ahead to Production hole Target TD (250' MD below OBe). Circulate BU, then POOH to run casing. 8. Run and cement the 7", 26#, L-80, BTC-M x TC-fl production casing. Displace the casing with seawater during cementing operations. Pressure test casing to 4,000 psi for 30 minutes at plug bump. Confirm 500 psi cement compressive strength prior to freeze protecting. Freeze protect the 7"x9 5/8" annulus out of critical path. 9. PU DPC guns and RIH w/ 140' of 4.5" Power Jet 4505 5 spt, pert guns with Schlumberger LWD GR/CCL for gun correlation. 10. Space out perf guns by tagging PBTD and utilizing GR/CCL and RA tags in 7" casing. Once correlated correctly, circulate over to 9.0 ppg brine. Confirm cement compressive strength is at least 1,000 psi before firing. Perforate OA, OBa, OBb, and OBd. POOH LD DP and guns. 11. RU Schlumberger E-line. RIH with gauge ring and junk basket to recover any pert debris. Repeat until clean to at least 50' below the bottom perforation. 12. Run USIT log following Primary Depth Control procedures as USIT log will be primary depth control for future well work. Log from PBTD up to surface. 13. Run the 3-'h", 9.2#, L-80, TCII completion with a 7" x 3-'/z" straddle packer assembly, I-wire, gauges, and injection mandrels. Torque turn TC-II threaded tubing. Before landing tubing, log onto depth using RA marker in tubing and SLB e-line GR/CCL. 14. Run in the lockdown screws and set the packers. Give AOGCC 24 hours notice, then test the production casing/tubing annulus and. tubing to 4,000 psi each. Shear the DCR shear valve and pump both ways to confirm circulation ability. 15. Install and test FMC TWC. Nipple down the BOPE. Nipple up & test the dual master valve tree to 5,000 psi. 16. Freeze protect the well to 2,500' TVD by first pumping corrosion inhibited brine down the IA with rig pumps followed by diesel down IA w/ a hot oil truck, taking clean brine returns to surface. Allow diesel to u-tube into tubing. 17. Install BPV in tubing hanger. Install a VR plug in the 7"x 3-'/2" annulus valve and secure the well. Assure that IA/OA are protected with two barriers. 18. Rig down and move off. Post-Rig Work: 1. R/U Slick-line and pull ball and rod / RHC from the tailpipe. 2. Replace the DCR shear valve with a dummy GLV. 3. Pull dummy valves in injection mandrels and replace with injection valves. 4. Pull VR plug. 5. Install well house, Leo Surface Safety Valve on tree, and flow lines. V-218i Permit to Drill Page 7 TREE- 4idi&" V~J'F~L HEA f3 = FMC _~~ ACTUATOR= Leo Kf3. ELEV = BF. ELE1l = KUP = 28.5' ~~ ~~ ~xxx' 300'. Max Angle = xx° ~ xxxx' Datum MD = _xxxx' Da1vmTVL1= xxxx' SS (-~T1=5: GLM'S ~ STA 1~1-S Aim -112"' X 1-112" MMGW W~t~l Ate .. WAT13~R.€K?Q MAIVDI~S. ~'~~~ 1 1 2$pp' 3-112" H)=5 X NIP, ID = ?.813" LVATERELOODIGASLIFT MANDRELS 9-'S!~" CSG, 4tt#, L-BtI, ~ = 8.835" 373i~' - XG? from BTGAA to TGII $~30' 1-V1~re run from surface xxxX ~,~~,...,,~...,.___. _..__,.,.,.,,,.,.m„_...,..,~,,..,.._., Minimum ID = 2813•' .~,..~... 3-112" HES X NIPPLE 7" hAARK~2 JOMd"1 wl RA TAG Top Ma cTS gauge ICkxx ,,,,,-- 661}0' 3-112" TE3Ca iiV! RA Tag ~ Centralizer Top QA MARKERJO~1'f W! RA TAG ~-~ Above i3bd PEREORA"f~?N sLIIti~MAARY REF LCiG: A N~GLE AT TOP PERF, Nate: S1ZE SPF INTERVAL Opn/Sqz L1ATE 4.5" 5 oA - ao' U 4.5" 5 OBa - 3f1' C7 4.S" 5 OSb - 2fl O 3-iYL" TBG, 9.2#, L-Bfl, .flU87 bpf, Id = 2.992" H 5911' 7" CSG, 26#, L-8i1, iL? ~ &.276°~ 7273' ST tv1D TV D DEV TYPE V LV LATCH PORT pATE 6 650fi 51 MMG OCR-1 RKP 1.5" 5 6611 51 MMG-W DUM RK i ~" 4 6f'i40 5i M1t~tAG-W DUM RK 1.5" 3 67~A'7 S0 MMG-W DUM RK i.5" 2 6775 ' S0 MMGW DUM RK i.5" 1 685i 5t1 tuWlG-W DUM RK 1:5" 6585' H 3-,rz" tags x ~v~, I© 7° X 3=112' IiES AHR Packer. ~ r 2.$21" 5669' (~ 7" X S i l2" HF~ A HR Packer, ID 6683" CTS gauge ~ = xx" 6726' 3-112" HES X NIP, ~ = 2.8i 3" 68(15" ],W,} 7"X3-ii2" tiES AHR Packer„ ~ = 2.92i' 6830 3-i 12" HES X N~', ~ = 2.81 68$-- .(1' ~ 3-112" t~S X N~', ID = 2.813" w/RHC-m plcrg 68111' H 3-112" HES X ', ~ = 2.Bi 3" 6$11' ]-~ 3-112" 1tUlEG, tD = 3.U0" C3RICIN UNCC V1L: V-2i8i PERMFI' No: A Pi No: Sec Tw P Rge ~'Exptaration ~Aiaska) }~ .~~,~ ~s 2 ~2,~~yn Schlumberger V-218 (P5b) Proaosal Report Date: February 19, 2007 Client: BP Exploration Alaska Field: Prudhoe Bay Unit - WOA Structure l Slot: V-Pad I Plan V-218 (N-V) ® ® 0 ~('1~i Well: Plan V-218 (N-V)V Borehole: Plan V-218 UWIIAPI#: 50029 Survey Name 1 Date: V-218 (P5b) I February 16, 2007 Tort 1 AHD 1 DDI I ERD ratio: 70.191 ° 14878.12 ft / 5.700 / 0.981 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location LaUlong: N 70.32814847, W 149.26421454 location Grid NIE YIX: N 5970138.470 ftUS, E 590723.980 ftUS Grid Convergence Angle: +0.69284644° Vertical Section Azimuth: 89.620° n ~f Vertical Secgon Origin: N 0.000 ft, E 0.000 ft ~j TVD Reference Datum: Rotary Table TVD Reference Elevation: 82.00 ft relative to MSL Sea Bed 1 Ground Level Elevation: 53.50 ft relative to MSL Magnetic Declination: 23.708° Total Field Strength: 57635.814 nT Magnetic Dip: 80.895° Declination Date: April 16, 2007 Magnetic Declination Model: BGGM 2006 North Reference: True North Total Corr Mag North •> True North: +23.708° Local Coordinates Referenced To: Well Head • Comments Measured Inclination Azimuth SulrSea TVD TVD Vertical NS ~ Gravity DLS Build Rate Walk Rate Northing Easting Latitude Longitude Depth Section Tool Face ft de de ft ft ft ft ft de de 1100 ft de 1100 ft de 1100 ft ftUS ftUS tilt U. UV U.UU IU. UU -OL.UU U.UU U.UU U.UU U.UU --- V.UV U.UV U.UV .7`J/U IJ8.4/ .7yU/LJ. 70 IV /U .JL01404/ VV 14.7.L04L 14.74 KOP Crv 1.5/100 300. 00 0.00 10. 00 218.00 300.00 0.00 0.00 0.00 HS 0.00 0.00 0.00 5970138. 47 590723. 98 N 70 .32814847 W 149.26421454 G1 322. 00 0.33 10. 00 240.00 322.00 0.01 0.06 0.01 HS 1.50 1.50 0.00 5970138. 53 590723. 99 N 70. 32814864 W 149.26421445 Crv 3.5/100 400. 00 1.50 10 .00 317.99 399.99 0.24 1.29 0.23 17.57R 1.50 1.50 0.00 5970139. 76 590724 .19 N 70 .32815199 W 149.26421269 500. 00 4.95 22. 33 417.82 499.82 2.14 6.57 2.09 5.26R 3.50 3.45 12.33 5970145. 07 590726. 00 N 70 .32816642 W 149.26419755 600. 00 8.44 24. 52 517.12 599.12 6.90 17.24 6.78 3.09R 3.50 3.49 2.18 5970155. 79 590730. 55 N 70 .32819558 W 149.26415954 Crv 3.5/100 644. 57 10.00 25 .00 561.11 643.11 9.93 23.73 9.77 70.45R 3.50 3.50 1.09 5970162. 31 590733 .47 N 70 .32821329 W 149.26413527 700. 00 10.80 34 .80 615.63 697.63 14.99 32.36 14.77 60.81 R 3.50 1.45 17.68 5970171. 00 590738 .36 N 70 .32823686 W 149.26409473 800. 00 12.87 48 .64 713.52 795.52 28.80 47.42 28.49 47.26R 3.50 2.07 13.84 5970186. 23 590751 .89 N 70 .32827801 W 149.26398352 900. 00 15.46 58 .32 810.49 892.49 48.61 61.78 48.20 37.87R 3.50 2.59 9.68 5970200. 83 590771 .42 N 70 .32831726 W 149.26382368 SV6 993. 51 18.15 64. 78 900.00 982.00 72.48 74.54 71.99 31.68R 3.50 2.88 6.91 5970213. 87 590795. 06 N 70. 32835210 W 149.26 4 1000. 00 18.35 65 .16 906.16 988.16 74.33 75.40 73.83 31.32R 3.50 2.98 5.84 5970214. 75 590796 .89 N 70 .32835445 W 149.26 1100. 00 21.41 70 .15 1000.20 1082.20 105.88 88.21 105.29 26.63R 3.50 3.06 4.99 5970227. 94 590828 .19 N 70 .32838945 W 149.263' 69 1200. 00 24.59 73 .92 1092.25 1174.25 143.12 100.18 142.46 23.16R 3.50 3.18 3.77 5970240. 35 590865 .21 N 70 .32842214 W 149.26305926 1300. 00 27.84 76 .87 1181.95 1263.95 185.94 111.25 185.20 20.51 R 3.50 3.25 2.95 5970251. 94 590907 .81 N 70 .32845238 W 149.26271266 1400. 00 31.14 79 .24 1268.99 1350.99 234.16 121.38 233.36 18.45R 3.50 3.30 2.37 5970262. 66 590955 .83 N 70 .32848007 W 149.26232218 1500. 00 34.47 81 .19 1353.03 1435.03 287.60 130.55 286.74 16.80R 3.50 3.34 1.96 5970272. 46 591009 .10 N 70. 32850510 W 149.26188926 1600. 00 37.84 82 .84 1433.76 1515.76 346.07 138.71 345.16 15.47R 3.50 3.36 1.65 5970281. 33 591067 .41 N 70 .32852738 W 149.26141553 1700. 00 41.22 84 .26 1510.89 1592.89 409.35 145.83 408.39 14.38R 3.50 3.38 1.42 5970289. 21 591130 .54 N 70 .32854682 W 149.26090276 SV5 1794. 23 44.42 85. 43 1580.00 1662.00 473.17 151.56 472.17 13.52R 3.50 3.40 1.24 5970295. 72 591194. 24 N 70. 32856248 W 149.26038554 1800. 00 44.62 85 .50 1584.11 1666.11 477.20 151.88 476.20 13.47R 3.50 3.40 1.17 5970296. 08 591198 .27 N 70 .32856335 W 149.26035285 1900. 00 48.02 86 .59 1653.17 1735.17 549.37 156.85 548.34 12.72R 3.50 3.41 1.10 5970301. 93 591270 .33 N 70 .32857692 W 149.25976786 End Crv 1940. 25 49.40 87 .00 1679.73 1761.73 579.58 158.54 578.54 --- 3.50 3.42 1.01 5970303. 98 591300 .51 N 70 .32858153 W 149.25952296 WeIlDesign Ver SP 2.1 Bld(doc40x_100) Plan V-218 (N-V)\Plan V-218 (N-V)\Plan V-218\V-218 (P5b) Generated 2/19/2007 10:40 AM Page 1 of 3 Comments Measured Inclination Azimuth Sub•Sea ND ND Vertical NS ~ Gravity DLS Build Rate Walk Rate Northing Easting Latitude Longitude Depth Section Tool face ft de de ft ft ft ft ft de de 1100 ft de 1100 ft de 1100 ft ftUS ftUS ttaseNerm 7y/1. 41 4J.4U 2f/.UU 1/UU. VU 1/tlY.UU 6UJ.11 7bJ. /tf OUZ.7tl --- V.UU V.UU U.VU Oy/UJVO.DU O`J7JL4. 77 IV /U.JGt3AU4JU W 14J.LO`JJJ147 SV4 1994. 46 49.40 87.00 1715. 00 1797.00 620.69 160. 69 619.64 --- 0.00 0.00 0.00 5970306.63 591341. 57 N 70.32858740 W 149.25918968 Crv 3.5/100 2002 .14 49.40 87.00 1720 .00 1802.00 626.52 161 .00 625.46 29.56R 0.00 0.00 0.00 5970307.01 591347 .39 N 70.32858824 W 149.25914244 2100 .00 52.40 89.13 1781 .72 1863.72 702.42 163 .53 701.35 28.22R 3.50 3.06 2.18 5970310.46 591423 .23 N 70.32859514 W 149.25852707 End Crv 2152 .30 54.02 90.20 1813 .04 1895.04 744.30 163 .77 743.23 --- 3.50 3.09 2.04 5970311.20 591465 .11 N 70.32859578 W 149.25818742 Fault Crossing 2368. 39 54.02 90.20 1940. 00 2022.00 919.15 163. 16 918.09 --- 0.00 0.00 0.00 5970312.70 591639. 94 N 70.32859405 W 149.25676947 SV3 2538. 59 54.02 90.20 2040. 00 2122.00 1056.87 162. 67 1055.81 --- 0.00 0.00 0.00 5970313.88 591777. 65 N 70.32859267 W 149.25565262 SV2 2802. 40 54.02 90.20 2195. 00 2277.00 1270.33 161. 92 1269.28 --- 0.00 0.00 0.00 5970315.71 591991. 10 N 70.32859053 W 149.25392149 SV1 3381. 09 54.02 90.20 2535. 00 2617.00 1738.57 160. 28 1737.55 --- 0.00 0.00 0.00 5970319.73 592459. 30 N 70.32858578 W 149.25012419 9-5/8" Csg Pt 3730. 00 54.02 90.20 2740. 00 2822.00 2020.90 159. 28 2019.88 --- 0.00 0.00 0.00 5970322.15 592741. 60 N 70.32858287 W 149.24 UG4 3866. 16 54.02 90.20 2820. 00 2902.00 2131.07 158. 89 2130.06 --- 0.00 0.00 0.00 5970323.09 592851. 77 7 N 70.32858173 W 149.24 UG4A 3925. 73 54.02 90.20 2855. 00 2937.00 2179.27 158. 73 2178.27 --- 0.00 0.00 0.00 5970323.51 592899. 97 N 70.32858123 W 149.246 UG3 4589. 51 54.02 90.20 3245. 00 3327.00 2716.37 156. 84 2715.39 --- 0.00 0.00 0.00 5970328.11 593437. 03 N 70.32857559 W 149.24219454 Drp 0.5/100 5368. 12 54.02 90.20 3702 .46 3784.46 3346.39 154 .62 3345.44 121.26R 0.00 0.00 0.00 5970333.51 594066 .99 N 70.32856884 W 149.23708534 5400. 00 53.93 90.37 3721 .21 3803.21 3372.17 154 .49 3371.22 121.16R 0.50 -0.26 0.53 5970333.70 594092 .77 N 70.32856846 W 149.23687625 5500. 00 53.68 90.90 3780 .27 3862.27 3452.86 153 .60 3451.92 120.85R 0.50 -0.26 0.53 5970333.78 594173 .47 N 70.32856591 W 149.23622186 5600. 00 53.42 91.44 3839 .68 3921.68 3533.27 151 .96 3532.33 120.53R 0.50 -0.26 0.53 5970333.11 594253 .89 N 70.32856133 W 149.23556972 5700. 00 53.17 91.97 3899 .45 3981.45 3613.38 149 .57 3612.47 120.21 R 0.50 -0.25 0.54 5970331.70 594334 .04 N 70.32855472 W 149.23491988 5800. 00 52.92 92.52 3959 .57 4041.57 3693.21 146 .44 3692.32 119.88R 0.50 -0.25 0.54 5970329.53 594413. 92 N 70.32854606 W 149.23427238 5900. 00 52.67 93.06 4020 .04 4102.04 3772.74 142 .57 3771.87 119.55R 0.50 -0.25 0.55 5970326.62 594493 .50 N 70.32853537 W 149.23362727 6000. 00 52.43 93.61 4080 .85 4162.85 3851.95 137 .95 3851.12 119.22R 0.50 -0.25 0.55 5970322.97 594572 .80 N 70.32852265 W 149.23298462 Mb1 6039. 57 52.33 93.83 4105. 00 4187.00 3883.21 135. 92 3882.40 119.09R 0.50 -0.24 0.55 5970321.31 594604. 09 N 70.32851705 W 149.23273102 6100. 00 52.18 94.16 4141 .99 4223.99 3930.86 132 .59 3930.07 118.88R 0.50 -0.24 0.55 5970318.56 594651 .79 N 70.32850789 W 149.23234446 Mb2 6129. 35 52.11 94.32 4160. 00 4242.00 3953.96 130. 88 3953.18 118.78R 0.50 -0.24 0.55 5970317.12 594674. 92 N 70.32850317 W 149.23215708 6200. 00 51.94 94.72 4203 .47 4285.47 4009.45 126 .49 4008.70 118.54R 0.50 -0.24 0.56 5970313.41 594730 .49 N 70.32849110 W 149.23170684 Mc 6259. 16 51.80 95.05 4240. 00 4322.00 4055.79 122. 53 4055.07 118.34R 0.50 -0.24 0.56 5970310.01 594776. 90 N 70.32848021 W 149.23133084 6300 .00 51.71 95.28 4265 .28 4347.28 4087.72 119 .64 4087.01 118.19R 0.50 -0.24 0.56 5970307.51 594808 .87 N 70.32847228 W 149.23107182 Na 6347. 90 51.59 95.55 4295. 00 4377.00 4125.08 116. 10 4124.41 118.03R 0.50 -0.24 0.56 5970304.42 594846. 30 N 70.32846254 W 149.23076860 Nb 6388. 10 51.50 95.77 4320. 00 4402.00 4156.39 112. 99 4155.73 117.89R 0.50 -0.23 0.56 5970301.69 594877. 66 N 70.32845401 W 149.23 6400. 00 51.47 95.84 4327 .41 4409.41 4165.65 112 .05 4165.00 117.84R 0.50 -0.23 0.56 5970300.86 594886 .93 N 70.32845142 W 149.23 4 Nc 6436. 23 51.39 96.05 4350. 00 4432.00 4193.80 109. 12 4193.17 117.72R 0.50 -0.23 0.57 5970298.27 594915. 13 N 70.32844337 W 149.23021101 Ne 6450. 64 51.35 96.13 4359. 00 4441.00 4204.99 107. 92 4204.37 117.66R 0.50 -0.23 0.57 5970297.21 594926. 35 N 70.32844009 W 149.23012020 6500. 00 51.24 96.41 4389 .86 4471.86 4243.25 103 .72 4242.65 117.49R 0.50 -0.23 0.57 5970293.47 594964 .68 N 70.32842854 W 149.22980974 6600 .00 51.01 96.98 4452 .63 4534.63 4320.51 94 .65 4319.97 117.13R 0.50 -0.23 0.57 5970285.33 595042 .09 N 70.32840364 W 149.22918279 V-218 Tgt OA 6603 .77 51.00 97.00 4455 .00 4537.00 4323.41 94 .29 4322.88 LS 0.50 -0.23 0.57 5970285.01 595045 .00 N 70.32840266 W 149.22915922 OA 6603. 78 51.00 97.00 4455. 01 4537.01 4323.42 94. 29 4322.89 LS 0.50 -0.50 0.00 5970285.01 595045. 02 N 70.32840265 W 149.22915912 6700 .00 50.52 97.00 4515 .87 4597.87 4397.32 85 .21 4396.86 LS 0.50 -0.50 0.00 5970276.83 595119 .08 N 70.32837773 W 149.22855937 OBa 6706. 49 50.49 97.00 4520. 00 4602.00 4402.29 84. 60 4401.82 LS 0.50 -0.50 0.00 5970276.28 595124. 05 N 70.32837605 W 149.22851909 OBb 6761. 34 50.21 97.00 4555. 00 4637.00 4444.17 79. 45 4443.74 LS 0.50 -0.50 0.00 5970271.64 595166. 02 N 70.32836192 W 149.22817920 6800 .00 50.02 97.00 4579 .79 4661.79 4473.59 75 .83 4473.19 LS 0.50 -0.50 0.00 5970268.38 595195 .51 N 70.32835200 W 149.22794043 OBc 6854. 64 49.75 97.00 4615. 00 4697.00 4515.03 70. 74 4514.66 LS 0.50 -0.50 0.00 5970263.79 595237. 04 N 70.32833802 W 149.22760414 WeIlDesign Ver SP 2.1 Bld( docAOx_100) Plan V-218 (N-V)\Plan V-218 (N-V)\Plan V-218\V-218 (P5b) Generated 2/19/2007 10:40 AM Page 2 of 3 Comments Measured Inclination Azimuth Sub•Sea ND ND Vertical NS ~ Gravity DLS Build Rate Walk Rate Northing Easting latitude Longitude Depth Section Tool Face ft de de ft ft ft ft ft de de 1100 ft de 1100 ft de 1100 ft ftUS ftUS (i9UU.UU 4y.bL y/.UU 4(i44.3i5 4/Lti.3tS 454y.3U titi.b3 4b425.yb LJ U.DU -V.bU OBd 6931.71 49.36 97.00 4665.00 4747.00 4573.20 63.59 4572.87 LS 0.50 -0.50 7000.00 49.02 97.00 4709.63 4791.63 4624.45 57.30 4624.18 LS 0.50 -0.50 7023.41 48.90 97.00 4725.00 4807.00 4641.96 55.14 4641.70 LS 0.50 -0.50 OBe 7023.42 48.90 97.00 4725.01 4807.01 4641.97 55.14 4641.71 LS 0.50 -0.50 OBf 7091.63 48.56 97.00 4770.00 4852.00 4692.82 48.89 4692.60 LS 0.50 -0.50 7100.00 48.52 97.00 4775.54 4857.54 4699.04 48.13 4698.82 LS 0.50 -0.50 OBfBase 7166.90 48.18 97.00 4820.00 4902.00 4748.61 42.04 4748.44 LS 0.50 -0.50 7200.00 48.02 97.00 4842.10 4924.10 4773.04 39.04 4772.89 LS 0.50 -0.50 TD / 7" Csg 7273.41 47.65 97.00 4891.38 4973.38 4827.01 32.40 4826.90 --- 0.50 -0.50 U.UU 0`J/UZb`3.~Jii b`JbZ/1.325 N /U.SL25SLb4U VV l4`J.LZ/3LUUU 0.00 5970257.34 595295.33 N 70.32831840 W 149.22713210 0.00 5970251.67 595346.70 N 70.32830110 W 149.22671612 0.00 5970249.73 595364.24 N 70.32829519 W 149.22657402 0.00 5970249.73 595364.25 N 70.32829519 W 149.22657393 0.00 5970244.09 595415.21 N 70.32827804 W 149.22616133 0.00 5970243.41 595421.44 N 70.32827594 W 149.22611086 0.00 5970237.91 595471.12 N 70.32825921 W 149.22570852 0.00 5970235.21 595495.61 N 70.32825096 W 149.22551025 0.00 5970229.23 595549.69 N 70.32823275 W 149.225 • WeIlDesign Ver SP 2.1 Bld( doc4Ox_1OO) Plan V-218 (N-V)\Plan V-218 (N-V)\Plan V-218\V-218 (PSb) Generated 2/19!2007 10:40 AM Page 3 of 3 • ~ ~ i ale ~- Schlumberger _ _ ~~ WEL< V-218 (P5b) FlE`~ Prudhoe Bay Unit - WOA STRUCtURE V-Pad Mey~eBC Parameters Surface LecaBOn NAD2] AlasBa State Plates, Zme 04, US Feel Miscella neous Model: BGGM 200fi Dip: 80.895° Dale: April tfi, 200] Lal: N]01841.334 NoMBg 59)0138.4] ttUS Grq DOnV: ~0.6928aea4° SM: Pbn V-218IN-V) TVD Ref: Rotary Task (82.00 tt above MSL) Mag Dec: ~23.)OB° FS: 5]6358 nT Lon: W1491551.1)2 Fasting: 590]2]98 flUS Srale Fetl: 0.99990935 Plan'. V~218IP55) Srry Date: Febuary 19,2W/ 0 800 1600 O O DD 2400 C II N U 3200 4000 4800 5600 1600 2400 3200 4000 4800 0 000 RTE KOP Crv 7.SN DO 7 Crv 3.SN 00 Crv 3.51100 _..~.. VB .._.._.._.. _.. _.._..:-.._.._.._... End Crv I,...,:.._.,_.._.._.. .._...~rv 3:160.... . 5. ,a...-•End crv ........................ e....,..,......... :: a:: a::::: a: ~:,::::>z:::::::::a:::::::::.: a::.::::1>a:::::::::::.:: ~: ~:: ~::::::::::::::,:::::: ~:: ~:: x::::1::::a Crossing .._.._.._......_.._.._.._.._.._.._.._.. .._......_.._.._.._.._. ,._......_.._.._.._.._...i.._.._,....._.... ................................................................~..................................C .... .,..........,......,......,.......................................,........................,......;.... ._.. _.._.._.. _.. _.._ _ ._.._......_.._.. _......_ .._.. _.. _.. _.._.._.. _.._ _.. _.._ .3 ._.. _.. _. .._.._.._.._.._.._.._. _.._.. _.._.._.._.. _.._ _ Dro 0.51100 ........................... ~,..,....................... _...,. r,...................................?......................,........... ~....... ,cr.c,.:.,:.,:..:..- .:.,:..:..:.,c.,:.,c..:ii:ii:ii:i:::cE::::icci::i~ic[ici;c::~ _: ~:iciiwi~ii i:~:::;:~::cii::~i - '..:a..s:[``.:i: ._.._.._.._.._.._.._..~.._.._.._.._.._.._.._.._.:_.._.._.._.._.._.._.._.._:._.._.._.._.._.._.._.._..r._.._.._.._.._.,_.._.._..~.._.._.._.._ _.._.._.._..=.._ TD 17" Csg V-218 (PSb)i 0 800 1600 2400 3200 4000 4800 Vertical Section (ft) Azim = 89.62°, Scale = 1(in):800(ft) Origin = 0 N/-S, 0 E/-V 0 800 1600 2400 3200 4000 4800 5600 o O O O O ~ N ~ O CO O r ~ _~ ~w i~ a Q i+ m d s -a a` a N O W m8 O -~ O ~z ~ r2 ~ ~ O m~ O M ~~$ Fh O &~o O m$ O M ~`~s hum s z~ O z ~ ~ N Ez~ O 9 O 3 W HS9 O °N r OE O O O E ~ i E U N O C m F m F ~ ' °o a 0 ~. a a U ...........................:..................................:.... ..................... P ........:.................................. g.......................,...........j...,.................,... ...........................:..................................:.... ............ p4,...... c .................,..........,.. ...........:....................,......,.... .................. U I IL t V C ' W ..............................................................w... ................... ' e ......,............,.....................,..,.............,.................w.........,............. z. U; c ~ Z W ~ U C ~_ a °o N: ~: U: U d Y W f K O O O O O O O O O N t0 (O N «< N (31)009=N!) ~ . a~eog g »> BP Alaska Anticollision Report Company: BP Amoco Date: 2/19/2007 Time: 10:42:37 Page: I Field: Prudhoe Bay Reference Site: PB V Pad Co-ordinate(NE) Reference: Well: Plan V-218 (N-V), True North Reference Well: Plan V-218 (N-V) Vertical (TVD) Refere nce: V-218 Plan 82.0 Reference Wellpath: Plan V-218 Dh: OraCle I NO GLOBAL SCAN: Using user defined selection & scan criteria Reference: Principal Plan & PLANNED PROGRAM j Interpolation Method: MD Interval: 5.00 ft Error Model: ISCWSA Ellipse ~ Depth Range: 28.50 to 7273.41 ft Scan Method: Trav Cylinder North Maximum Radius:10000.00 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath i Date: 12/14/2006 Validated: No Version: 4 ~ Planned From To Survey Toolcode Tool Name i ft ft 28.50 800.00 Planned: Pla n #5 V2 GYD-GC-SS Gyrodata gyro single shots 800.00 2200.00 Planned: Pla n #5 V2 MWD MWD - Standard 800.00 4100.00 Planned: Plan #5 V2 MWD+IFR +MS MWD +IFR + Mu lti Station 4100.00 7273.41 Planned: Plan #5 V2 MWD+IFR +MS MWD +IFR + Mu lti Station Casing Points MD 1'Vll lliameter Holc Size Name ft ft in in __ --- -- 3730.00 2822.00 9.625 12.250 9 5/8" 7273.41 4973.38 7.000 8.750 7" Summary _ <- -- O ffset Wellpath ---> Reference Offset Ctr-Ctr No-Go Allowable ~ Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft PB V Pad Plan V-121 (S-R) Plan V-121 V2 Plan: PI 1807.44 1905.00 133.36 30.26 103.10 Pass. Major Risk ~ PB V Pad ~ Plan V-215 (S-I) Plan V-215 V1 Plan: PI 341.65 345.00 296.40 6.47 289.93 Pass: Major Risk i PB V Pad V-01 V-01 V15 279.49 280.00 217.29 5.07 212.22 Pass: Major Risk PB V Pad V-02 V-02 V12 270.39 270.00 236.33 4.94 231.39 Pass: Major Risk PB V Pad V-03 V-03 V7 552.34 470.00 15.63 8.83 6.80 Pass: Major Risk PB V Pad V-04 V-04 V7 404.27 405.00 106.64 7.44 99.20 Pass: Major Risk PB V Pad V-100 V-100 V7 308.05 310.00 181.43 5.37 176.05 Pass: Major Risk PB V Pad V-101 V-101 V7 401.23 405.00 307.62 6.87 300.74 Pass: Major Risk PB V Pad V-102 V-102 VS 392.89 395.00 188.96 7.90 181.06 Pass: Major Risk PB V Pad V-103 V-103 V6 408.92 410.00 44.92 7.16 37.76 Pass: Major Risk PB V Pad V-104 V-104 V13 367.88 370.00 250.81 6.30 244.51 Pass: Major Risk PB V Pad V-105 V-105 V13 422.09 425.00 120.91 7.22 113.68 Pass: Major Risk PB V Pad V-106 V-106 V10 417.80 420.00 72.73 6.70 66.03 Pass: Major Risk i PB V Pad V-106 V-106A V9 432.19 435.00 74.24 8.18 66.06 Pass: Major Risk PB V Pad V-106 V-106AP61 V6 432.19 435.00 74.24 8.18 66.06 Pass: Major Risk PB V Pad V-106 V-106AP62 V2 432.19 435.00 74.24 8.18 66.06 Pass: Major Risk '; PB V Pad V-106 V-106AP63 V2 432.19 435.00 74.24 8.18 66.06 Pass: Major Risk PB V Pad V-107 V-107 V5 420.35 425.00 220.11 6.60 213.52 Pass: Major Risk i PB V Pad V-108 V-108 V7 254.68 255.00 342.44 4.50 337.95 Pass: Major Risk t ~ PB V Pad V-109 V-109 V2 361.12 365.00 347.06 6.42 340.64 Pass: Major Risk PB V Pad V-109 V-109P61 V5 361.12 365.00 347.06 6.42 340.64 Pass: Major Risk PB V Pad V-109 V-109P62 V2 361.12 365.00 347.06 6.42 340.64 Pass: Major Risk PB V Pad V-111 V-111 V25 429.79 430.00 12.14 8.09 4.05 Pass: Major Risk PB V Pad V-111 V-111 P61 V8 429.79 430.00 12.14 8.09 4.05 Pass: Major Risk PB V Pad V-111 V-111 PB2 V2 429.79 430.00 12.14 8.09 4.05 Pass: Major Risk PB V Pad V-111 V-111 PB3 V6 429.79 430.00 12.14 8.09 4.05 Pass: Major Risk PB V Pad V-112 V-112 V7 309.70 310.00 400.04 5.76 394.27 Pass: Major Risk PB V Pad V-113 V-113 V6 341.74 345.00 372.53 5.42 367.11 Pass: Major Risk PB V Pad V-114 V-114 V5 304.84 305.00 322.14 5.27 316.87 Pass: Major Risk ~ PB V Pad V-114 V-114A V4 304.84 305.00 322.14 5.27 316.87 Pass: Major Risk PB V Pad V-114 V-114AP61 V4 304.84 305.00 322.14 5.27 316.87 Pass: Major Risk PB V Pad V-114 V-114AP62 V2 304.84 305.00 322.14 5.27 316.87 Pass: Major Risk PB V Pad V-115 V-115 V5 332.70 335.00 182.54 5.64 176.90 Pass: Major Risk PB V Pad V-115 V-115PB1 V4 332.70 335.00 182.54 5.64 176.90 Pass: Major Risk PB V Pad V-117 V-117 V9 312.61 315.00 183.77 5.58 178.18 Pass: Major Risk PB V Pad V-117 V-117P61 V6 312.61 315.00 183.77 5.58 178.18 Pass: Major Risk PB V Pad V-117 V-117PB2 V6 312.61 315.00 183.77 5.58 178.18 Pass: Major Risk PB V Pad V-119 V-119 V13 402.49 410.00 334.00 7.21 326.79 Pass: Major Risk PB V Pad V-120 V-120 V5 289.88 290.00 29.94 5.28 24.66 Pass: Major Risk PB V Pad V-122 V-122 V10 2198.57 2225.00 98.45 55.54 42.92 Pass: Major Risk PB V Pad V-122 V-122P61 V10 57 2198 2225.00 98.45 55.54 42.92 Pass: Major Risk . ~ • Company: BP Amoco Field: Prudhoe Bay Reference Site: PB V Pad Reference Well: Plan V-218 (N-V) Reference Wellpath: Plan V-218 Summars BP Alaska Anticollision Report Date: 2119/2007 Time: 10:42:37 Page: Co-ordinate(NE) Reference: Vertical (TVD) Reference: < --- Offset Wellpath - - ---> Reference Offset Site Well Wellpath MD MD ft ft PB V Pad V-201 Plan V-201A V1 Plan: P 363.49 365.00 PB V Pad V-201 V-201 V10 363.49 365.00 PB V Pad V-202 V-202 V9 410.34 415.00 PB V Pad V-202 V-202L1 V5 410.34 415.00 PB V Pad V-202 V-202L2 V5 410.34 415.00 PB V Pad V-203 V-203 V18 440.27 450.00 PB V Pad V-203 V-203L1 V6 1700.00 7715.00 PB V Pad V-203 V-203L2 V4 1600.00 6965.00 PB V Pad V-203 V-203L3 V3 1600.00 6915.00 PB V Pad V-203 V-203L4 V3 440.27 450.00 PB V Pad V-204 V-204 V2 533.95 565.00 PB V Pad V-204 V-204L1 V2 533.95 565.00 PB V Pad V-204 V-204L1P61 V6 533.95 565.00 PB V Pad V-204 V-204L2 V2 533.95 565.00 PB V Pad V-204 V-204L2P61 V5 533.95 565.00 PB V Pad V-204 V-204L3 V3 533.95 565.00 PB V Pad V-204 V-204P61 V9 533.95 565.00 PB V Pad V-204 V-204P62 V2 533.95 565.00 PB V Pad V-205 drilling Plan V-205L2 OA V6 Pla 370.40 375.00 PB V Pad V-205 drilling V-205 V13 351.40 355.00 PB V Pad V-205 drilling V-205L1 V7 351.40 355.00 PB V Pad V-210 V-210 V9 434.22 440.00 PB V Pad V-211 V-211 V5 310.68 310.00 PB V Pad V-212 V-212 V7 430.57 430.00 PB V Pad V-213 V-213 V5 1219.03 1255.00 PB V Pad V-213 V-213PB1 V5 1219.03 1255.00 PB V Pad V-214 V-214 V3 540.68 560.00 PB V Pad V-214 V-214P61 V2 484.90 495.00 PB V Pad V-214 V-214P62 V3 538.75 555.00 PB V Pad V-214 V-214P63 V5 538.75 555.00 PB V Pad V-214 V-214P64 V2 538.75 555.00 PB V Pad V-216 V-216 V8 414.92 415.00 PB V Pad V-217 V-217 V5 346.68 350.00 PB V Pad V-221 V-221 V6 551.08 560.00 Well: Plan V-218 (N-V), True North V-218 Plan 82.0 Db: Oracle Ctr-Ctr No-Go Allowable Distance Area Deviation Warning ft ft ft 206.37 6.13 200.24 Pass: Major Risk 206.37 6.13 200.24 Pass: Major Risk 280.61 7.51 273.11 Pass: Major Risk 280.61 7.46 273.16 Pass: Major Risk 280.61 7.46 273.16 Pass: Major Risk 351.10 8.95 342.15 Pass: Major Risk 5954.79 No Offset Errors 5646.85 No Offset Errors 5612.64 No Offset Errors 351.10 8.95 342.15 Pass: Major Risk 296.87 9.70 287.17 Pass: Major Risk 296.87 9.70 287.17 Pass: Major Risk 296.87 9.70 287.17 Pass: Major Risk 296.87 9.70 287.17 Pass: Major Risk 296.87 9.70 287.17 Pass: Major Risk 296.87 9.70 287.17 Pass: Major Risk 296.87 9.70 287.17 Pass: Major Risk 296.87 9.70 287.17 Pass: Major Risk 201.90 7.17 194.73 Pass: Major Risk 201.40 6.39 195.01 Pass: Major Risk 201.40 6.39 195.01 Pass: Major Risk 264.12 7.79 256.33 Pass: Major Risk 325.69 5.44 320.25 Pass: Major Risk 61.14 7.50 53.64 Pass: Major Risk 70.26 19.97 50.29 Pass: Major Risk 70.26 19.97 50.29 Pass: Major Risk 295.63 10.23 285.40 Pass: Major Risk 295.31 10.47 284.84 Pass: Major Risk 295.68 10.39 285.29 Pass: Major Risk 295.68 10.39 285.29 Pass: Major Risk 295.68 10.39 285.29 Pass: Major Risk 27.48 7.64 19.83 Pass: Major Risk 193.94 7.20 186.75 Pass: Major Risk 132.39 11.60 120.79 Pass: Major Risk FieldPrudhoe Bay SitoPB V Pad Well :Plan V-218 (N-V) WellpathPlan V-218 -3 1 3 5 t 3 ~ 5 , 2~~~24 1 4''. -200 '~p37 200 ~ 0 1$ 1 2 1 ~ ~ r} 3, 3 0 2 2 2 6 ~ ;t 3 1 7 , V~ 12 12 t 1 00 4 t 9 ~ 1 2 `'~bt 2 E 1 1 ~ '4 1 0t~1 1 ~i 3 ~~ t ~1 8 ~~~ 2~t. 1 5 1 0 , } 4 \' ~ 2 24 8., 1j ?2 ;9 ~1 \1 ~ 0 1~2D '~ 7 4 g 1i 7 1 3 t 5" ~~ S 5 $ ~6 t7 t~ `~ 7V 6 7 ' l; ,~o~ s ~ a_~~ o~~ g, ~. ay =~ ° ~ ,d,~" ~ ~~ ` ~ as " y 8 _tl! Ei 51 a ~T ~ ~ 2 2 f~ {~1 1 ~~ ~~~ yy ~~ c ~ 6 l'. IU X 5 7 1 ~ 6 1 0 0 +"~ ,r 7 ~ ~$.~`' "r7 L, 2 t ~'f4 i 7 ~ 1 5 ~ g0 0 `, ~ ~g 2 0 , $ ~ ,6 1 8 f 1 0 ,, 2~ '~ t ~ 1 ° 7 3 t ~ t 3 ~ ~ ~ "~ ~15 t5a 11~ ~~ 6 '8 ..200 ~ 6 dt. ~~ ~ ~ L1{. ~ 1 D ~~ ~ ~ T~_g~ ~g ~ $ 5 '7 /~~" ~.r~ 0 9 S. 0 1 4 T ~- T g1 1 3 0 0 3 0 D ~~,_/ --3 1 3 _ '~. 0 90 20 50 Travelling Cylinder Azimuth (TFO+AZI) [degj vs Centre t Target: V-218 Tgt OA Site: PB V Pad Well: Plan V-218 (N-V) ' Drilling Target Conf.: 90% Based on: Planned Program ' Description: Vertical Depth: 4455.00 ft below Mean Sea Level ap ort mg: ocal + - --- -, ------- Map Easting : 595045.00 ft Local +E/-W: 4322.87 ft Latitude: 70° 19'42.249N Longitude: 149° 13'44.973 W Shape: Circle Radius: 50 ft __ 200 50 I00 50 0 ~ o ,~ p 0 D~~ 0~~} oti l~ 0 0 0 0 o ~n o ~n m c~ ~ ~ ~ ~ ~ ~ ------ 1-------- ---------1 E 5,172 I 15'00' GRIP I 00" PLANT Z ^ v-120 V-03 V-2181 V-111 ^ V-2161 ^ V-103 ^ V-212 ^ V-106 ^ V-04 ^ V-1051 ^ V-221i I' I IM Im IZ I I I I I I I I I I I I I I I I ~ ~~PAD ~ / ZO WOA ~ ~~~ NOTES ^ V-102 ^ V-201 ^ v-107 ^ v-02 ^ V-104i ^ V-210i ^ V-202 ^ V-214i ^ V-101 ^ V-211 i ^ V-108 ^ V-203 ^ V-115 ^ V-2131 ^ V-100 ^ Y-122 ^ V-117 ^ SLOT S-R ^ V-2171 ^ V-205 ^ V-01 \ jl L-PAD ~`, 34 . 35 i 36 ~' 1 -N- `~ ~ ~ T12N ~~ ~~ ~ T11N ,WEST r; { ,;' ~s~~A~~K 2 ; r 1`. 3 PROJECT'. AREA ' V-PAD 1e ` s~~N 11 12 E R~ VICINITY MAP N.T.S. ^ V-SPARE (SLOT 5-~) I I ^ SLOT S-J I ml ^ V-204 ~ ~ v-iis ZI WELL V-2181 RENAME NOTE ^ V-109 I THIS AS-BUILT DRAWING IS A REISSUE OF I A PREVIOUS CONDUCTOR AS-BUILT FOR WELL ^ V-113 I WELL V-110 DATED MARCH 26, 2004. I WELL V-110 IS BEING RENAMED WELL V-218i ^ V-112 I I I I V-PAD ~- TO SPINE ROAD - - - - LEGEND -~- AS-BUILT CONDUCTOR ^ EXISTING CONDUCTOR 1. DATE OF SURVEY: MARCH 23-24, 2004. 2. REFERENCE FIELD BOOK: W004-03 PG's 26-29. 3. ALASKA STATE PLANE COORDINATES ARE ZONE 4, NAD 27. GEODETIC POSITIONS ARE NAD-27. 4. BASIS OF HORIZONTAL CONTROL IS V-PAD OPERATOR MONUMENTATION. 5. BASIS OF ELEVATION IS KUPARUK PIPELINE CONTROL. ELEVATIONS ARE BP MEAN SEA LEVEL DATUM. 6. THE MEAN SCALE FACTOR FOR V-PAD IS 0.999909334. OF ,~~ A~ ~P°°°~•~ ~°°~`S' ~e •°~9 ~0 49~' ~ e~ '~,'~o Richard F. Allison 10608 •• ~•~°°• o ~`ESSIONA~ SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS AS-BUILT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF MARCH 24, 2ID04. LOCATED WITHIN PROTRACTED SEC. 11. T. 11 N., R. 11 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION N0. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) BOX ELEV. OFFSETS V-2181 Y 5,970,138.47 N 10,180.10 70'19'41.334" 70.3281483' 53 5' 4,889' FSL ' X 590,723.98 E 4,985,09 149'15'51.172" 149.2642144' . 1,576 FEL r. r<ooerr, """"SAcoes CHECKED: {1„ HACKLEMAN ~./Y DATE: 2/70/07 •' DRAN7NG: SHEET: yy~~ FR807 WOV 01-00 GREATER PRUDHOE BAY V-PAD ~ 14I~~~~o doe No: RENAMED AS-BUILT CONDUCTOR B 2 10 07 ISSUED FOR INFORMATION ~ K,~ SCALE: 1 ~ 1 ~•=is0' WELL V-2181 NQ DATE REVISION BV CHK ~~~. u.sc RE: Paddle Variance Request--V-218 Subject: RE: Paddle Variance Request--V-218 From: "Staudinger, Mark" <Mark.Staudinger~%bp.com> Date: Thu, 22 Mar 2007 10:08:37 -0800 Ta: Thom~~~ ~~l~uin~ic•r ~ -t~~m nutun~lci-"~i'~idmin.state.ak.us> Tom- I have included an updated V-2181 permit to drill with the wording you are looking for. Let me know if you need anything else. Thanks, Mark Staudinger GPB Rotary. Drilling (907) 564-4337 (907} 440-7403 cell -----Original Message----- From: Thomas Maunder [mailtc:to:r mz;underC~=~adnin.state.ak.us] Sent: Thursday, March 22, 2007 7:32 AM To: Staudinger, Mark Cc: Tirpack, Robert B Subject: Paddle Variance Request--v-218 Mark, I am reviewing the application for V-218. With regard to having the paddle removed during the early portions of the surface hole, you have listed the reason for the request however there also needs to be mention of the mitigation .steps that will be taken while the paddle is out. Check with Scott Kolstad, I_ believe he had provided a statement for V-121. Call or message with any questions. - Tom Maunder. PE AOGCC Content-Description: V-218i Permit To DrilI.ZIP V-218i Permit To Dri11.ZIP' Content-Type: application/x-zip-compressed Content-Encoding: base64 1 of 1 3!22/2007 10:13 AM 6050000 ~.~_ , EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) ,~.~. ~~ _,. ; ..._.. ....::..,,,,...x,..t'~s,w8. . w.,_~kn~sa..;.~ .'.,. x ,_.ik4s4:, , ..o~,...s .... t..x.~''.~..t;:~~C^_...a.. ~ .:: ....... ~,. , _ ....-... 6000000 5950000 I 5900000 5850000 '-~---~-- 400000 500000 600000 700000 800000 • i .~_ ° Alaska Department of Natur~esources Land Administration System ~_~ ~~,c.€~~lt.~~.:.,~~cl~~State Gabins Page 1 of 4 ~~r~a ~r~es _._~_.._ ~ +~ 1"~/ LAS Nfenu ~ Case Abstrar# ~ Case De#ail ~ Land A4~strac# :, I tle: aDL 282~4Q Sear::,~~ ff~r Status ~'~4t ~~:1 ~+=-~s Customer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON [3L A"C"fN: LAND MANAGL'K- ALASKA ANCHORAGE AK 995196612 Case Ttihe: 784 OIL & GAS LEASE COMP DNR Unit: 780 O[L AND GAS File Location: DOG DIV OIL AND GAS ' Ouse Status: 3~ ISS/APPRV/AC ~ aJ AUTI I ~ Stcttu~, hale: 09~ 14/ 1965 TotulAcres: 2560.000 Date ulitiutecl: 03/28/I9ti5 C)ffice of Primrn~~ Respor~r.cibilii~: DOG D[V O IL AND GAS Lase Tf~ansaction Date: 12/04/2006 Case Suhtyhe: NS NORTH SLOPE Last Transaction: AA-NRB ASSIGNMENT APP ROVED I l~~ri~/rent: l'~ Toit°nship: 011 N Ratz;e: 01 1 E ~~~... Section. 0 t Section Acres: 640 Searcl3 _,, > 1Vlericliun: U Totivns~i~~: O1 IN Lunge: 011E Section: 02 Section Acres: 640 Nlericlian: U Totir~t~lrri>: OIIN Range: O1lE Section: I1 SeclionAcres:640 :I~Iericlian: U Totiti~n~{rii~ ~ U I TN Runge: 011E Section: 12 Section ,1cf~es: 640 . Legal Description 0~-?~~-196 '~"~ ~SALI~' ~~'OTICELEU_~L DE,S'C'RII'TIOr'~'* `^` CI-/-19 OI1~V-011E-C1tI1,2,11,1? ?60.00 U-1-01-1~ ~? * ~ L;l~"ITIZED, LE.-SSE ~IIVD PARTICIPATING ARIA LEGA I, DESC 'RIPTIC)iV * ~` LF.:<LSF_ CO_lI,1IITTED LV ENTIRETY TO PRUDHOE PAY (L'~'ITAIVZ) OIL RIaI GAS CAP P.1 PRCI~fI(JF PAY CN'IT http://www.dnr. state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28240&... 3/19/2007 'Alaska Department of Natura Resources Land Administration System Page 2 of 4 (III. IZI11:11'~~'D G.4,S' ~:dP PAIZIIC'IPAILti'G ,4IZEAS' 1: 11 N. R 11 E_, Ull%IL~TIIIERIDIAN ALASKA SECTION I: ALL, 6-10.00 ACRES; SECTION 2: ALL, 6-10.00 ACRES; .S'ECTION 11: ALL, 610.00ACRES; SECTION 12: AI G, 6-10. DO ACRES; CONTAL'VINGAPPR(~YI~1%I_~11EI,Y2.~60.OOACRES, MORE OR LESS'. ##%k*~e***:R#*:k ;k v:k <:kx:k*~:r**kk-%,<*~~:k*TT*~*~*~:~~**~x#~k :kT~=*:kv*M:k~x <~N~:k~~ : :kx~ I I -01- 2001 * *T°OR~~t=1 TION OF BOREALIS P~1 RTICIPA TING ~tRE~1 LFG.~I L DESCRIPTION LE<~SG INCORFOR~1 TED I,'V PART INTO THE BP,~1 * °~ PRZ.'UHOF. f3:~{Y (,-T'IT BORF_ilLIS P: RTICIPATING ARE4 ~ ~ ' TRACT ~0 (P:9RTIAL~ 7: 11:x'.. R.11 E.. U:'III.=1 T :1IERIDI.~1 ~'~~, AL,-1.S'I~:1 SECTIOl~' 1: tit", YV?E2, -150.00 f1 CRES,~ SECTION ?: ALL, 6=10.00 ACRES; SECTION I1: N2..V 252, Ib'0.00 AC 'RES: SLE;TIO.N I2: ~~'[~"1. [d'2.NE:'1, ?-10.001<1C'RES'; THlS TRACT CONTAINS 1,810.00 ACRES, MORE OR LESS. *:k'm*i: :k >,: *'~:k v:k~~x,i=;k ~:~ <;tx~:k >_i=:k :k ~: :k i_:I;~ <:k~~=:kK~~=k*~*~k:k~x*T ~k :k Ac ~,=k=k ~: ;:xv~:k*~;,; ~: 02-01-200-1 r *FORMi1 TIO>t' Olt ORION P,1 RIIL'IP:4 TING ARE 4 LEG_d I_ DE'SCRIPTION'k ~~ LEASE CO~~L'~IITTED IN PART TO ORION PARTICIPATING ~1RL:4 1'RUDHOE BAY UNIT TR_4C.'T ~0 ORION PARTICIPATING AREA T II ;~'. R. 1I 1:'., U.IILATaIERIDLI'~; ,1TA~S'K1 http://www. dnr. state. ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=2 8240&... 3/ 19/2007 `Alaska Department of Natur~esources Land Administration System Page 3 of 4 SECTION I: ALL, 6~lO.OOACRES: SECT IO;~%?: ALL, 6-10.00 AC'RF_S; .S'EC;TIO,V I l: EL'2, El '?l~'G~'U-1, -100.00 AC'RE,S; SECTION 12: ALL, 6-10.00 ACRES; C01V7AINING APPROXIMATELY 2, 3?0.00 ~tC`RFS', ~L~ORE OR LESS: :; ~ :k ,_~, :<'; >: ~:tx%k <:k**k%KT%Kx~x**x**%Rk %:k*~:~~~~=*~KK~Ft ;k %k >;< <~~= c < <;<y>I= <1=^`k-:t-1=F :r :t ;< 12-01-?00-1 * * * *BOREALIS PA E.kPANUED, LEASE INCORPORATED IN P_ART* * * * * "` LEG=AL DESCKIP"['ION /S AS FOLLOWS.• PR UDHOE I3A Y UNIT 130REALIS P.~IRTTCIP.9TINGAREA TR=~C.'T~0 (PriRTIAL~ T I I N. R. 11 Z~'. , U~L114 T 1t1E1ZIDIAN, ALAShA SECTION 1: EZE2, 160. DO ACRES'; .S"ECTION 11: S2SE~, b'O.OO ACIDS: SECTION I?: S'2, E2NE-1, ~100.OOACRES: THIS TRAC T CONT_%tINS 6.10.00 ACRES, 111c~RE~f~R L-ESS. *THE ACREAGE NOW' INCORPORATED INTO THE BPA hS' DESCRIBED AS FOLLOWS'.' PR UDHOE I3A Y UNIT BOREAI GS PARTK-IP_ATING AREA TRACT ~0 (P.-ART/f1 L) T 11N, 1:11E., U~t11ATMERIDIAN. 1~LASK:-t SECTION I: ALL. 6.10.00 ACRES; SEC'TTON 2: ~1LL, 6-10.00 ACRES, SECTION I1: N2, SEd, N2SiV-1, 360 ACRES; SECTION 12: ALL; 60.00 ACRES; http://www.dnr. state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28240&... 3/19/2007 'Alaska Department of Natur~ esources Land Administration System Page 4 of 4 • THIS TR t(:'T COI'~'7: ~L1'S' ?-~~50.O11 ACRES, MORE OR LESS. :k;~:i::t:k~~::k:~K:kx~k~=k~~:t:key:k:k~~_:k*~,:g:<;;<:t*##*#%k~~k;k*:k:k=k T%K :k ~:k %:<~:%<~~;,: y:tx;~ ~ <~„<~kt Last updated on 03/19/2007. Not sure who to contact? Have a question about DNR? Visit the uiic Infc~rrna~~an :enter. Report technical problems with this page to the Webrr~aster. Site optimized for Netscape 7, IE 6 or above. This site also requires that all ~3IES must be accepted. State of Alaska Natura(_Resouroes LRS Home Copyright I'r€vacy System_Status http://www.dnr. state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28240&... 3/19/2007 • Sondra D. Stewman 8s-si,25z 161 BP Exploration AK INC. "Mastercard Check" PO Box 196612 MB 7-5 - _~ ~ ~~ Anchorage, AK 99519-6612 oarE lJ PAY TO THE ~~/ (~ $ ~~L(~'j~~: ORDER OF ~~.~' ' ~~/ °OLLARS First National Alaska o K 99501^ ~ l.. {/... L MEMO ~:L25200060~:99L46227L56411' 0.~6L • • WELL t~i'AIVtE ~,BC~ 1/-- o?/~ PT~# ~o~o.~o ®evelopment / Service Exploratory Stratigraphic Vest Yon-Conventional Welt Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ~ ADD-ONS TEXT FOR APPROVAL LETTER WHAT ~ (OPTIONS) ! ' APPLIES L Mli LTt LATERAL ~ The permit is for a new wellbore segment of existing ~ ~ well (AIF last two digits in ~ Permit No. ,API No. 30- - - PI b I num er a between 60-69) re Production should continue to be reported as a function of the i' j ;original APt number stated above. PILOT HOLE [n accordance with 20 AAC 23.003(f), all records, data and. logs !acquired for the pilot hole must be clearly differentiated in both i ;well name ( PH) and API number i ' (30- - -_) from records, data and lobs ~ ~ ~ acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION i 23.0». Approval to perforate and produce /infect is contingent ~ upon issuance of a conservation order approving a spacing j i I exception. assumes the ' liability of any protest to the spacing exception that may occur. ; ;DRY DITCH ~ All dry ditch sample sets submitted to the Commission must be in SA!VIPLE I no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals j through target zones. ;Please note the following, special condition of this permit: jNon-Conventional ~ production or production testing of coal bed methane is not allowed Well ~ for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data I j on water quality and quantity. (Company Name) must contact the ~ Commission to obtain advance approval of such water well testing program. ~ Rev: 12Ji06 C:`jody~transmittal_checklist • • Q N ~ ~ ~ a j O ~ ~ ~ ~ ~ ~ N. - L ~ °, rn o N n. a uJ d O ~ ~ ~ ~ a. ~ ~ O' ~ ~ ~ ~ N' N > o ~ N m a ~ ° ~~ ~ : o m. o. ~ 't. o ~ 3. ~ ~ ~ p, l ° '~ ~ o N ° 3 , ~ ~ ~ ° o. : N, , : n col Q. a c ~ ~ ' ~ ~: o, c. ~ ~, ~ 'I p m M a W ~ OI ( ~ ~ ~ ~ ~~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~ ~ ~ ~ ~ ~ ~ ~ N. Z~ t , o' . ~ , ~ ~, ~ w. ~ O ~ a, 7~ Z i ~ ~ ~ _~ U ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ N. N U• . ~ ~. ~ m O ~ O. N~ n N ' ~ ~ N Z' ~ ~ -o. ~ o. c: Q. aNj oo, v, o N c. Z ~ m O. ~ ~ ~ Z, ~, a c' .. '~ ~ ~ d' W ~ O U p N , o. ' 4 n. p ~ Z ~ ~ ' ~ ~ ~ ~ ~ ~ ~ ~ . ~ ~ ~ ~ . ~ .. . 4 ~ ~: O ~ ~ ~ ~ N~ ~~ . ~ N~ C ~ ~ II ~ ~ ~ M. ~ ~ C ~ ~ ~ ~ ~ ~ ~ N. ~ ~ ~ ~ ~ . ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ o. o 3 ~ ~~ ~ . ~ ~, ~ . N~ ~ ~ L' ~ ~ N~ ~ ~ °~ ~ a. ~ ~ m y Q ~ ~ m• ~ ~ ~ ~ ~ ~ ~ ~ ~ -p' ~ N' ~ Q. ~ ~ a• ~ ~~ ~ Xr ~~ p~ p. ~ d. ~ ~ c. 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