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205-081
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, January 10, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC S-122 PRUDHOE BAY UN AURO S-122 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/10/2025 S-122 50-029-23265-00-00 205-081-0 G SPT 6585 2050810 1646 3137 3137 3134 3133 0 0 0 0 OTHER P Austin McLeod 11/2/2024 MITIA to MAIP. Under evaluation/diagnostic test. Op aware of the lack of 500psi differential. 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 AURO S-122 Inspection Date: Tubing OA Packer Depth 1353 3497 3442 3426IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM241102181907 BBL Pumped:2.5 BBL Returned:2.5 Friday, January 10, 2025 Page 1 of 1 99 999 99 9 9 9 9 9 9 9 9 9 9 Under evaluation/diagnostic test James B. Regg Digitally signed by James B. Regg Date: 2025.01.10 14:27:29 -09'00' CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: OPERABLE: WAG Injector S-122 (PTD #2050810) AA for slow TxIA communication Date:Thursday, December 5, 2024 12:32:37 PM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, December 5, 2024 12:08 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> Subject: OPERABLE: WAG Injector S-122 (PTD #2050810) AA for slow TxIA communication Mr. Wallace, Injector S-122 (PTD 2050810) AOGCC has approved AA 22F.002 for continued WAG injection with slow TxIA communication. The well is now classified as OPERABLE. 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: Sunday, December 1, 2024 9:09 AM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: [EXTERNAL] Re: UPDATE UNDER EVALUATION: WAG Injector S-122 (PTD #2050810) possible TxIA communication Ryan, Approved for an additional 28 days injection while we review and process the admin approval request. Thanks Chris From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Sunday, December 1, 2024 11:11:52 AM 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. To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: UPDATE UNDER EVALUATION: WAG Injector S-122 (PTD #2050810) possible TxIA communication Mr. Wallace, Injector S-122 (PTD 2050810) AA request was submitted to AOGCC on 11/22. The current 28 day under evaluation period ends on 12/03. With approval, we would like to extend the under evaluation period while the AA is being reviewed and keep the well on injection. 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, November 5, 2024 9:55 AM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Aras Worthington <Aras.Worthington@hilcorp.com>; Michael Hibbert <Michael.Hibbert@hilcorp.com>; PB EOC Specialists <PBEOCSpecialists@hilcorp.com>; PB Wells Optimization Engineers <PBWellsOptimizationEngineers@hilcorp.com>; PBW GC2 Field Lead Operator <PBWGC2FieldLeadOperator@hilcorp.com>; PBW GC2 Foreman <PBWGC2Foreman@hilcorp.com>; PBW GC2 Wellpad HUQ <PBWGC2WellpadHUQ@hilcorp.com>; PBW GC2 Wellpad LV <PBWGC2WellpadLV@hilcorp.com>; PBW GC2 Wellpad MN <PBWGC2WellpadMN@hilcorp.com>; PBW GC2 Wellpad RJ <PBWGC2WellpadRJ@hilcorp.com>; PBW GC2 Wellpad S <PBWGC2WellpadS@hilcorp.com>; PBW GC2 Wellpad W <PBWGC2WellpadW@hilcorp.com>; PBW GC2 Wellpad Z <PBWGC2WellpadZ@hilcorp.com>; PBW GC2 West Field Lead Operator <PBWGC2WestFieldLeadOperator@hilcorp.com>; PBW PCC Leads <GC3ProdContCenterLeads@hilcorp.com>; Tyson Shriver <Tyson.Shriver@hilcorp.com> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; Tim Atkinson <Tim.Atkinson@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UPDATE UNDER EVALUATION: WAG Injector S-122 (PTD #2050810) possible TxIA communication All, Injector S-122 (PTD 2050810) passed AOGCC MIT-IA on 11/02 to 3426 psi. AOGCC has agreed to an additional 28 days monitoring to verify TxIA rate and potentially apply for AA for continued gas injection. The under evaluation clock has been reset. 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: Thursday, October 10, 2024 8:18 AM To: Aras Worthington <Aras.Worthington@hilcorp.com>; Michael Hibbert <Michael.Hibbert@hilcorp.com>; PB EOC Specialists <PBEOCSpecialists@hilcorp.com>; PB Wells Optimization Engineers <PBWellsOptimizationEngineers@hilcorp.com>; PBW GC2 Field Lead Operator <PBWGC2FieldLeadOperator@hilcorp.com>; PBW GC2 Foreman <PBWGC2Foreman@hilcorp.com>; PBW GC2 Wellpad HUQ <PBWGC2WellpadHUQ@hilcorp.com>; PBW GC2 Wellpad LV <PBWGC2WellpadLV@hilcorp.com>; PBW GC2 Wellpad MN <PBWGC2WellpadMN@hilcorp.com>; PBW GC2 Wellpad RJ <PBWGC2WellpadRJ@hilcorp.com>; PBW GC2 Wellpad S <PBWGC2WellpadS@hilcorp.com>; PBW GC2 Wellpad W <PBWGC2WellpadW@hilcorp.com>; PBW GC2 Wellpad Z <PBWGC2WellpadZ@hilcorp.com>; PBW GC2 West Field Lead Operator <PBWGC2WestFieldLeadOperator@hilcorp.com>; PBW PCC Leads <GC3ProdContCenterLeads@hilcorp.com>; Tyson Shriver <Tyson.Shriver@hilcorp.com> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; Kevin Brackett <Kevin.Brackett@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UPDATE UNDER EVALUATION: WAG Injector S-122 (PTD #2050810) possible TxIA communication All, Injector S-122 (PTD 2050810) per AOGCC, the under evaluation clock has been reset to allow for continued intervention and monitoring to resolve possible slow TxIA communication. Access to S- 122 has been obstructed by the rig activity on S-119. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, September 12, 2024 3:31 PM To: Aras Worthington <Aras.Worthington@hilcorp.com>; Michael Hibbert <Michael.Hibbert@hilcorp.com>; PB EOC Specialists <PBEOCSpecialists@hilcorp.com>; PB Wells Optimization Engineers <PBWellsOptimizationEngineers@hilcorp.com>; PBW GC2 Field Lead Operator <PBWGC2FieldLeadOperator@hilcorp.com>; PBW GC2 Foreman <PBWGC2Foreman@hilcorp.com>; PBW GC2 Wellpad HUQ <PBWGC2WellpadHUQ@hilcorp.com>; PBW GC2 Wellpad LV <PBWGC2WellpadLV@hilcorp.com>; PBW GC2 Wellpad MN <PBWGC2WellpadMN@hilcorp.com>; PBW GC2 Wellpad RJ <PBWGC2WellpadRJ@hilcorp.com>; PBW GC2 Wellpad S <PBWGC2WellpadS@hilcorp.com>; PBW GC2 Wellpad W <PBWGC2WellpadW@hilcorp.com>; PBW GC2 Wellpad Z <PBWGC2WellpadZ@hilcorp.com>; PBW GC2 West Field Lead Operator <PBWGC2WestFieldLeadOperator@hilcorp.com>; PBW PCC Leads <GC3ProdContCenterLeads@hilcorp.com>; Tyson Shriver <Tyson.Shriver@hilcorp.com> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; Kevin Brackett <Kevin.Brackett@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UNDER EVALUATION: WAG Injector S-122 (PTD #2050810) possible TxIA communication All, Injector S-122 (PTD 2050810) was recently converted to a WAG injector under Sundry #324-268. The well was placed on initial injection on 08/28/24 and passed an AOGCC witnessed MIT-IA on 09/03/24. Shortly after the AOGCC MIT-IA the IAP was bled and since that bleed, the IAP has continued to increase. This indicates the IA re-pressurization is due to TxIA communication. The well will now be classified as UNDER EVALUATION and is on the 28-day clock for diagnostics. Plan forward: 1. DHD: PPPOT-T 2. Slickline: Replace DGLVs with extended packing DGLVs 3. Well Integrity: Monitor for IA re-pressurization/additional diagnostics as needed. 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 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UPDATE UNDER EVALUATION: WAG Injector S-122 (PTD #2050810) possible TxIA communication Date:Monday, December 2, 2024 10:12:31 AM From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Sunday, December 1, 2024 9:09 AM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: Re: UPDATE UNDER EVALUATION: WAG Injector S-122 (PTD #2050810) possible TxIA communication Ryan, Approved for an additional 28 days injection while we review and process the admin approval request. Thanks Chris From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Sunday, December 1, 2024 11:11:52 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: UPDATE UNDER EVALUATION: WAG Injector S-122 (PTD #2050810) possible TxIA communication Mr. Wallace, Injector S-122 (PTD 2050810) AA request was submitted to AOGCC on 11/22. The current 28 day under evaluation period ends on 12/03. With approval, we would like to extend the under evaluation period while the AA is being reviewed and keep the well on injection. 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, November 5, 2024 9:55 AM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Aras Worthington <Aras.Worthington@hilcorp.com>; Michael Hibbert <Michael.Hibbert@hilcorp.com>; PB EOC Specialists <PBEOCSpecialists@hilcorp.com>; PB Wells Optimization Engineers <PBWellsOptimizationEngineers@hilcorp.com>; PBW GC2 Field Lead Operator <PBWGC2FieldLeadOperator@hilcorp.com>; PBW GC2 Foreman <PBWGC2Foreman@hilcorp.com>; PBW GC2 Wellpad HUQ <PBWGC2WellpadHUQ@hilcorp.com>; PBW GC2 Wellpad LV <PBWGC2WellpadLV@hilcorp.com>; PBW GC2 Wellpad MN <PBWGC2WellpadMN@hilcorp.com>; PBW GC2 Wellpad RJ <PBWGC2WellpadRJ@hilcorp.com>; PBW GC2 Wellpad S <PBWGC2WellpadS@hilcorp.com>; PBW GC2 Wellpad W <PBWGC2WellpadW@hilcorp.com>; PBW GC2 Wellpad Z <PBWGC2WellpadZ@hilcorp.com>; PBW GC2 West Field Lead Operator <PBWGC2WestFieldLeadOperator@hilcorp.com>; PBW PCC Leads <GC3ProdContCenterLeads@hilcorp.com>; Tyson Shriver <Tyson.Shriver@hilcorp.com> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; Tim Atkinson <Tim.Atkinson@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UPDATE UNDER EVALUATION: WAG Injector S-122 (PTD #2050810) possible TxIA communication All, Injector S-122 (PTD 2050810) passed AOGCC MIT-IA on 11/02 to 3426 psi. AOGCC has agreed to an additional 28 days monitoring to verify TxIA rate and potentially apply for AA for continued gas injection. The under evaluation clock has been reset. 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: Thursday, October 10, 2024 8:18 AM To: Aras Worthington <Aras.Worthington@hilcorp.com>; Michael Hibbert <Michael.Hibbert@hilcorp.com>; PB EOC Specialists <PBEOCSpecialists@hilcorp.com>; PB Wells Optimization Engineers <PBWellsOptimizationEngineers@hilcorp.com>; PBW GC2 Field Lead Operator <PBWGC2FieldLeadOperator@hilcorp.com>; PBW GC2 Foreman <PBWGC2Foreman@hilcorp.com>; PBW GC2 Wellpad HUQ <PBWGC2WellpadHUQ@hilcorp.com>; PBW GC2 Wellpad LV <PBWGC2WellpadLV@hilcorp.com>; PBW GC2 Wellpad MN <PBWGC2WellpadMN@hilcorp.com>; PBW GC2 Wellpad RJ <PBWGC2WellpadRJ@hilcorp.com>; PBW GC2 Wellpad S <PBWGC2WellpadS@hilcorp.com>; PBW GC2 Wellpad W <PBWGC2WellpadW@hilcorp.com>; PBW GC2 Wellpad Z <PBWGC2WellpadZ@hilcorp.com>; PBW GC2 West Field Lead Operator <PBWGC2WestFieldLeadOperator@hilcorp.com>; PBW PCC Leads <GC3ProdContCenterLeads@hilcorp.com>; Tyson Shriver <Tyson.Shriver@hilcorp.com> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; Kevin Brackett <Kevin.Brackett@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UPDATE UNDER EVALUATION: WAG Injector S-122 (PTD #2050810) possible TxIA communication All, Injector S-122 (PTD 2050810) per AOGCC, the under evaluation clock has been reset to allow for continued intervention and monitoring to resolve possible slow TxIA communication. Access to S- 122 has been obstructed by the rig activity on S-119. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, September 12, 2024 3:31 PM To: Aras Worthington <Aras.Worthington@hilcorp.com>; Michael Hibbert <Michael.Hibbert@hilcorp.com>; PB EOC Specialists <PBEOCSpecialists@hilcorp.com>; PB Wells Optimization Engineers <PBWellsOptimizationEngineers@hilcorp.com>; PBW GC2 Field Lead Operator <PBWGC2FieldLeadOperator@hilcorp.com>; PBW GC2 Foreman <PBWGC2Foreman@hilcorp.com>; PBW GC2 Wellpad HUQ <PBWGC2WellpadHUQ@hilcorp.com>; PBW GC2 Wellpad LV <PBWGC2WellpadLV@hilcorp.com>; PBW GC2 Wellpad MN <PBWGC2WellpadMN@hilcorp.com>; PBW GC2 Wellpad RJ <PBWGC2WellpadRJ@hilcorp.com>; PBW GC2 Wellpad S <PBWGC2WellpadS@hilcorp.com>; PBW GC2 Wellpad W <PBWGC2WellpadW@hilcorp.com>; PBW GC2 Wellpad Z <PBWGC2WellpadZ@hilcorp.com>; PBW GC2 West Field Lead Operator <PBWGC2WestFieldLeadOperator@hilcorp.com>; PBW PCC Leads <GC3ProdContCenterLeads@hilcorp.com>; Tyson Shriver <Tyson.Shriver@hilcorp.com> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; Kevin Brackett <Kevin.Brackett@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UNDER EVALUATION: WAG Injector S-122 (PTD #2050810) possible TxIA communication All, Injector S-122 (PTD 2050810) was recently converted to a WAG injector under Sundry #324-268. The well was placed on initial injection on 08/28/24 and passed an AOGCC witnessed MIT-IA on 09/03/24. Shortly after the AOGCC MIT-IA the IAP was bled and since that bleed, the IAP has continued to increase. This indicates the IA re-pressurization is due to TxIA communication. The well will now be classified as UNDER EVALUATION and is on the 28-day clock for diagnostics. Plan forward: 1. DHD: PPPOT-T 2. Slickline: Replace DGLVs with extended packing DGLVs 3. Well Integrity: Monitor for IA re-pressurization/additional diagnostics as needed. 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 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UPDATE UNDER EVALUATION: WAG Injector S-122 (PTD #2050810) possible TxIA communication Date:Monday, November 4, 2024 11:02:40 AM Attachments:MIT PBU S-122 11-02-24.xlsx From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Monday, November 4, 2024 10:48 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: UPDATE UNDER EVALUATION: WAG Injector S-122 (PTD #2050810) possible TxIA communication Mr. Wallace, Injector S-122 (PTD 2050810) passed AOGCC MIT-IA on 11/02 to 3426 psi. Prior to the MIT-IA, the rate of TxIA while on MI appeared to be ~600 psi / day. Post MIT-IA, the TxIA rate on gas appears to be significantly lower (~190 psi / day). It is possible that the MIT-IA potentially helped seat the extended packing DGLV’s that were set last month. With your approval, I would like to request an additional 28 days of extended monitoring on MI when the current period expires on 11/07 to confirm the TxIA rate and apply for AA for continued injection. We would also use this time to monitor any liquid level changes in the annulus. 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: Thursday, October 10, 2024 8:18 AM To: Aras Worthington <Aras.Worthington@hilcorp.com>; Michael Hibbert <Michael.Hibbert@hilcorp.com>; PB EOC Specialists <PBEOCSpecialists@hilcorp.com>; PB Wells Optimization Engineers <PBWellsOptimizationEngineers@hilcorp.com>; PBW GC2 Field Lead Operator <PBWGC2FieldLeadOperator@hilcorp.com>; PBW GC2 Foreman <PBWGC2Foreman@hilcorp.com>; PBW GC2 Wellpad HUQ <PBWGC2WellpadHUQ@hilcorp.com>; PBW GC2 Wellpad LV <PBWGC2WellpadLV@hilcorp.com>; PBW GC2 Wellpad MN <PBWGC2WellpadMN@hilcorp.com>; PBW GC2 Wellpad RJ <PBWGC2WellpadRJ@hilcorp.com>; PBW GC2 Wellpad S <PBWGC2WellpadS@hilcorp.com>; PBW GC2 Wellpad W <PBWGC2WellpadW@hilcorp.com>; PBW GC2 Wellpad Z <PBWGC2WellpadZ@hilcorp.com>; PBW GC2 West Field Lead Operator <PBWGC2WestFieldLeadOperator@hilcorp.com>; PBW PCC Leads <GC3ProdContCenterLeads@hilcorp.com>; Tyson Shriver <Tyson.Shriver@hilcorp.com> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; Kevin Brackett <Kevin.Brackett@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UPDATE UNDER EVALUATION: WAG Injector S-122 (PTD #2050810) possible TxIA communication All, Injector S-122 (PTD 2050810) per AOGCC, the under evaluation clock has been reset to allow for continued intervention and monitoring to resolve possible slow TxIA communication. Access to S- 122 has been obstructed by the rig activity on S-119. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, September 12, 2024 3:31 PM To: Aras Worthington <Aras.Worthington@hilcorp.com>; Michael Hibbert <Michael.Hibbert@hilcorp.com>; PB EOC Specialists <PBEOCSpecialists@hilcorp.com>; PB Wells Optimization Engineers <PBWellsOptimizationEngineers@hilcorp.com>; PBW GC2 Field Lead Operator <PBWGC2FieldLeadOperator@hilcorp.com>; PBW GC2 Foreman <PBWGC2Foreman@hilcorp.com>; PBW GC2 Wellpad HUQ <PBWGC2WellpadHUQ@hilcorp.com>; PBW GC2 Wellpad LV <PBWGC2WellpadLV@hilcorp.com>; PBW GC2 Wellpad MN <PBWGC2WellpadMN@hilcorp.com>; PBW GC2 Wellpad RJ <PBWGC2WellpadRJ@hilcorp.com>; PBW GC2 Wellpad S <PBWGC2WellpadS@hilcorp.com>; PBW GC2 Wellpad W <PBWGC2WellpadW@hilcorp.com>; PBW GC2 Wellpad Z <PBWGC2WellpadZ@hilcorp.com>; PBW GC2 West Field Lead Operator <PBWGC2WestFieldLeadOperator@hilcorp.com>; PBW PCC Leads <GC3ProdContCenterLeads@hilcorp.com>; Tyson Shriver <Tyson.Shriver@hilcorp.com> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; Kevin Brackett <Kevin.Brackett@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UNDER EVALUATION: WAG Injector S-122 (PTD #2050810) possible TxIA communication All, Injector S-122 (PTD 2050810) was recently converted to a WAG injector under Sundry #324-268. The well was placed on initial injection on 08/28/24 and passed an AOGCC witnessed MIT-IA on 09/03/24. Shortly after the AOGCC MIT-IA the IAP was bled and since that bleed, the IAP has continued to increase. This indicates the IA re-pressurization is due to TxIA communication. The well will now be classified as UNDER EVALUATION and is on the 28-day clock for diagnostics. Plan forward: 1. DHD: PPPOT-T 2. Slickline: Replace DGLVs with extended packing DGLVs 3. Well Integrity: Monitor for IA re-pressurization/additional diagnostics as needed. 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 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently 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 theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 2050810 Type Inj G Tubing 3137 3137 3134 3133 Type Test P Packer TVD 6585 BBL Pump 2.5 IA 1353 3497 3442 3426 Interval O Test psi 3300 BBL Return 2.5 OA 0 0 0 0 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 / S Pad Austin McLeod Ryan Holt 11/02/24 Notes:MIT-IA to max anticipated injection pressure to inform AA application. Max MI header pressure ~ 3300 psi Notes: Notes: Notes: S-122 Form 10-426 (Revised 01/2017)MIT PBU S-122 11-02-24 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:PB Wells Integrity Cc:Regg, James B (OGC); Oliver Sternicki Subject:RE: UPDATE UNDER EVALUATION: WAG Injector S-122 (PTD #2050810) possible TxIA communication Date:Monday, November 4, 2024 11:02:18 AM Ryan, Your request for extended 28 days monitoring on MI is approved. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Monday, November 4, 2024 10:48 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: UPDATE UNDER EVALUATION: WAG Injector S-122 (PTD #2050810) possible TxIA communication Mr. Wallace, Injector S-122 (PTD 2050810) passed AOGCC MIT-IA on 11/02 to 3426 psi. Prior to the MIT-IA, the rate of TxIA while on MI appeared to be ~600 psi / day. Post MIT-IA, the TxIA rate on gas appears to be significantly lower (~190 psi / day). It is possible that the MIT-IA potentially helped seat the extended packing DGLV’s that were set last month. With your approval, I would like to request an additional 28 days of extended monitoring on MI when the current period expires on 11/07 to confirm the TxIA rate and apply for AA for continued injection. We would also use this time to monitor any liquid level changes in the annulus. 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: Thursday, October 10, 2024 8:18 AM To: Aras Worthington <Aras.Worthington@hilcorp.com>; Michael Hibbert <Michael.Hibbert@hilcorp.com>; PB EOC Specialists <PBEOCSpecialists@hilcorp.com>; PB Wells Optimization Engineers <PBWellsOptimizationEngineers@hilcorp.com>; PBW GC2 Field Lead Operator <PBWGC2FieldLeadOperator@hilcorp.com>; PBW GC2 Foreman <PBWGC2Foreman@hilcorp.com>; PBW GC2 Wellpad HUQ <PBWGC2WellpadHUQ@hilcorp.com>; PBW GC2 Wellpad LV <PBWGC2WellpadLV@hilcorp.com>; PBW GC2 Wellpad MN <PBWGC2WellpadMN@hilcorp.com>; PBW GC2 Wellpad RJ <PBWGC2WellpadRJ@hilcorp.com>; PBW GC2 Wellpad S <PBWGC2WellpadS@hilcorp.com>; PBW GC2 Wellpad W <PBWGC2WellpadW@hilcorp.com>; PBW GC2 Wellpad Z <PBWGC2WellpadZ@hilcorp.com>; PBW GC2 West Field Lead Operator <PBWGC2WestFieldLeadOperator@hilcorp.com>; PBW PCC Leads <GC3ProdContCenterLeads@hilcorp.com>; Tyson Shriver <Tyson.Shriver@hilcorp.com> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; Kevin Brackett <Kevin.Brackett@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UPDATE UNDER EVALUATION: WAG Injector S-122 (PTD #2050810) possible TxIA communication All, Injector S-122 (PTD 2050810) per AOGCC, the under evaluation clock has been reset to allow for continued intervention and monitoring to resolve possible slow TxIA communication. Access to S- 122 has been obstructed by the rig activity on S-119. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, September 12, 2024 3:31 PM To: Aras Worthington <Aras.Worthington@hilcorp.com>; Michael Hibbert <Michael.Hibbert@hilcorp.com>; PB EOC Specialists <PBEOCSpecialists@hilcorp.com>; PB Wells Optimization Engineers <PBWellsOptimizationEngineers@hilcorp.com>; PBW GC2 Field Lead Operator <PBWGC2FieldLeadOperator@hilcorp.com>; PBW GC2 Foreman <PBWGC2Foreman@hilcorp.com>; PBW GC2 Wellpad HUQ <PBWGC2WellpadHUQ@hilcorp.com>; PBW GC2 Wellpad LV <PBWGC2WellpadLV@hilcorp.com>; PBW GC2 Wellpad MN <PBWGC2WellpadMN@hilcorp.com>; PBW GC2 Wellpad RJ <PBWGC2WellpadRJ@hilcorp.com>; PBW GC2 Wellpad S <PBWGC2WellpadS@hilcorp.com>; PBW GC2 Wellpad W <PBWGC2WellpadW@hilcorp.com>; PBW GC2 Wellpad Z <PBWGC2WellpadZ@hilcorp.com>; PBW GC2 West Field Lead Operator <PBWGC2WestFieldLeadOperator@hilcorp.com>; PBW PCC Leads <GC3ProdContCenterLeads@hilcorp.com>; Tyson Shriver <Tyson.Shriver@hilcorp.com> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; Kevin Brackett <Kevin.Brackett@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UNDER EVALUATION: WAG Injector S-122 (PTD #2050810) possible TxIA communication All, Injector S-122 (PTD 2050810) was recently converted to a WAG injector under Sundry #324-268. The well was placed on initial injection on 08/28/24 and passed an AOGCC witnessed MIT-IA on 09/03/24. Shortly after the AOGCC MIT-IA the IAP was bled and since that bleed, the IAP has continued to increase. This indicates the IA re-pressurization is due to TxIA communication. The well will now be classified as UNDER EVALUATION and is on the 28-day clock for diagnostics. Plan forward: 1. DHD: PPPOT-T 2. Slickline: Replace DGLVs with extended packing DGLVs 3. Well Integrity: Monitor for IA re-pressurization/additional diagnostics as needed. 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 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, October 16, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC S-122 PRUDHOE BAY UN AURO S-122 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/16/2024 S-122 50-029-23265-00-00 205-081-0 G SPT 6585 2050810 1646 3125 3124 3122 3122 79 230 231 233 INITAL P Kam StJohn 9/3/2024 Initial MIT-IA Per Sundry 324-268 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 AURO S-122 Inspection Date: Tubing OA Packer Depth 63 2520 2482 2479IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS240904123559 BBL Pumped:3.2 BBL Returned:3 Wednesday, October 16, 2024 Page 1 of 1 9 9 9 9 9 9 999 9 9 9 9 9 9 9 Sundry 324-268 James B. Regg Digitally signed by James B. Regg Date: 2024.10.16 15:45:05 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UPDATE UNDER EVALUATION: WAG Injector S-122 (PTD #2050810) possible TxIA communication Date:Wednesday, October 9, 2024 8:06:05 AM From: Wallace, Chris D (OGC) Sent: Tuesday, October 8, 2024 3:15 PM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: RE: UPDATE UNDER EVALUATION: WAG Injector S-122 (PTD #2050810) possible TxIA communication Ryan, Additional 28 days monitoring and diagnostics is approved. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, October 8, 2024 2:52 PM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: UPDATE UNDER EVALUATION: WAG Injector S-122 (PTD #2050810) possible TxIA communication Mr. Wallace, Injector S-122 (PTD 2050810) TxIA remains consistent as it was reported on 09/12. An attempt to run extended packing DGLV was unsuccessful on 09/21 and access to the well with slickline is currently blocked by rig activity on S-119. With permission, I would like to extend the under evaluation period for an additional 28 days starting 10/10 to allow for intervention, monitoring and potential AA request. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, September 12, 2024 3:26 PM To: chris.wallace@alaska.gov Cc: jim.regg <jim.regg@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: WAG Injector S-122 (PTD #2050810) possible TxIA communication Mr. Wallace, Injector S-122 (PTD 2050810) was recently converted to a WAG injector under Sundry #324-268. The well was placed on initial injection on 08/28/24 and passed an AOGCC witnessed MIT-IA on 09/03/24. Shortly after the AOGCC MIT-IA the IAP was bled and since that bleed, the IAP has continued to increase. This indicates the IA re-pressurization is due to TxIA communication. The well will now be classified as UNDER EVALUATION and is on the 28-day clock for diagnostics. Plan forward: 1. DHD: PPPOT-T 2. Slickline: Replace DGLVs with extended packing DGLVs 3. Well Integrity: Monitor for IA re-pressurization/additional diagnostics as needed. 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 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU S-122 Convert to Injection Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 205-081 50-029-23265-00-00 12173 Conductor Surface Intermediate Liner Scab Liner 6732 503 3630 10192 2108 2050 11950 13-3/8" 9-5/8" 7" 4-1/2" 3-1/4" 6751 29 - 532 28 - 3658 26 - 10217 9974 - 12082 9955 - 12005 29 - 532 28 - 3136 26 - 6738 6619 - 6741 6609 - 6747 None 2260 3090 5410 7500 11950 5020 5750 7240 8430 11800 - 11830 4-1/2" 12.6# L80 23 - 9955 6760 - 6758 Structural 80 20" X 34" 30 - 110 30 - 110 770 4-1/2" AHR Packer 9907 6585 Torin Roschinger Operations Manager Tyson Shriver tyson.shriver@hilcorp.com 907-564-4542 PRUDHOE BAY, Aurora Oil Pool Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028257, 0047448 23 - 6609 N/A N/A 17 3 3012 42 800 350 200 3146 324-268 13b. Pools active after work:Aurora Oil Pool No SSSV Installed 9907, 6585 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 10:12 am, Sep 16, 2024 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2024.09.16 06:31:45 - 08'00' Torin Roschinger (4662) DSR-9/25/24 RBDMS JSB 091924 WCB 10-15-2024 ACTIVITY DATE SUMMARY 6/21/2024 ***WELL S/I ON ARRIVAL*** T-BIRD BEGIN LOAD 150bbls CRUDE DOWN TBG (cont on next day) BRUSHING w/ KJ, 2' x 1-7/8'' STEM, 4-1/2'' BLB, 3.80'' G-RING (cont on next day) ***WSR CONT ON 6-22-24*** 6/21/2024 T/I/O=1950/1950/0 TFS Unit 1 Assist Slickline (TBG LOAD) Pumped 76 BBLS out of 155 BBLS to Load the TBG ***JOB CONTINUES*** 6/22/2024 ***WSR CONT FROM 6-21-24*** BRUSHED w/ KJ, 2' x 1-7/8'' STEM, 4-1/2'' BLB, 3.80'' G-RING, BRUSH TIGHT SPOT IN TBG, S/D HIGH @ 8703' SLM, T- BIRD PUMPED 154bbls CRUDE DRIFTED 2' x 1-7/8'' STEM, 3.80'' CENT, 2.50'' SAMPLE BAILER, DRIFT FREELY TO S/D ON XO @ 9930' SLM (no sample) BRUSHED w/ 2.65'' CENT, 2' x 1-7/8'' STEM, 4-1/2'' BLB, B.NOSE, BURSH X-NIPS @ 9907' SLM / 9934' MD & 9858' SLM / 9884' MD, T-BIRD PUMPED 13bbls SET 3.81'' PX-PLUG IN X-NIP @ 9934'MD SET P-PRONG IN PLUG BODY @ 9934'MD SET 4-1/2'' WHIDDON CATCHER SUB ON PRONG @ 9934'MD PULLED BK-DGLV FROM ST#1 @ 9815'MD PULLED ST#4 BK-OGLV FROM 7224' MD (scale on vlv) FAILED ATTEMPT TO PULL ST#5 FROM 4750' MD ***WSR CONT ON 6-23-24*** 6/22/2024 ***JOB CONTINUED from 6-21-2024*** (Assist Slickline with Load & Test) Pumped 168 bbls Crude down TBG for Load & Test. Tested plug to 1500 psi.Passed. Bled TBG down to 500 psi. Bled back 1.1 bbls Pollard SL in control of well upon TFS departure FWHPS=500/1550/0 6/23/2024 ***WSR CONT FROM 6-22-24*** PULLED ST#5 BK-LGLV FROM 4750' MD MADE MULTIPLE ATTEMPTS TO SET ST#5 SET ST#4 BK-DGLV @ 7224'MD SET ST#5 BK-DGLV @ 4750'MD SET ST#1 BK-FLOWSLEEVE @ 9815'MD ***WHIDDON CATCHER SUB LIH***(WCS-44) ***WELL LEFT S/I ON DEPARTURE*** 7/7/2024 T/I/O=1000/1400/0 (Circ Out) Pumped 1 bbl of 50/50 followed by 198 bbls of 1% KCL down the TBG taking returns up the IA to S-100 flowline to circ out well *Job continues to 7-8-24* 7/8/2024 *Job continues from 7-7-24 (Circ Out) Pumped 295 bbls of 2% KCL with corrosion inhibator down the TBG still taking returns up the IA to S-100 flowline. Followed KCL with 86 bbls of DSL down the TBG to freeze protect. Allowed TBG to U-tube to IA for ~1 hour. Pumped 5 bbls of DSL down the flowline of S-100 to freeze protect. Flags and tags hung. PO notified of well status FWHPS=600/600/0 SV/WV/SSV=C MV=O I/O=OTG Daily Report of Well Operations PBU S-122 Pumped 295 bbls of 2% KCL with corrosion() inhibator down the TBG still taking returns up the IA to S-100 flowline. Followed KCL g with 86 bbls of DSL down the TBG to freeze protect. Allowed TBG to U-tube to IA for ~1 hour. PULLED ST#5 BK-LGLV FROM 4750' MD MADE MULTIPLE ATTEMPTS TO SET ST#5 SET ST#4 BK-DGLV @ 7224'MD@ SET ST#5 BK-DGLV @ 4750'MD@ SET ST#1 BK-FLOWSLEEVE @ 9815'MD @ SET 3.81'' PX-PLUG IN X-NIP @ 9934'MD@ SET P-PRONG IN PLUG BODY @ 9934'MD@ SET 4-1/2'' WHIDDON CATCHER SUB ON PRONG @ 9934'MD PULLED BK-DGLV FROM ST#1 @ 9815'MD@ PULLED ST#4 BK-OGLV FROM 7224' MD (scale on vlv)( FAILED ATTEMPT TO PULL ST#5 FROM 4750' MD Daily Report of Well Operations PBU S-122 7/12/2024 ***WELL S/I ON ARRIVAL*** RIH TO PULL ST# 1 @ 9,815' MD ***CONT ON 7/13/2024*** 7/12/2024 (TFS unit 1 assist SL) Travel to location, Spot in unit, SB for SL ******WSR Continue on 12-13-2024****** 7/13/2024 ***CONTINUED FROM 6/12/24*** MADE MULTIPLE ATTEMPTS TO PULL BK-FLOWSLEEVE FROM ST#1 @ 9815'MD PULLED ST#1 BK-FLOWSLEEVE FROM 9815'MD SET BK-DGLV IN ST#1 @ 9815'MD PRESSURE TUBING UP TO 1000PSI, IA NOT TRACKING ***CATCHER LEFT IN HOLE*** ***WELL LEFT S/I ON DEPARTURE*** 7/13/2024 *******WSR Continued from 7-12-2024******** T/I/O = 214/285/0 Temp S/I (TFS unit 1 Assist SL with MIT-T and MIT-IA) MIT's postponed. Pumped .5 bbls DSL down TBG to reach test pressure of 1020 psi on TBG. Test passed per SL. Pollard SL in control of well upon TFS departure FWHPS = 800/348/0 7/13/2024 T/I/O = 863/411/0 Temp = SI MIT-T PASSED at 3457 psi, MIT IA PASSED to 3493 psi (Injection Conversion) Pumped 1.5 bbls of DSL down the TBG to reach a max applied psi of 3520 psi. 1st 15 min TBG lost 63 psi, 2nd 15 min TBG lost 22 psi for a total loss of 85 in a 30 min test. Bled TBG to 300 psi bleeding back .7 bbls. Rig up to IA Pumped 1 bbls of DSL down the IA to reach a max applied psi of 3520 psi. 1st 15 min IA lost 37 psi. 2nd 15 min IA lost 5 psi for a total loss of 42 psi in a 30 min test. Bled IA down to 105 psi bleeding back 2 bbls. Final WHPS 300/110/0 Tags hung and DSO notified of completion of job. 7/17/2024 T/I/O= 153/155/2 AOGCC MIT-T PASSED to 3374 psi, AOGCC MIT -IA PASSED to 3400 psi. (Witnessed by AOGCC Inspector Austin McLeod) Pumped 2.1 bbls of diesel down tubing to achieve test pressure of 3480 psi. 1st 15-minute loss of 79 psi, 2nd 15-minute loss of 27 psi, for total loss of 106 psi in 30 minutes. Bled back ~1.6 bbls. Pumped 2.6 bbls of diesel down IA to achieve test pressure of 3467 psi. 1st 15- minute loss of 54 psi, 2nd 15-minute loss of 13 psi, for a total loss of 67 psi in 30 minutes. Bled back ~1.6 bbls. FWHPs= 195/200/2 Valve Positions - SV/WV/SSV/AL= Closed, MV= Open, IA/OA= OTG 7/22/2024 ***WELL S/I ON ARRIVAL*** PULL WHIDDON CATCHER @ 9'898 SLM PULL P-PRONG @ 9'902 SLM ***CONTINUE TO 7/23/24*** 7/23/2024 ***CONTINUE FROM 7/22/24*** PULLED PX PLUG BODY FROM 9,934' MD ***WELL S/I ON DEPARTURE*** 8/24/2024 T/I/O=SI/250/0. SSV repair. Removed 4" LEO actuator barrel for repair. ***Job in Progress*** Final WHP's SI/250/0. 8/25/2024 T/I/O=SI/250/0. SSV repair. Installed 4" LEO actuator barrel post repair. ***Job Complete*** Final WHP's SI/250/0. AOGCC MIT-T PASSED to 3374 psi, AOGCC MIT -IA PASSED to 3400 psi. (Witnessed by AOGCC Inspector Austin McLeod) Pumped 2.1 bbls of(y ) diesel down tubing to achieve test pressure of 3480 psi. 1st 15-minute loss of 79 psi,g 2nd 15-minute loss of 27 psi, for total loss of 106 psi in 30 minute PULLED ST#1 BK-FLOWSLEEVE FROM 9815'MD SET BK-DGLV IN ST#1 @ 9815'MD Daily Report of Well Operations PBU S-122 9/1/2024 T/I/O = 3200/1800/70. Temp = 125*. Bleed IAP to 0 psi (Pre MIT). On MI. IA FL @ surface. Bled IAP to BT to 0 psi in 45 mins (gas/energized fluid, 3.9 bbls). OAP decreased 30 psi. No monitor. Final WHPs = 3200/VAC/40. SV = C. WV, SSV, MV = O. IA, OA = OTG. 17:00 9/3/2024 T/I/O = 3125/63/79 AOGCC MIT-IA (ANN-COMM) **PASSED** Witnessed by: StJohn Max applied:2500 / Target: 1800 Pumped 3.2 bbls of 85 *F DSL down IA to reach max pressure of 2520 psi. After first 15 min IA lost 38 psi. After second 15 min IA lost 3 psi. Bled back 3 bbls. Pad Op notified upon departure. FWHP = 3123/70/77 AOGCC MIT-IA (ANN-COMM) **PASSED** Witnessed by: () y StJohn Max applied:2500 / Target: 1800 Pumped 3.2 bbls of 85 *F DSL down IA tog reach max pressure of 2520 psi. After first 15 min IA lost 38 psi. After second 15 min IA lost 3 psi. 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 S-122 (PTD #2050810) possible TxIA communication Date:Friday, September 13, 2024 9:29:57 AM Attachments:S-122.pdf From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, September 12, 2024 3:26 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: WAG Injector S-122 (PTD #2050810) possible TxIA communication Mr. Wallace, Injector S-122 (PTD 2050810) was recently converted to a WAG injector under Sundry #324-268. The well was placed on initial injection on 08/28/24 and passed an AOGCC witnessed MIT-IA on 09/03/24. Shortly after the AOGCC MIT-IA the IAP was bled and since that bleed, the IAP has continued to increase. This indicates the IA re-pressurization is due to TxIA communication. The well will now be classified as UNDER EVALUATION and is on the 28-day clock for diagnostics. Plan forward: 1. DHD: PPPOT-T 2. Slickline: Replace DGLVs with extended packing DGLVs 3. Well Integrity: Monitor for IA re-pressurization/additional diagnostics as needed. 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 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 00$24 062&24 07l0324 0711D24 0T1T24 07124J24 well: 5-122 0713124 0&'0724 0&'14124 0&21�24 0812&24 09A 24 09i 11 r24 300 290 280 270 260 250 240 230 220 210 200 190 130 170 160 3 150 m 140 C 130 m 120 110 100 90 80 70 60 50 40 30 20 10 TIO Plo f Tubini —On ■ Bleed * Opera + Not OI ♦ Under f Man. I —A Man. ( - - Man. ( �— Man. ( r Man.I WELLHEAD=FMC ACRIATOR= OKB. ELB/ = 64.25 BF. E-EV = 35-T KOP= 300' Max Angle = 99" @ 11200' Datum MD = 12257' DatumTVD= 6600'SS L-80 GRAVEL STRING WELL SEE PAGE 2 S-1 22 20" X 34" COND, 215.5#, A-53, D= " FC, ID = 12.415" ITCH Minimum ID = 2.378" @ 11911' 3-3/16" X 2-7/8" 1 532' 1 L-00 JFE BEAR, .0152 bpf, ID = 3.958" 1 9955' BKRWHPST0CK(08/12105) 10217" 3G. 26#. L-00 BTC. D = 6276' PERFORATION SUMMARY REF LOG: MWD ON 08/17/05 ANGLE AT TOP PERF: 94° @ 11800' Note: Refer to Production DB for historical rfdata SIZE SPF INTERVAL OprVSqz DATE 2412" 6 10220 -10250 S 072123 2-12" 6 10300-10440 S 072123 2-12" 6 10500 -10550 S 072123 2-12" 6 10600 -10650 S 072123 2-12" 6 10700 -10750 S 072123 2-12" 6 10890 -10940 S 072123 2-12" 6 10980 -11070 S 072123 2-12" 6 11120 -11270 S 072123 2-12" 6 11350 -11400 S 072123 2-12" 6 11450 -11550 S 072123 2-12" 6 11600 -11750 S 072123 2-12" 6 11800 -12030 S 072123 2-12" 6 11800-11830 O 072123 3-1/4- LNR, 6.4#, L-80 TCIL .0076 bpf, ID = 2.805' 11 111' 2-7/8" LNR, 6.4#, LA0 STL, .0058 bpf, ID = 2.441' 12005 4-12- LNR I I AN, L-00 LTC, .0149 bpf, D = 3.958' 12039' PBTD 1203W 4-12' LNR, 12.6#, L-8O, .0152 bpf, D = 3.958' 12082' SAFETY NOTES: DISCREPANCIES IN 4-12" LNR TALLY WEIGHT & PIPE DESCRIPTIONS - PLEASE REVIEW TALLY FOR MORE DETAILS. WELL ANGLE> 70" @ 10269'. 2251' I4-12' HES X NP, D = 3 813' GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 4750 3748 54 KBG2 DMY BK 0 062324 4 7224 5101 56 KBG2 DMY BK 0 062324 3 8750 5951 57 KBG2 DMY BK 0 062324 2 9746 6502 59 KBG2 DMY BK 0 0713123 1 9815 6537 59 KBG2 DMY BK 0 07/1324 9$$4' 4-12" HES X NIP, D = 3.813" 990E 7' X 4-12' AHR PKR, D = 3.863- 9934' 4-12- HES X NIP, D = 3.813- 9955' —14-12" X 3.3/16' XO, D = 2.804' 9974' 7" X 5" BKR ZXP LNR TOP PKR & HMC LNR HNGR, D = 4.40" END TT NOT LOGGBD 9998' 5' X 4-12' XO, D = 3.950' MILL0UT 7" CSG WINDOW 10217' - 10229' I RA TAG w/SHORT JOINT. D = 3.91- 114�y RA TAG w/SHORT JOINT, D = 3.91" 11911' —� 13/16- X 2-718" XO, D = 2.378- 1- 12005' 1--12-7/8-MULESHOE, 9)=2A41" DATE REV BY COMMENTS DATE REV BY COMMENTS 08r21/05 LV ORIGINAL COMPLETION 102623 CK/JMD GLV C 0 10/1123 06/1923 TB1 INTERVENTIONS RWO 0710124 CK/J D GLV C/O 062324 062123 JMD UDPATED WBS 07/1824 CK/JMD GLV C/O 07/1324 0713123 JCF/JMD FINALIZED 08/0123 JMGIJMD GLV C/O 07/3123 09/1123 JKC/JMD GLV C/O 09/0523 AURORA UNIT WELL: S-122 PERMIT No:'k50810 API No: 50-029-23265-00 Hilcorp North Slope, LLC MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, August 30, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC S-122 PRUDHOE BAY UN AURO S-122 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/30/2024 S-122 50-029-23265-00-00 205-081-0 N SPT 6585 2050810 3200 558 1004 1023 1027 2 2 2 2 OTHER P Austin McLeod 7/17/2024 MITIA for injector conversion. Sundry 324-268. 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 AURO S-122 Inspection Date: Tubing OA Packer Depth 526 3467 3413 3400IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM240718135714 BBL Pumped:2.6 BBL Returned:1.6 Friday, August 30, 2024 Page 1 of 1 9 9 9 9 9 9 99 9 9 9 9 9 9 9 9 9 9 injector conversion James B. Regg Digitally signed by James B. Regg Date: 2024.08.30 14:55:32 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, August 30, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC S-122 PRUDHOE BAY UN AURO S-122 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/30/2024 S-122 50-029-23265-00-00 205-081-0 N SPT 6585 2050810 3200 528 3480 3401 3374 2 2 2 2 OTHER P Austin McLeod 7/17/2024 MITT for injector conversion. Sundry 324-268. 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 AURO S-122 Inspection Date: Tubing OA Packer Depth 532 804 807 806IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM240718135320 BBL Pumped:2.1 BBL Returned:1.6 Friday, August 30, 2024 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 MITT for injector conversion James B. Regg Digitally signed by James B. Regg Date: 2024.08.30 14:57:20 -08'00' 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in this pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By: Date: APPROVED BY THE AOGCCCOMMISSIONER PBU S-122 Convert to Injection, Extended Perf w CTU Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 205-081 50-029-23265-00-00 457B ADL 0028257, 0047448 12173 Conductor Surface Intermediate Liner Scab Liner 6732 503 3630 10192 2108 2050 11950 13-3/8" 9-5/8" 7" 4-1/2" 3-1/4" 6751 29 - 532 28 - 3658 26 - 10217 9974 - 12082 9955 - 12005 2448 29 - 532 28 - 3136 26 - 6738 6619 - 6741 6609 - 6747 None 2260 3090 5410 7500 11950 5020 5750 7240 8430 11800 - 11830 6760 - 6758 4-1/2" 12.6# L80 23 - 9955 Structural 80 20" X 34" 30 - 110 30 - 110 770 4-1/2" AHR Packer No SSSV Installed 9907, 6585 Date: Torin Roschinger Operations Manager Leslie Manning lreavis@hilcorp.com 907-777-8326 PRUDHOE BAY 5/17/2024 Current Pools: AURORA OIL Proposed Pools: AURORA OIL Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 12:53 pm, May 03, 2024 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2024.05.03 12:11:14 -08'00' Torin Roschinger (4662) 10-404 MGR03MAY23 SFD 5/3/2024 Convert to Injection DSR-5/6/24 * Confirmation of cement across the confining zone confirmed in previous well work fracturing sundry. Perforate 2448 JLC 5/6/2024 The Kuparuk reservoir interval is cement-isolated. A detailed description of casing and cementing can be found in Sundry Application 323-441 for hydraulic fracturing of PBU S-122. SFD 5/3/2024 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 S-122 205081 500292326500 5 9/19/2023 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 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU S-122 Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 205-081 50-029-23265-00-00 12173 Conductor Surface Intermediate Liner Scab Liner 6732 533 3630 10192 2108 2050 11950 13-3/8" 9-5/8" 7" 4-1/2" 3-1/2" 6750 29 - 562 28 - 3658 26 - 10217 9974 - 12082 9955 - 12005 29 - 561 28 - 3136 26 - 6738 6619 - 6741 6609 - 6747 None 2260 3090 5410 7500 11950 5020 5750 7240 8430 11800 - 11830 4-1/2" 12.6# L80 23 - 9955 6760 - 6758 Structural 80 20" X 34" 29 - 109 29 - 109 770 4-1/2" AHR Packer 9907, 6585 9907 6585 Aras Worthington for Torin Roschinger Operations Manager Marshall Brown henry.brown@hilcorp.com 907-777-8419 PRUDHOE BAY, AURORA OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028256, 0028257, 0047448 23 - 6609 Perforations from 11800 - 11830'MD See Attached Fracture Stimulation Reports 85 50 43 2315 3200 73 1625 800 233 200 323-441 13b. Pools active after work:AURORA OIL No SSSV Installed STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 2:19 pm, Nov 02, 2023 Digitally signed by Aras Worthington (4643) DN: cn=Aras Worthington (4643) Date: 2023.11.02 13:21:07 -08'00' Aras Worthington (4643) RBDMS JSB 110823 WCB 4-26-2024 CDW 11/07/2023 DSR-11/2/23 ACTIVITY DATE SUMMARY 9/4/2023 ***WELL S/I ON ARRIVAL*** SET 4-1/2" WHIDDON @ 9,955' MD ***CONTINUE 9/5/23*** 9/5/2023 T/I/O=300/521/0 (Assist Slickline) TFS U3. Pumped 175 bbls of 2% KCL down the IA to load for slickline, followed KCL load with 46 bbls of DSL to freeze protect IA to 2500'. Pumped 3 bbls of 60/40 followed by 11 bbls of 2% KCL to attempt TBG laod, Formation not taking fluids KCL TBG load scrapped by WSL. Pumped 40 bbls of DSL down the TBG to freeze protect TBG to 2500'. Pumped 5 bbls of DSL down the FL to FP, *Job continues to 9-6-23* 9/5/2023 ***CONTINUE FROM 9/4/23*** PULL STA. # 1 BK-DGLV @ 9,815' MD SET STA. # 1 BK-FLOSLEEVE @ 9,815' MD T-BIRD LOADED IA w/ 172 bbls KCL & 46 bbl DIESEL FREEZE PROTECT PULL BK-FLOWSLEEVE FROM ST#1 @ 9,815' MD SET BK-DGLV IN ST#1 @ 9,815' MD PULL WHIDDON FROM XO @ 9,955' MD THUNDERBIRD PUMPED 3 BBLS 60/40, 8 BBLS KCL & 40 BBL DIESEL FREEZE PROTECT SET PX PLUG BODY @ 9,884' MD ***CONTINUE 9/6/23*** 9/6/2023 *Job continues from 9-5-23* (Assist Slickline/MIT-T, MIT-IA) TFS U3. Pumped 2.5 BBLS of DSL down the TBG to pressure up for an MIT-T MAP @ 3500 psi. Reached test pressure at 3490 psi. First 15 minutes TBG lost 125 psi. Second 15 minutes TBG lost 43 psi. ****PASSED**** Bleed back 2 bbls to bring TBG to 1000 psi for an MIT-IA. Pumped 3 bbls of DSL down the IA for an MIT-IA MAP @ 3750 psi. Reached test pressure at 3744 psi. First 15 minutes IA lost 62 psi. Second 15 minutes IA lost 11 psi. ****PASSED****. Bled back 3 bbls of DSL to bring IA to 500 psi. FWHPS=1050/500/0. Well left in control of slickline upon departure 9/6/2023 Injectivity Test (FRACTURING) Pumped 1 bbl DSL in IA to take IA to 1000 psi. Pumped 173 bbls crude down Tbg for load. Pumped 50 bbls crude on injectivity test. Got an injectivity of 5 bpm @ ~3000 psi. Pad Op notified of well status per LRS departure. SV,WV,SSV=C MV=O IA,OA=OTG 9/6/2023 ***CONTINUE 9/5/23*** SET P-PRONG @ 9,884' MD PERFORM PASSING MIT-T 3500 psi W/ THUNDERBIRD PERFORM PASSING MIT-IA 3500 psi W/ THUNDERBIRD PULL P-PRONG @ 9,884' MD PULL 4-1/2" PX PLUG BODY @ 9,884' MD BLEED IA TO 500 PSI ***WELL LEFT SHUT IN ON DEPARTURE*** 9/8/2023 T/I/O 500/955/0 LRS Unit 72 (FRACTURING) Pump Injectivity Test Pumped 260 bbls of 1% KCL down TBG, (Injectivivty rate was 5 bpm @ 2400 psi), Pumped 40 bbls of crude to FP TBG. RDMO. SV, WV = closed, SSV, MV = open, IA and OA = OTG, GLV = Closed. FWHP's = 1500/907/4 Daily Report of Well Operations PBU S-122 @ PERFORM PASSING MIT-T 3500 psi W/ THUNDERBIRD PERFORM PASSING MIT-IA 3500 psi W / THUNDERBIRD Daily Report of Well Operations PBU S-122 10/3/2023 Job Scope: S-122 Fracture Stimulation: Mobilize Frac Equipment to S-Pad. Spot frac tanks, sand chief, PCM, POD, and pumps. Lynden sifting and loading 84,640 lbs of16/20 CBL in yard, transporting, and offloading proppant to sand chief on location. Well Support rigged up wellhead equipment and tied in P-Sub and IA to choke trailer and PRV skid. SLB begin rigging up surface lines. .....Continued on 10/4/23 WSR 10/4/2023 Job Scope: Post RWO Frac T-reatment. Spot (5) 500 bbl Frac tanks. Lynden loading screened 16/20 CarboBond Lite Frac Sand. Finish Spot Frac Pumps, Frac Manifold (Missle), & POD Blender. Sand loading complete. Total 202K Loaded. Start loading fresh water in Frac tanks. Rig up Oil States Tree saver. Job in Progress. 10/5/2023 Job Scope: Post RWO Frac T-reatment. Finish loading frac tanks Total 2000 bbls. Continue rigging up treating Iron to pumps and SLB Missle. Connect electronics in the Frac Cat Mod. Pull water sample from each Frac Tank for testing. LRS heated diesel from transpor. SLB discovered diesel leak under the Frac Cat Module, notified the Pad op and SRT. Est 2-3 gal diesel to ground from failed fuel line on generator. RU LRS pump truck to the IA. PT the PRV to 3550. RU OA for monitoring. Start and warm up Frac equipment. Trouble shooting Frac pump #4. Unable to get started. Decision made to replace pump. SLB bringing pump from deadhorse. Frac Job will continue tomorrow morning. Job In Progress 10/5/2023 RU to tanker Circulate to heat from 30* to 90*. Test PRVs to 3550 PSI, Job Postponed. SLB on locatin upon departure 10/6/2023 Job Scope: Post RWO Frac T-reatment. Frac crew on location, warming equipment. LRS rigged up to IA. Verify PRV set to 3550 psi. . Prime pumps and frac system. Heat diesel. , Pressure Test Treating lines to 7K - good. Test Global kickout & N2 PRV. Pump single stage Frac Treatment per pump scheduel. Pump Injection/Data frac. Screened out when 3 ppa hit the perfs. Screened out all the way back to the POD. Leaving ~30K of 16/20 CBond Lite sand in the well & roughly 14K lb of 16/20 CBond Lite behind pipe. Cleaned out surface lines with diesel. Attempted to get some FP in the well. Pumped roughly 3bbls into the well. Rigged down Frac standpipe and cleared out of the way. Pulled and Rigged down Oil States Tree saver. Secured the well, removed the fusible cap on the SSV & returned to normal condition. Face to Face with the Pad operator, informed him of the status of the frac and the condition of the well before leaving. Job complete for Frac Portion 10/6/2023 Assist Frac Crew. hold IAP as required by frac crew. FWHP=0/500/0 Casing valves OTG, SLB on location upon departure 10/7/2023 LRS Unt # 2 1.75" (Blue Coil) CT .156" WT Scope; Post Frac FCO 10/7/2023 LRS CTU# 2 1.75" (Blue Coil) CT .156" WT Scope; Post Frac FCO MIRU CTU. RIH w/ 2" Ball Drop Nozzle. Establish Reverse circulating. Start seeing sand returns at 1400' nozzle depth. Cleanout to 4076'. Continue to FCO on 10-8-23. ***Continue job on 10/8/23*** Lynden sifting and loading 84,640 lbsyg g of16/20 CBL in yard, transporting, and offloading proppant to sand chief on location gg j Screened out when 3 ppa hit the perfs. Screened out all the way back to they POD. Leaving ~30K of 16/20 CBond Lite sand in the well & roughly 14K lb of 16/20 g CBond Lite behind pipe Daily Report of Well Operations PBU S-122 10/8/2023 LRS CTU#2 1.75" Blue Coil. Job Scope: FCO - Post Frac Continue reverse FCO from 4076'. Reverse FCO down to 11900' CTM. See less returns beginning around 11775' - 11780'. 15 bbl/hour losses increased to 30 bbl/hour losses once passed 11800'. Pump rate 1.5 bpm. Out Return Density ranged from normal KCL at 8.4 ppg up to 9.3 ppg at the highest. Swapped over to conventional circulation (down coil) @ 10100'. Pump 10 bbl PowerVis Gel Sweep @ 2.5 bbl/min. Returns now 1:1 with 350 psi WHP on choke. Jet all GLMs on trip OOH. Park at 2500'. Perform injectictivity test with diesel down CTBS. 1 bpm = 1680 psi WHP. 1.5 bpm = 2200 psi WHP 2 bpm = 2400+ psi WHP. Pressure did not fully stabilize at the 2 bpm rate. Slowly climbed, did not exceed 2475 psi WHP. POOH, with Diesel FP in tubing, 38 bbls. Pump 1.188" drift ball down coil with diesel at surface to tanks. Recover Ball. RDMO. Final T/I/O 521/97/0 ***Job Complete*** 10/10/2023 *** WELL S/I ON ARRIVAL*** RAN 2.76'' CENT, 1.75'' S.BAILER (cont on next day) ***WSR CONT ON 10-11-23*** 10/11/2023 ***WSR CONT FROM 10-10-23*** DRIFTED 2.76'' CENT, 1.75'' S.BAILER, DEVIATE OUT @ 10,300' SLM (no sample) SET 4-1/2'' WIDDONN CATCHER ON XO @ 9,955' MD PULLED BK-DGLV FROM ST#4 @ 7,224' MD MAKE SEVERAL ATTEMPTS TO PULL ST#5 @ 4,750' MD BRUSH w/ 4-1/2'' BLB, 3.50" G-RING. MAKE SEVERAL BRUSH PASSES BY ST#4 & ST#5 SET BK-SO GLV IN ST#4 @ 7,224' MD RAN KJ,4-1/2" OMK, JK RUNNIG TOOL (pinned) TO ST#5 @ 4,750' MD (tattletale pins sheared) PULLED ST#5 BK-DGLV FROM 4,750' MD SET ST#5 BK-LGLV (16/64'' ports, tro 1500#) @ 4,750' MD ***WSR CONT ON 10-12-23*** 10/12/2023 ***WSR CONT FROM 10-11-23*** PULLED 4-1/2'' WHIDDON CATCHER FROM 9,955' MD ***JOB COMPLETE, WELL LEFT S/I*** 10/15/2023 LRS Test Unit # 1, Begin WSR, IL Well S-122 / OL wWell S-100, Frac flow back/ clean out, Unit move, Begin RU, Continued to 10/16/23 WSR 10/16/2023 LRS Test Unit # 1, Continued from 10/15/23 WSR, IL Well S-122 / OL Well S-100, Frac flow back/ clean out, Continue RU, PT, POP, Continue to 10/17/23 WSR 10/17/2023 LRS Test Unit # 1, Continued from 10/16/23 WSR, IL Well S-122 / OL Well S-100, Frac flow back/ clean out, Flowback, Continue to 10/18/23 WSR 10/18/2023 LRS Test Unit # 1, Continued from 10/17/23 WSR, IL Well S-122 / OL Well S-100, Frac flow back/ clean out, Flowback, Continue to 10/19/23 WSR 10/19/2023 LRS Test Unit # 1, Continued from 10/18/23 WSR, IL Well S-122 / OL Well S-100, Frac flow back/ clean out, Flowback, Continue to 10/20/23 WSR 10/20/2023 LRS Test Unit # 1, Continued from 10/19/23 WSR, IL Well S-122 / OL Well S-100, Frac flow back/ clean out, Continue purge, 4HR Piggy Back Test, BD, Begin RD, Stop due to scheduling, End WSR Daily Report of Well Operations PBU S-122 10/21/2023 LRS Test Unit # 1, Begin WSR, Continued from 10/20/23 WSR, IL Well S-122 / OL Well S-100, Frac flow back/ clean out, Finish RD, Stop due to scheduling, End WSR 10/21/2023 LRS Test Unit # 1, Begin WSR, IL Well S-122 OL Well S-100, Continue RD, RD Complete, End WSR x FracCAT Treatment Report Well : S-122 Field : Aurora Formation : Kuparuk C Well Location : Greater Prudhoe Bay County : North Slope Borough State : Alaska Country : United States Prepared for Client : Hilcorp North Slope, LLC Client Rep : Anthony Knowles Date Prepared : 06-Oct-23 Prepared by Name : Alena Lutskaia Division : Schlumberger Phone : 630 780 0058 Pressures Initial Wellhead Pressure (psi)140 Surface Shut in Pressure(psi)6,511 Maximum Treating Pressure (psi)6,511 Injection Test ISIP (psi)1,452 Average Treating Pressure (psi)4,271 ISIP (psi)SO Treatment Totals Total Slurry Pumped (Water+Adds+Proppant) (bbl)1143.3 Total Proppant Pumped (lbs.); FracCat Totals 44,270 Total Crosslink Fluid (bbl) 879.6 Total BH Proppant Pumped (lbs.); FracCat Totals 14,318 WF128 for Injection Test (bbl)181.6 Total Chemical Additives Invoiced Past WH Invoiced Past WH F103 (gal)50 49.3 J134 (lb)10 0 L065 (gal)52 51.3 J475 (lb)110 105.7 L071 (gal)93 91.6 J580 (lb)1534 1278.8 J532 (gal)128 126.2 Diesel (bbl)0 41.8 S123 (gal)0 0 M275 (lbs)30 30 Disclaimer Notice This information is presented in good faith, but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment. The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the model, the assumptions and such input data. The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values. The quality of input data, and hence results, may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue. Actual charges may vary depending upon time, equipment, and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. 6,511 Client: HilcorpNorth Slope, LLC Well: S-122 Formation: Kuparuk c Country: United States Injection Prior to the main job, an injection test was performed, and the pressure decline was monitored for about 40 minutes. There were no hammer effect after well shut in. The selected fluid was WF128 (linier gel), ISIP is 1,452 psi. Based on the data, the decision was made to continue job according to initially designed schedule. The treatment plot for the injection is below: 12:03:22 12:24:12 12:45:02 13:05:52 13:26:42 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 6000 Pressure - psi0 5 10 15 20 25 30 35 40 45 50 Rate - bbl/min0 0.5 1.0 1.5 2.0 2.5 3.0 Prop Con - PPATreating Pressure Annulus Pressure Slurry Rate Prop Conc BH Prop Con DF Treatment Hilcorp S122, Stage 1 10-06-2023 Section 1: As Measured Pump Schedule As Measured Pump Schedule Step #Step Name Slurry Volume (bbl) Slurry Rate (bbl/min) Pump Time (min) Fluid Name Fluid Volume (gal) Proppant Name Max Prop Conc (PPA) Prop Conc (PPA) Prop Mass (lb) 1 Displace WB 20.5 4.8 4.8 Freeze Protect 860 0.0 0.0 0 2 Shutdown 0.0 0.0 0.0 -0 0.0 0.0 0 3 Injection 181.6 20.1 11.0 WF128 7628 0.0 0.0 0 4 Shutdown 0.0 0.0 0.0 -0 0.0 0.0 0 Injection Test Plot Injection testFreeze Protect Client: HilcorpNorth Slope, LLC Well: S-122 Formation: Kuparuk c Country: United States Stage Pressures & Rates Step #Step Name Average Slurry Rate (bbl/min) Maximum Slurry Rate (bbl/min) Average Treating Pressure (psi) Maximum Treating Pressure (psi) Minimum Treating Pressure (psi) 1 Displace WB 4.8 5.4 2368 2463 39 2 Shutdown 0.0 0.0 2368 1593 1587 3 Injection 20.1 24.4 4114 5089 839 4 Shutdown 0.0 0.0 4114 1455 1455 As Measured Totals Slurry (bbl) Pump Time (min) Clean Fluid (gal) Proppant (lb) 202.1 15.8 8488 0 Average Treating Pressure:3049 psi Maximum Treating Pressure:5110 psi Minimum Treating Pressure:264 psi Average Injection Rate:12.9 bbl/min Maximum Injection Rate:24.5 bbl/min Average Horsepower:1242.9 hhp Maximum Horsepower:2839.8 hhp Maximum Prop Concentration:0.0 PPA Section 2: Job Messages Message Log #Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 1 9:08:34 Start Priming With Diesel 31 246 0.0 0.0 0.0 2 9:48:19 Test Trips 1406 245 0.0 0.0 0.0 3 9:50:47 Mid Test 3502 246 0.0 0.0 0.0 4 9:58:29 High Pressure Test 7129 245 0.0 0.0 0.0 5 12:08:18 Open Well 161 170 0.0 0.0 0.0 6 12:08:32 Start Displace WB Automatically 104 177 0.0 0.0 0.0 7 12:08:47 Started Pumping 40 173 0.0 0.0 0.0 8 12:15:47 Stopped Pumping 1578 4504 20.5 0.0 0.0 9 12:15:47 Shutdown for 10 min 1578 4504 20.5 0.0 0.0 10 12:25:08 Started Pumping 849 1533 20.5 0.0 0.0 11 12:25:13 Start Injection Manually 845 1531 20.5 0.0 0.0 12 12:36:37 Stopped Pumping 1453 2880 202.1 0.0 0.0 13 12:36:37 Monitoring Pressure Decline 1453 2880 202.1 0.0 0.0 Client: HilcorpNorth Slope, LLC Well: S-122 Formation: Kuparuk c Country: United States Main Treatment Overall, the stage treated with some pressure increases/decreases which eventually led to screen out (SO). Treating pressure was generally at Pad stage declining at the same level around 4350-4500 psi until the 1 PPA started going into formation, then pressure behavior changed. At this point pressures started increasing on surface to 5060 psi, then it decreased to 4550psi. Once 2 PPA went through perforation there was a pressure spike to 4730 psi. Next, once 3ppa went through perforation there was a pressure spike to 5250 psi which led to pump kickout activation on one pump and then pressure suddenly increased to GORV (N2 POP-off) activation. SO occurred. At this point, the pressure decline was monitored, and an attempt was made to flush the surface lines of proppant. This attempt failed and the well was shut in for some time. The shut in pressure was 4,808 psi. Next, the decision was made to try to pump Freeze protect as much as it would be possible by surging the well and pumping freeze protect after (8 attempts). The shut in pressure was 3,088 psi. There were not any major equipment issues during the job. There was one issue at the PAD stage with a pump #5. The possible problem was connected to power end issues. The decision was made to drop the rate of pump #5 and recover rate from remaining 4 pumps. Moving forward, the power end will beinspected before the next job. 13:16:16 13:28:46 13:41:16 13:53:46 14:06:16 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 6000 7000 8000 Pressure - psi0 5 10 15 20 25 30 Rate - bbl/min0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Prop Con - PPATreating Pressure Annulus Pressure Slurry Rate Prop Conc BH Prop Con Main Treatment Hilcorp S 122, Stage 1 10-06-2023 0 Pump#1 loss 2 PPA at BH 3 PPA at BH pump kickout at max Trip Pressure Client: HilcorpNorth Slope, LLC Well: S-122 Formation: Kuparuk c Country: United States Section 3: As Measured Pump Schedule As Measured Pump Schedule Step #Step Name Slurry Volume (bbl) Slurry Rate (bbl/min) Pump Time (min) Fluid Name Fluid Volume (gal) Proppant Name Max Prop Conc (PPA) Prop Conc (PPA) Prop Mass (lb) 1 Pad 100.0 18.8 6.3 YF128ST 4183 0.0 0.0 0 2 0.5 PPA 100.2 25.0 4.0 YF128ST 4123 16/20 CarboBOND Lite 0.7 0.5 1877 3 Pad 300.0 24.0 12.5 YF128ST 12596 16/20 CarboBOND Lite 0.5 0.0 102 4 1.0 PPA 170.2 24.9 6.8 YF128ST 6857 16/20 CarboBOND Lite 1.0 1.0 6569 5 2.0 PPA 50.1 24.9 2.0 YF128ST 1941 16/20 CarboBOND Lite 2.1 1.9 3656 6 3.0 PPA 49.8 24.9 2.0 YF128ST 1855 16/20 CarboBOND Lite 3.0 2.9 5372 7 4.0 PPA 49.4 24.9 2.0 YF128ST 1771 16/20 CarboBOND Lite 4.0 3.9 6879 8 5.0 PPA 50.1 24.9 2.0 YF128ST 1728 16/20 CarboBOND Lite 5.1 4.9 8451 9 6.0 PPA 50.6 24.9 2.0 YF128ST 1686 16/20 CarboBOND Lite 6.0 5.9 9929 10 7.0 PPA 5.9 15.9 1.3 YF128ST 204 16/20 CarboBOND Lite 8.8 7.1 1436 11 Freeze Protect 14.9 0.8 21.3 Freeze Protect 625 0.0 0.0 0 Stage Pressures & Rates Step #Step Name Average Slurry Rate (bbl/min) Maximum Slurry Rate (bbl/min) Average Treating Pressure (psi) Maximum Treating Pressure (psi) Minimum Treating Pressure (psi) 1 Pad 18.8 24.5 3622 4206 555 2 0.5 PPA 25.0 25.1 4280 4355 4188 3 Pad 24.0 25.0 4276 4553 3865 4 1.0 PPA 24.9 25.0 4450 4558 4381 5 2.0 PPA 24.9 24.9 4454 4609 4372 6 3.0 PPA 24.9 25.0 4719 4904 4599 7 4.0 PPA 24.9 25.0 4872 5071 4701 8 5.0 PPA 24.9 25.0 4606 4693 4542 9 6.0 PPA 24.9 24.9 4641 4859 4531 10 7.0 PPA 15.9 24.8 4534 6511 39 11 Freeze Protect 0.8 1.2 4206 5886 24 As Measured Totals Slurry (bbl) Pump Time (min) Clean Fluid (gal) Proppant (lb) 941.2 55.9 37569 44270 Average Treating Pressure:4271 psi Maximum Treating Pressure:6511 psi Minimum Treating Pressure:24 psi Average Injection Rate:22.9 bbl/min Maximum Injection Rate:25.1 bbl/min Average Horsepower:2415.0 hhp Maximum Horsepower:3325.1 hhp Maximum Prop Concentration:8.8 PPA Client: HilcorpNorth Slope, LLC Well: S-122 Formation: Kuparuk c Country: United States Section 4: Job Messages Message Log #Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 1 13:17:04 Started Pumping 561 1491 202.1 0.0 0.0 2 13:17:07 Start Pad Manually 560 1492 202.1 0.0 0.0 3 13:23:57 Start 0.5 PPA Automatically 4219 2734 302.5 24.5 0.0 4 13:23:57 Started Pumping Prop 4219 2734 302.5 24.5 0.0 5 13:27:24 Stage at Perfs: 0.5 PPA 4262 3094 388.7 25.0 0.5 6 13:27:57 Start Pad 2 Automatically 4285 3089 402.4 24.9 0.5 7 13:35:51 Stage at Perfs: Pad 2 4166 3120 588.7 21.7 0.0 8 13:40:28 Start 1.0 PPA Automatically 4536 3055 702.3 24.8 0.0 9 13:40:32 Started Pumping Prop 4558 3056 703.9 24.9 0.0 10 13:47:19 Start 2.0 PPA Automatically 4394 3054 872.8 24.9 1.0 11 13:47:57 Stage at Perfs: 1.0 PPA 4329 3067 888.6 25.0 2.1 12 13:49:19 Start 3.0 PPA Automatically 4616 3109 922.6 24.9 2.1 13 13:51:20 Start 4.0 PPA Automatically 4889 3157 972.8 25.0 3.0 14 13:53:19 Start 5.0 PPA Automatically 4686 3053 1022.2 24.9 4.0 15 13:54:48 Stage at Perfs: 2.0 PPA 4585 3046 1059.2 24.9 5.0 16 13:55:19 Start 6.0 PPA Automatically 4526 3047 1072.0 24.9 4.9 17 13:56:48 Stage at Perfs: 3.0 PPA 4633 3056 1108.9 24.9 6.0 18 13:57:21 Start 7.0 PPA Automatically 4785 3131 1122.6 24.8 6.0 19 13:57:52 Stopped Pumping Prop 52 3324 1127.9 2.1 9.1 20 14:03:09 Stopped Pumping 4904 2991 1128.3 0.0 0.0 21 14:07:09 Shut in the well 4828 2949 1128.3 0.0 0.0 22 14:31:10 Clean Surface Lines 62 2793 1128.3 0.0 0.0 23 14:59:59 Open Well 3803 1890 1128.3 0.0 0.0 24 15:01:13 Started Pumping 4602 2017 1128.3 0.8 0.0 25 15:01:17 Start Freeze Protect Manually 4788 2047 1128.4 0.7 0.0 26 16:03:10 Shut in the well 1581 2694 1128.4 0 0 Additive Additive Description F103 Surfactant 1.1 Gal/mGal 49.3 gal J475 Breaker J475 2.4 lb/mGal 105.7 lbm J532 Crosslinker 2.8 Gal/mGal 126.2 gal J580 Gel J580 28.7 lb/mGal 1,278.8 lbm L065 Scale Inhibitor 1.2 Gal/mGal 51.3 gal L071 Clay Control Agent 2.1 Gal/mGal 91.6 gal M275 Bactericide 0.7 lb/mGal 30.0 lbm S526-1620 Propping Agent varied concentrations 14,318.0 lbm 95.53643 % 3.70474 % 0.33006 % 0.14686 % 0.06619 % 0.05405 % 0.02593 % 0.02422 % 0.02188 % 0.01995 % 0.01995 % 0.01832 % 0.00994 % 0.00520 % 0.00484 % 0.00388 % 0.00249 % 0.00160 % 0.00083 % 0.00078 % 0.00047 % 0.00039 % 0.00026 % 0.00014 % 0.00014 % 0.00013 % 0.00013 % 0.00008 % 0.00008 % 0.00006 % 0.00001 % 100 %Total * Mix water is supplied by the client. Schlumberger has performed no analysis of the water and cannot provide a breakdown of components that may have been added to the water by third-parties. * The evaluation of attached document is performed based on the composition of the identified products to the extent that such compositional information was known to GRC - Chemicals as of the date of the document was produced. Any new updates will not be reflected in this document. 14808-60-7 Quartz, Crystalline silica 127-08-2 Acetic acid, potassium salt (impurity) 64-19-7 Acetic acid (impurity) 1310-73-2 Sodium hydroxide (impurity) 7447-40-7 Potassium chloride (impurity) 14464-46-1 Cristobalite 111-46-6 2,2''-oxydiethanol (impurity) 9002-84-0 poly(tetrafluoroethylene) 14807-96-6 Magnesium silicate hydrate (talc) 10377-60-3 Magnesium nitrate 55965-84-9 5-chloro-2-methyl-4-isothiazolin-3-one and 2-methyl-4-isothiazolin-3-one 7786-30-3 Magnesium chloride 10043-52-4 Calcium chloride 112-42-5 1-undecanol (impurity) 7631-86-9 Silicon Dioxide (Impurity) 25038-72-6 Vinylidene chloride/methylacrylate copolymer 7647-14-5 Sodium chloride 91053-39-3 Diatomaceous earth, calcined 111-76-2 2-butoxyethanol 34398-01-1 Ethoxylated C11 Alcohol 68131-39-5 Ethoxylated Alcohol 129898-01-7 2-Propenoic acid, polymer with sodium phosphinate 7727-54-0 Diammonium peroxidisulphate 67-63-0 Propan-2-ol 56-81-5 1, 2, 3 - Propanetriol 1303-96-4 Sodium tetraborate decahydrate 107-21-1 Ethylene Glycol 66402-68-4 Ceramic materials and wares, chemicals 9000-30-0 Guar gum 67-48-1 2-hydroxy-N,N,N-trimethylethanaminium chloride CAS Number Chemical Name Mass Fraction -Water (Including Mix Water Supplied by Client)* YF128ST:WF128 44,572 gal † Proprietary Technology The total volume listed in the tables above represents the summation of water and additives. Water is supplied by client. Report ID:RPT-1720 Fluid Name & Volume Concentration Volume Disclosure Type:Post-Job Well Completed: Date Prepared:10/12/2023 State:Alaska County/Parish:North Slope Borough Case: Client:Hilcorp North Slope Well:S-122 Basin/Field:PRUDHOE BAY Page: 1 / 1 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU S-122 Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 205-081 50-029-23265-00-00 457B ADL 0028256 12173 Conductor Surface Intermediate Liner Scab Liner 6732 536 3630 10192 2108 2050 11950 13-3/8" 9-5/8" 7" 4-1/2" 3-1/4" 6751 27 - 562 28 - 3658 26 - 10217 9974 - 12082 9955 - 12005 2256 26 - 561 28 - 3136 26 - 6738 6619 - 6741 6609 -6747 None 2260 3090 5410 7500 11950 5020 5750 7240 8430 11800 - 11830 4-1/2" 12.6# L80 23 - 99556760 - 6758 Structural 80 20" X 34" 27 - 107 26 - 106 2280 770 4-1/2" AHR Packer No SSSV Installed 9907, 6585 Date: Torin Roschinger Operations Manager Claire Mayfield claire.mayfield@hilcorp.com (907) 564-4375 PRUDHOE BAY 9/10/2023 Current Pools: Aurora Oil Proposed Pools: Aurora Oil Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 8:33 am, Aug 04, 2023 323-441 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.08.03 12:58:17 -08'00' Torin Roschinger (4662) DSR-8/7/23 SFD 8/23/2023 , ADL 0028257, ADL 0028258 Fracture Stimulate SFD 8/24/2023 MGR30AUG23 10-404 2256 SFD 8/28/2023 CDW 08/29/2023 *&: 08/30/23 JLC 8/30/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.08.30 13:20:34 -08'00' RBDMS JSB 083123 Frac post RWO Well: S-122 PTD: 205-081 Well Name:S-122 API Number:50-029-23265-00 Current Status:Producer Estimated Start Date:9/10/2023 Rig:SL/Coil Sundry #Date Reg. Approval Rec’vd: Regulatory Contact:Abbie Barker Permit to Drill Number:205-081 First Call Eng (until 9/1/23):Claire Mayfield (907) 564-4375 (O)(713) 443-3631 (M) First Call Eng (after 9/1/23):Marshall Brown (601)-613-0173 (M) Second Call Engineer:Tyson Shriver (907)-564-4542 (O)(406) 690-6385 (M) Current Bottom Hole Pressure:2926 psi @ 6700 TVD 8.4 PPG (RWO continuous hole fill w 8.4 ppg 1% KCL) Max. Anticipated Surface Pressure:2256 psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:N/A since recomplete Min ID:2.441” XO at 11879’ MD Max Angle:99 Deg @ 11200’ MD 70 deg: 10269’ MD High DLS from 10269-10332 MD Formation Tops: HRZ: 9979’ MD, 6622’ TVD Kalubik: 10197’ MD, 6728’ TVD Kuparuk: 10207’MD, 6733’TVD MITs: CMIT: 3750 psi on 6/09/2023 Brief Well Summary: S-122 is a Kuparuk producer that was drilled in 2005. The well has a ~2000ft horizontal 4-1/2” cemented liner in the Kuparuk that had 1140’ of perforations in 12 intervals. To shut off the high water cut perforations, a RWO was completed on 6/19/2023 to insert a 3-1/4” scab liner deployed via 4-1/2” tubing inside the existing 4-1/2” production liner. The liner was cemented with service coil to squeeze all the old perforations behind the new 3-1/4” liner to shut off water. Then coil perforated 30’ at the toe. A single stage frac is proposed to stimulate oil production from the toe. Notes Regarding Wellbore Condition x 5/2/2006: CTU set IBP at 10270’ x 7/11/2009: CTU pulled IBP x 11/13/2010: CTU mill scale, had to cut coil during ops x 3/13/2011: CTU fished cut coil x 3/29/2011: Acid wash x 5/2/2011: SIT x 6/15/2012: EL Tractor PPROF x 12/19/2014: CTU mill scale, acid treatment x 1/4/2015: SIT x 4/26/2016: GLV C/O x 5/19/2023: RWO pulled tubing x 5/19/2023: RWO ran new tubing and scab liner for WSO x 7/21/2023: Coil cemented scab liner and perforated toe CMIT: 3750 psi on 6/09/2023 A single stage frac 2256 psi Frac post RWO Well: S-122 PTD: 205-081 Objective: x DMY valves, circ packer fluid, frac and flowback Slickline with fullbore assist 1. Set plug in X nipple at 9884’MD 2. Dummy GLVs above St1 3. Pull St1 GLV for circ’ing in KWF 4. Load hole with 1% KCl + Freeze protect a. Total T+IA volume to St#1: 150+182 = 332 bbls b. Freeze protect volume to ~2500’ in tbg and IA: 38 bbls + 46 bbls = 104 bbls 5. Dummy st#1 6. MIT-T to 3500 psi, hold 500psi on IA 7. Obtain 3500 psi MIT-IA a. Hold 1000 psi on the tubing during MIT-IA 8. Pull plug in X nipple Sundry Procedure (Approval Required to Proceed) Frac/Special Projects 1. Spot water tanks and fill with fresh water a. Heat water to 110 degF b. Minimum pumping temp for water: 90 degF 2. Pull water from each tank and have SLB lab test our water quality: a. pH - ~7 i. Higher pH delays the hydration of the gel and delays break b. Calcium/magnesium <500 mg/l i. Mg/Ca Negative side effects in the formation such as carbonate deposits, which tend to be insoluble c. Bicarbonate - <400 mg/l i. High bicarbonate levels will cause slow hydration times and elevated delay times with X-linking fluids. If we have elevated bicarbonate levels and have introduced delay agents, it could have an exponential effect in delay times. d. Chlorides-<10,000 mg/l i. This fluid system should be able to cope with elevated Chloride levels e. Iron (Fe+3) - <5 mg/l i. Elevated Iron concentrations exist, the ammonium persulfate (breaker) can have an accelerated effect. Can cause viscosity degradation in linear gels (especially if batch mixed). Also can interfere with X-linking b/c iron will tie up the X-linking sites. f. TDS – minimal/<5000 i. Effects depend on the solids that are dissolved in the fluid. 3. RU and set treesaver per OilStates rep * Pressure test tree saver to 7000 psi (maximum treating pressure+ 1000). * Pressure test treating lines to 7000 psi. * Pressure test IA POP off to 3250 psi. - mgr Frac post RWO Well: S-122 PTD: 205-081 4. Frac per pump schedule MIT-T 3000 psi MIT-IA 3500 psi Maximum Anticipated Treating Pressure:3000 psi @ 25 BPM IA Pop-off Set Pressure (~95% of MIT-IA):3250 psi IA Minimum Hold Pressure (POP-off – 300 psi):3000 psi Maximum Allowable Treating Pressure (MATP = Ann hold + MIT-T): 6000 psi (using tree saver) Stagger Pump Kickouts Between 90 – 95% of MATP:5400 -5700 Global Kickout (95% of MATP):5700 psi N2 POP-off set pressure (MATP + 1000 psi):7000 psi Treating Line Test Pressure (MATP + 1000 psi):7000 psi x If treating pressure starts acting sporadic, consider dropping rate to as low as 11 ppa. If it is acting up at 11 ppa, we should be on flush. Slickline 1. Drift, tag fill – determine whether coil FCO needed 2. Install catcher 3. Install LGLVs 4. Pull catcher 5. RDMO Coil Tubing - Pending – Only FCO if unable to get returns due to fill 1. MIRU and pressure test 2. MU JSN or down jet 3. FCO to ~11900’ MD 4. POOH Testers: 1. MIRU, pressure test 2. POP the well to ASRC with 1-1.5 MMSCFD Lift gas at minimum choke, adjust GL rate as necessary to eliminate slugging. Flow the initial returns to the flowline as long as the shake-outs meet the returned fluid/solids management guidelines. 3. Limit flow to 500 bpd 4. If solids are < 1%, after 1.5 wellbore volumes (~250 bbls) increase the production rate to 750 BLPD. 5. Flow bottoms up and sample for solids production. If solids are still below 1%, increase flow to 1000 BFPD. 6. Flow bottoms up and sample for solids production. If solids are still below 1% continue to increase the flow rate in 250 BPD increments. The objective is to achieve maximum drawdown. Watch returns and do not continue to open choke if solids > 1%; allow well clean up before choke is opened further. 7. Once at FOC, stabilize the well for 4 hrs. Obtain an 8 hr welltest. 4500 psi CDW 8/29/2023 Frac post RWO Well: S-122 PTD: 205-081 Current WBD: S-122 Fracture Stimulation PTD: 205-081 Page 1 Date: August 1, 2023 Subject: S-122 Fracture Stimulation From: Claire Mayfield O: (907) 564-4375 C: (713) 443-3631 To: AOGCC Estimated Start Date: 9/10/2023 Attached is Hilcorp’s proposal and supporting documents to perform a fracture stimulation on well S- 122 in the Kuparuk reservoir of the Prudhoe Bay Unit. The objective of this program is to perform a single stage fracture stimulation to the planned Kuparuk perforations to improve well performance. S-122 was recently worked over to install a tubing deployed cemented scab liner to isolate the watered- out perforations. The workover to install the liner was completed on 6/19/2023, and the liner cement job and 30’ add perf was completed with service coil on 7/21/2023 prior to the proposed frac. Hilcorp requests a variance to sections 20 AAC 25. 283, a, 3- 4 which require identification of fresh - water aquifers and a plan for base-water sampling. Please direct questions or comments to Claire Mayfield. Kuparuk p requests a variance to sections 20 AAC 25. 283, a, 3- 4 w single stage fracture stimulation to t S-122 Fracture Stimulation PTD: 205-081 Page 2 SECTION 1 - AFFIDAVIT (20 AAC 25. 283, a, 1): Below is an affidavit stating that the owners, landowners, surface owners and operators identified on a plat within one-half mile radius of the current or proposed wellbore trajectory have been provided notice of operations in compliance with 20 AAC 25.283, a 1 S-122 Fracture Stimulation PTD: 205-081 Page 3 SIGNED AFFIDAVIT: S-122 Fracture Stimulation PTD: 205-081 Page 4 COPY OF NOTIFICATION SENT VIA EMAIL: S-122 Fracture Stimulation PTD: 205-081 Page 5 SECTION 2: PLAT IDENTIFYING ALL WELLS WITHIN ½ MILE (20 AAC 25. 283, a, 2): Plat of wells within one-half mile of S-122 trajectory. S-122 Fracture Stimulation PTD: 205-081 Page 6 List of wells in Plat 20 AAC 25.283, a, 2 Sw Name Well Class Desc Well Status Desc Sw Name Well Class Desc Well Status Desc S-01 Development Abandoned S-13A Development Oil Producer Gas Lift S-01A Development Abandoned S-13APB1 Development Plugged Back For Redrill S-01B Development Abandoned S-14 Service Abandoned S-01C Development Oil Producer Gas Lift S-14A Service Water Injector Shut-In S-02 Development Abandoned S-15 Service Miscible Injector Shut-In S-02A Development Oil Producer Gas Lift S-15PB1 Service Plugged Back For Redrill S-02AL1 Development Oil Well S-16 Development Oil Producer Shut-In S-02AL1PB1 Development Plugged Back For Redrill S-16PB1 Development Plugged Back For Redrill S-02APB1 Service Plugged Back For Redrill S-17 Development Abandoned S-03 Development Oil Producer Gas Lift S-17A Development Abandoned S-04 Service Water Injector Shut-In S-17AL1 Development Abandoned S-05 Development Abandoned S-17AL1PB1 Development Plugged Back For Redrill S-05A Service Water Injector Injecting S-17APB1 Development Plugged Back For Redrill S-05APB1 Service Plugged Back For Redrill S-17B Development Abandoned S-06 Service Water Injector Injecting S-17C Development Oil Producer Shut-In S-07 Development Abandoned S-17CPB1 Development Plugged Back For Redrill S-07A Development Oil Producer Shut-In S-17CPB2 Development Plugged Back For Redrill S-08 Development Abandoned S-18 Development Abandoned S-08A Development Abandoned S-18A Development Abandoned S-08B Development Oil Producer Gas Lift S-18B Development Oil Producer Shut-In S-09 Service Abandoned S-19 Development Oil Producer Shut-In S-09A Service Water Injector Injecting S-20 Service Abandoned S-09APB1 Service Plugged Back For Redrill S-200 Development Abandoned S-09APB2 Service Plugged Back For Redrill S-200A Development Oil Producer Gas Lift S-09APB3 Service Plugged Back For Redrill S-200PB1 Development Plugged Back For Redrill S-10 Development Abandoned S-201 Development Abandoned S-100 Development Oil Producer Flowing S-201A Service Miscible Injector Operating S-101 Service Miscible Injector Operating S-201PB1 Development Plugged Back For Redrill S-101PB1 Development Plugged Back For Redrill S-202 Development Oil Producer Gas Lift S-102 Development Oil Producer Shut-In Development Oil Well S-102L1 Development Abandoned S-202L2 Development Oil Well S-102L1PB1 Development Plugged Back For Redrill S-202L3 Development Oil Well S-102PB1 Development Plugged Back For Redrill S-202L4 Development Oil Well S-103 Development Oil Producer Gas Lift S-20A Service Water Injector Injecting S-104 Service Water Injector Injecting S-21 Development Oil Producer Gas Lift S-105 Development Abandoned S-210 Service Water Injector Injecting S-105A Development Oil Producer Gas Lift S-213 Development Abandoned S-106 Development Abandoned S-213A Development Oil Producer Gas Lift S-106A Development Oil Producer Gas Lift S-213AL1 Development Oil Producer Flowing S-106L1PB1 Development Plugged Back For Redrill S-213AL1-01 Development Oil Producer Flowing S-106L1 Development Abandoned S-213AL2 Development Oil Well S-106PB1 Development Plugged Back For Redrill S-213AL3 Development Oil Well S-107 Service Miscible Injector Shut-In S-215 Service Water Injector Injecting S-108 Development Oil Producer Shut-In S-216 Service Miscible Injector Operating S-109PB1 Development Plugged Back For Redrill S-217 Service Miscible Injector Operating S-10A Development Suspended S-218 Service Water Injector Injecting S-10APB1 Development Plugged Back For Redrill S-22 Development Abandoned S-10APB2 Development Plugged Back For Redrill S-22A Development Abandoned S-11 Service Abandoned S-22B Service Water Injector Injecting S-110 Service Abandoned S-23 Development Oil Producer Gas Lift S-110A Service Abandoned S-24 Development Abandoned S-110B Service Water Injector Injecting S-24A Service Abandoned S-111 Service Water Injector Injecting S-24APB1 Service Plugged Back For Redrill S-111PB1 Service Plugged Back For Redrill S-24B Service Water Injector Injecting S-111PB2 Service Plugged Back For Redrill S-25 Development Abandoned S-112 Service Water Injector Injecting S-25A Service Water Injector Injecting S-112L1 Service Water And Gas Injector S-25APB1 Service Plugged Back For Redrill S-112L1PB1 Service Plugged Back For Redrill S-26 Development Oil Producer Shut-In S-112L1PB2 Service Plugged Back For Redrill S-27 Development Abandoned S-113 Development Abandoned S-27A Development Abandoned S-113A Development Abandoned S-27APB1 Development Plugged Back For Redrill S-113B Development Oil Producer Shut-In S-27B Development Oil Producer Shut-In S-113BL1 Development Oil Producer Shut-In S-28 Development Abandoned S-114 Development Abandoned S-28A Development Abandoned S-114A Service Water Injector Shut-In S-28B Development Oil Producer Shut-In S-115 Development Oil Producer Gas Lift S-28BPB1 Development Plugged Back For Redrill S-116 Service Abandoned S-29 Development Abandoned S-116A Service Miscible Injector Operating S-29A Service Water Injector Shut-In S-116APB1 Service Plugged Back For Redrill S-29AL1 Service Water Injector Shut-In S-116APB2 Service Plugged Back For Redrill S-30 Development Oil Producer Shut-In S-117 Development Oil Producer Gas Lift S-31 Development Abandoned S-118 Development Oil Producer Gas Lift S-31A Service Water Injector Injecting S-119 Development Abandoned S-32 Development Abandoned S-119A Development Oil Producer Shut-In S-32A Development Oil Producer Shut-In S-11A Service Abandoned S-33 Development Oil Producer Gas Lift S-11B Service Water Injector Injecting S-34 Service Water Injector Injecting S-12 Development Abandoned S-35 Development Oil Producer Gas Lift S-120 Service Water Injector Injecting S-36 Development Oil Producer Shut-In S-121 Development Oil Producer Gas Lift S-37 Development Abandoned S-121PB1 Development Plugged Back For Redrill S-37A Development Oil Producer Shut-In S-122 Development Oil Producer Gas Lift S-37APB1 Development Plugged Back For Redrill S-122PB1 Development Plugged Back For Redrill S-38 Development Oil Producer Shut-In S-122PB2 Development Plugged Back For Redrill S-40 Development Abandoned S-122PB3 Development Plugged Back For Redrill S-400 Service Abandoned S-123 Service Water Injector Injecting S-400A Service Water Injector Shut-In S-124 Service Water Injector Injecting S-401 Service Water Injector Shut-In S-125 Development Oil Producer Gas Lift S-401PB1 Service Plugged Back For Redrill S-125PB1 Development Plugged Back For Redrill S-40A Development Oil Producer Shut-In S-126 Service Miscible Injector Operating S-41 Development Abandoned S-128 Service Water Injector Injecting S-41A Service Water Injector Injecting S-128PB1 Service Plugged Back For Redrill S-41AL1 Service Water Injector Shut-In S-128PB2 Service Plugged Back For Redrill S-41L1 Development Abandoned S-129 Development Abandoned S-41PB1 Service Plugged Back For Redrill S-129A Development Oil Producer Gas Lift S-42 Development Abandoned S-129PB1 Development Plugged Back For Redrill S-42A Development Oil Producer Gas Lift S-129PB2 Development Plugged Back For Redrill S-42PB1 Service Plugged Back For Redrill S-12A Development Abandoned S-43 Development Oil Producer Gas Lift S-12B Development Oil Producer Shut-In S-43L1 Development Oil Producer Gas Lift S-13 Development Abandoned S-44 Development Abandoned S-134 Service Water Injector Injecting S-44A Development Oil Producer Flowing S-135 Development Oil Producer Gas Lift S-44L1 Development Abandoned S-135PB1 Development Plugged Back For Redrill S-44L1PB1 Development Plugged Back For Redrill S-135PB2 Development Plugged Back For Redrill S-504 Service Water Injector Shut-In M-200 Development Oil Producer Gas Lift M-204 Development Oil Producer Gas Lift M-201 Development Water Injector Injecting M-205 Development Water Injector Injecting NKUPST Exploration Abandoned S-122 Fracture Stimulation PTD: 205-081 Page 7 SECTION 3: EXEMPTION FOR FRESHWATER AQUIFERS (20 AAC 25. 283, a, 3): Well S-122 is in the West Operating Area of Prudhoe Bay. Per Aquifer Exemption Order No. 1 dated July 11, 1986 where Standard Alaska Production Company requested the Alaska Oil and Gas Conservation Commission to issue an order exempting those portions of all aquifers lying directly below the Western Operating Area and K Pad Area of the Prudhoe Bay Unit for Class II Injection activities. Findings 1- 4 state: 1. Those portions of freshwater aquifers occurring beneath the Western Operating and K pad areas of the Prudhoe Bay Unit do not currently serve as a source of drinking water. 2. Those portions of freshwater aquifers occurring beneath the Western Operating and K pad areas of the Prudhoe Bay Unit are situated at a depth and location that makes recovery of water for drinking water purposes economically impracticable. 3. Those portions of freshwater aquifers occurring beneath the Western Operating and K pad areas of the Prudhoe Bay Unit are reported to have total dissolved solids content of 7000 mg/ I or more. 4. By letter of July 1, 1986, EPA- Region 10 advises that the aquifers occurring beneath the Western Operating and K pad areas of the Prudhoe Bay Unit qualify for exemption. It is considered to be a minor exemption and a non-substantial program revision not requiring notice in the Federal Registrar. Per the above findings, " Those portions of freshwater aquifers lying directly below the Western Operating and K Pad Areas of the Prudhoe Bay Unit qualify as exempt freshwater aquifers under 20 AC 25. 440" thus allowing Hilcorp exemption from 20 AAC 25. 283, a, 3- 4 which require identification of freshwater aquifers and establishing a plan for base-water sampling.Agree. SFD 8/24/2023 S-122 Fracture Stimulation PTD: 205-081 Page 8 SECTION 4: PLAN FOR BASELINE WATER SAMPLING FOR WATER WELLS 20 AAC 25.283.a.4 There are no water wells located within one-half mile of the current or proposed wellbore trajectory and fracturing interval. A water well sampling plan is not applicable.Agree. SFD 8/24/2023 S-122 Fracture Stimulation PTD: 205-081 Page 9 SECTION 5: DETAILED CEMENTING AND CASING INFORMATION (20 AAC 25. 283, a, 5): All casing is cemented in accordance with 20 AAC 25.52, b and tested in accordance with 20 AAC 25.030, g when completed. See wellbore schematic for casing details: S-122 Fracture Stimulation PTD: 205-081 Page 10 SECTION 6: ASSESSMENT OF EACH CASING AND CEMENTING OPERATION TO BE PERFORMED TO CONSTRUCT OR REPAIR THE WELL 20 AAC 25.283, a, 6 Summary: S-122 History: The S-122 well was spudded on July 30, 2005. The 20” conductor, previously set at 80’ MD, was cleaned out with a 12 ¼” bit however upon drilling the first several hundred feet, several S pad wells (S-216, S-117, S-120) showed signs that S-122 drilling was communicating to their 20” x 9-5/8” annuli. Work was stopped and after discussions with the AOGCC, it was decided to run a 13 3/8” casing string from surface to 535’ to isolate S-122 from other nearby wells on the pad. The 12 ¼” BHA was pulled, a 16” bit picked up, and the hole opened to 16” to 535’ MD. Thirteen joints of 68# L-80 BTC 13 3/8” casing was run to 532’. The casing was cemented with 148 bbls of 15.7 ppg Arctic Set l cement, with returns to surface. The diverter was nippled down, the well head dressed, and the 20”x 9 5/8” annulus topped off with 1.5 bbls of cement. The diverter was nippled back up in preparation to drill ahead. The 12 ¼” hole drilled ahead to the base shales in SV2 to set casing at 3665” MD (-2819’ Tvdss). 9 5/8” casing was run to 3658’ MD (40 # L-80/K-55/L-80 ERW. The casing was cemented with 341 bbls of 10.7 ppg Arctic Lite lead cement and 98 bbls 15.8 ppg tail slurry. Returns were to surface and the plug bumped and 1500 psi held for 5 minutes. PB-1: An 8 ¾” BHA was assembled and run in hole, drilling out the shoe and new formation down to 3685 MD. Following a FIT test to 12.2# EMW, drilling resumed in the intermediate hole section. TD for the intermediate pilot hole was called in the Kuparuk B at 10731 MD, 6985 TVD, 6921 TVDSS. 7” casing was run to 10701 MD, set and cemented with 232 bbls of Arctic lite cement. A plug was set at 10233’ MD, then a whipstock was set on top of the plug at 10217’ MD. PB-2: The window was milled from 10217-10229’ MD near the top of the Kuparuk in the C3C interval. The 6.125” build section was drilled to 86º by 10345 MD, 6711 TVDSS. The lateral BHA was tripped in the hole and drilled upward into the overlying C3C before abruptly entering the HRZ at 10700 MD, 6749 TVD, 6685 TVDSS, and a decision was made to sidetrack to avoid exposed HRZ shales in the wellbore. Total depth encountered in the PB-2 hole was 10854 MD, 6750 TVD, 6685 TVDSS. PB-3: The drill string was pulled back to 10420 MD, and trenching commenced for a low side sidetrack. By 10450 MD, the sidetrack had successfully kicked off, and the well drilled ahead, maintaining a sub horizontal profile in the C3B interval at 6765-70 TVD, 6700-6705 TVDSS. At 10836 MD, the well abruptly reentered the HRZ. This time, while discussing options with town, the well was steered downward, and abruptly reentered the C3B at 10994 MD, 6771 TVD, 6707 TVDSS. Drilling continued while dropping in the section, but with HRZ shales exposed, the decision was made to plug back this section of the well and attempt to pass underneath the erosional surface. TD of PB #3 was called at 11460 MD, 6804 TVD, 6739 TVDSS in C2E sands. S-122 final lateral: A sidetrack was successfully kicked off by 10380 MD. The sidetrack was drilled ahead to 12084 MD, 6740 TVD, 6676 TVDSS, when the wellbore exited the TKUP. Final TD for the well was called at 12173 MD, 6732 TVD, 6668 TVDSS in the HRZ. After laying down the BHA, the 4.5” liner was run in the hole and cemented with 57bbls 15.8 ppg Class G cement with Gasblok. After displacing the r upon drilling the first several hundred feet, several S pad wells (S-216, S-117, S-120) showed signs that S-122 drilling was communicating to their 20” x 9-5/8” annuli. 13 3/8” casing string from surface to 535’ to isolate S-122 from other nearby wells o S-122 Fracture Stimulation PTD: 205-081 Page 11 cement, the plug bumped and increased pressure to 3500psi to set the hanger. Released from hanger and circulated out cement with 23 bbls cement returned to surface indicating good cement job. The rig perforated 12 intervals with 2 ½” 6spf guns underbalanced by 200psi. Since original completion, the well has made ~3000bfpd but the water cut increased from ~50% to ~90% between 2005 and 2013. In 2013, a PPROF log was run along the liner and found the heel-ward perfs to be making most of the production and water. The toe perfs showed the lowest rate but ~100% oil. The supporting water injectors around S-122 are much closer to the heel rather than the toe, which further supports the theory that the heel perfs are more swept than the toe perfs. The well was treated with acid for scale in 2011 and 2014 but neither caused flow rates to change significantly. To shut off the high water cut perforations, a RWO was completed on 6/19/2023 to insert a 3-1/4” scab liner deployed via 4-1/2” tubing inside the existing 4-1/2” production liner. A liner cement job was completed with service coil to squeeze all of the old perforations behind the new 3-1/4” liner to shut off water. Then coil perforated 30’ at the toe. A single stage frac is proposed to stimulate oil production from the toe. All casing is cemented in accordance with 20 AAC 25.030 and each hydrocarbon zone penetrated by the well is isolated. Based on engineering evaluation of the wells referenced in this application, Hilcorp has determined that this well can be successfully fractured within its design limits. Agree. SFD 8/24/2023 coil perforated 30’ at the toe. A single stage frac is proposed to stimulate oil production from the toe. S-122 Fracture Stimulation PTD: 205-081 Page 12 SECTION 7 – PRESSURE TEST INFORMATION AND PLANS TO PRESSURE TEST CASINGS AND TUBING INSTALLED IN THE WELL 20 AAC 25.283, A, 7 On 6/09/2023, the production casing was pressure tested to 3750 psi for a passing CMIT. The new tubing will be pressure tested with an MIT-T to at least 3000 psi prior to executing the proposed frac. The production casing annulus pressure will be monitored during the frac, if any change of pressure is seen outside of thermal expansion, the job will be flushed and the pressure source diagnosed before frac operations continue. S-122 Fracture Stimulation PTD: 205-081 Page 13 SECTION 8: PRESSURE RATINGS AND SCHEMATICS FOR THE WELLBORE, WELLHEAD, BOPE AND TREATING HEAD 20 AAC 25.283, A, 8 Wellbore Tubular Ratings Size/Name Weight Grade Burst, psi Collapse, psi 13-3/8” Surface Casing 68#L-80 5020 2260 9-5/8” Surface Casing 40#L-80 5750 3090 7” Production Casing 26#L-80 7240 5410 4-1/2” Production Tubing 12.6#L-80 8430 7500 3-1/4” x 2-7/8” Production Liner 6.6#L-80 8620 7820 Wellhead FMC manufactured wellhead, rated to 5, 000 psi. Tubing head adaptor: 11" 5,000 psi x 4-1/16" 5,000 psi Tubing Spool: 11” 5,000psi w/ 2-1/16” side outlets Casing Spool: 11” 5,000psi w/ 2-1/16” side outlets Tree: CIW 4-1/16” 5,000psi A 10k psi rated TreeSaver will be used during these fracturing operations: S-122 Fracture Stimulation PTD: 205-081 Page 14 SECTION 9: DATA FOR FRACTURING ZONE AND CONFINING ZONES 20 AAC 25.283, A, 9 Formation MD Top (ft) MD Bot (ft) TVDss Top (ft) TVDss Bot (ft) TVD Thickness (ft) Frac Grad psi/ft Lith. Desc. THRZ 9979 10207 -6554 -6664 110 .7 Shale Top Kup/C interval 10207 10582 -6664 -6845 181 .62 Silts/SS LCU/ Kuparuk B 10582 --6845 -6946*101*.64 Silts/SS Kuparuk A ---6946*-7016*70*.64 Silts/SS Miluveach ---7016*-7852**836**.68 Shale “Depths are estimated from S-122PB1, except where *(estimated from S-103) and ** (estimated from S-03).” (Source: Claire Mayfield, email to AOGCC dated 8/24/2023 SFD 8/25/2023) S-122 Fracture Stimulation PTD: 205-081 Page 15 SECTION 10: LOCATION, ORIENTATION AND A REPORT ON MECHANICAL CONDITION OF EACH WELL THAT MAY TRANSECT CONFINING ZONE 20 AAC 25.283, a, 10 Plat of wells within one-half mile of S-122 wellbore reservoir trajectory and location of faults. The blue line indicates the approximate fracture length and orientation of the frac’s. The plat shows the location and orientation of each well that transects the confining zone. Hilcorp has formed the opinion, based on the following assessments for each well and seismic, well and other subsurface information currently available that none of these wells will interfere with containment of the hydraulic fracturing fluid within the one-half mile radius of the proposed wellbore trajectory. S-122 Fracture Stimulation PTD: 205-081 Page 16 Casing and Cement assessments for all wells that transect the confining zone: There are six primary cement jobs that have been evaluated for zonal isolation that transect the confining zone within a ½ mile of the S-122 wellbore trajectory. Several wells have sidetracks and/or plugbacks that exit below the top of Kuparuk, so the motherbore primary cement job is used for zonal isolation in these evaluations. All six wells within the ½ mile radius were drilled as Kuparuk producers or injectors, and they were cemented to achieve zonal isolation across the Kuparuk. S-111 has a casing cement bond log which was used to determine TOC, and the remaining five wells’ TOC was calculated volumetrically using drilling and an assumed washout for contingency. S-102’s cement job did report losses during the first stage cement pumping around the shoe, so a volumetric TOC calculation of the first stage has an unknown amount of error. However, the casing shoe was set just below the confining shale over the Kuparuk, so it is very likely that adequate zonal isolation exists above the Kuparuk. Also, a second stage cement job was pumped down the casing annulus from surface (see details below). S-102A is an active Kuparuk producer and its tubing, IA and OA pressures will be monitored during the frac; however, we have not observed any indications poor zonal isolation on S-102 to date. No other anomalous cementing or annular pressure reports were found for the other wells to indicate poor zonal isolation of these wells currently completed in the Kuparuk reservoir. Listed below are summaries of the logging (where available) or cementing records used in volumetric calculations for the subsequent zonal isolation table that details measured depth and TVDss depths for top of pay and top of cement. S-102 / S-102L1 / S-102L1PB1: Intermediate hole drilled to 11727’ MD, just below the top of Kuparuk. Initially had full returns while running 7” casing, but lost returns at 4630'. Csg landed at 11717' MD. Stg#1: 155 bbls of 11.54 class G cement followed by 66 bbl 15.8 ppg class G cement pumped around the shoe. Stg#2: 118 bbls of cement injected down the 7x10-3/4" annulus from surface and displaced with 170 bbls mud. **Due to some reported losses, the Stg 1 volumetric TOC calc of 8257' MD, 4760' TVD around the shoe may be inaccurate. However, the 7” casing shoe was set just ~20' TVD below the top of Kuparuk reservoir, so it's very likely that cement exists between the 7” casing and confining shale, isolating the Kuparuk zone of S-102. Cement Stg 2 places cement from 3499' MD to 5927' MD. S-102L1 and L1PB1 were drilled entirely within the Kuparuk C interval below the 7" casing shoe, so primary cement job isolating the Kuparuk is provided by S-102 7” casing. L1 was P&A'd in 2011 with a cemented concentric liner set in S-102. S-102 is an active Kuparuk producer, with existing offset injection support from S-107. S-103: After working through tight spots near 3500' and 7900', the 7" casing was run and cemented with 1224 cu ft of cement. They had full returns and floats held. The rig then pumped down the 7" annulus to clear the 9-5/8" shoe. S-104: After cementing the surface casing, a 8.75" hole was drilled to near top of Shrader. Core was taken through Schrader then drilling continued to TD 9196’ MD. 7" casing was run to 9186’ MD and cemented with 915 cu ft of cement and no reported losses. S-122 Fracture Stimulation PTD: 205-081 Page 17 S-111 / S-111PB1 / S-111PB2 / S-111PB3: 7 5/8” casing ran to 12195’ and cemented (219 bbls of LiteCrete lead; 69 bbls 15.8 ppg Class G tail) with no losses. The plug was bumped with 1500 psi and held for 2 minutes. A USIT on the casing found TOC at 5291' MD. This 7-5/8" casing was the pilot hole and provides primary cement job for PB1/2/3. S-121 / S-121PB1: ran 7" csg to 9993' with DV tool at 7820'. Stg 1 (from 9993') Pumped 38 bbls LiteCrete 15.5 ppg and 43 bbls G 15.8 ppg from shoe. Cal TOC 30% washout is 7091'. Stg2 (from 7820'): 74 bbls 12.5 ppg LiteCrete + 41 bbls 15.8 ppg G. Cal TOC 30% washout is 4516'. S-121 sidetracked from S-121PB1 at 9436', so 7" primary cement job Isolates Kuparuk. S-122 / S-122 PB1 / S-122 PB2: PB1 had 7" casing run to 10701' and cemented with 232 bbls of Arctic Lite cement forming the primary cement job for S-122 and plug backs 2 and 3. S-122 and plug backs 2 and 3 were all kicked off below the top of Kuparuk. S- 1 2 2 F r a c t u r e S t i m u l a t i o n PT D : 2 0 5 - 0 8 1 Pa g e 1 8 We l l Na m e Ca s i n g t y p e Ca s i n g Si z e Ca s i n g De p t h Ho l e Si z e Vo l cm t TO C e s t . vi a TO C TO C To p o f p a y In t e r v a l Zo n a l Is o l a t i o n ? La t e s t M I T Co m m e n t s in MD in Cu F t MD TV D s s TV D s s S- 1 0 2 In t e r m e d i a t e 7 11 7 1 7 9. 8 7 5 12 4 1 Vo l u m e t r i c "S t g 1 : 82 5 7 ' * * St g 2 : 34 9 9 ' - 59 2 7 ' " "S t g 1 : 46 9 0 ** St g 2 : 26 9 7 - 37 1 0 " -6 6 8 0 YE S 9/ 1 / 2 0 1 2 : M I T - I A t o 3 9 9 9 p s i 7” c a s i n g s h o e i s a t ~ 2 0 ’ T V D be l o w t o p o f K u p a r u k a n d b a s e o f co n f i n i n g s h a l e . Lo s s e s R I H w / c s g we r e r e p o r t e d , bu t l o s s e s w e r e m o s t l i k e l y a b o v e th e c o n f i n i n g s h a l e ; t h e r e f o r e ce m e n t s h o u l d p r o v i d e a d e q u a t e is o l a t i o n f o r K u p a r u k . St g 2 c m t w / 1 1 8 b b l s a n d w / 1 7 0 bb l s m u d f r o m s u r f a c e . S- 1 0 2 L 1 In t e r m e d i a t e 7 11 7 1 7 9. 8 7 5 12 4 1 Vo l u m e t r i c -6 6 8 0 YE S 9/ 1 / 2 0 1 2 : M I T - I A t o 3 9 9 9 p s i S- 10 2 L 1 P B 1 In t e r m e d i a t e 7 11 7 1 7 9. 8 7 5 12 4 1 Vo l u m e t r i c -6 6 8 0 YE S 9/ 1 / 2 0 1 2 : M I T - I A t o 3 9 9 9 p s i S- 1 0 3 Pr o d u c t i o n 7 10 0 5 7 8. 7 5 12 2 4 Vo l u m e t r i c 35 4 4 -3 0 3 9 -6 6 5 2 YE S 10 / 3 / 2 0 0 5 8 : C M I T t o 3 5 0 0 p s i Pa s s i n g T I F L 7 / 2 4 / 2 0 1 7 S- 1 0 4 Pr o d u c t i o n 7 91 8 6 8. 7 5 91 5 Vo l u m e t r i c 43 1 7 -3 1 3 2 -6 7 3 7 YE S 7/ 2 4 / 2 0 2 0 : M I T - I A t o 2 5 1 6 p s i AO G C C w i t n e s s e d M I T - I A , co m i n g l e d K u p a r u k a n d s h r a d e r in j e c t o r S- 1 1 1 Pr o d u c t i o n 7. 6 2 5 12 1 9 5 9. 8 7 5 91 0 Vo l u m e t r i c 52 9 0 -3 5 7 3 -6 7 6 9 YE S 9/ 1 4 / 2 0 2 2 : M I T - I A t o 3 5 0 0 p s i US I T 5 - 2 8 - 2 0 0 5 f o u n d T O C a t 5 2 9 1 ' md S- 1 1 1 P B 1 Pr o d u c t i o n 7. 6 2 5 12 1 9 5 9. 8 7 5 91 0 Vo l u m e t r i c 52 9 0 -3 5 7 3 -6 7 6 9 YE S 9/ 1 4 / 2 0 2 2 : M I T - I A t o 3 5 0 0 p s i US I T 5 - 2 8 - 2 0 0 5 f o u n d T O C a t 5 2 9 1 ' md S- 1 1 1 P B 2 Pr o d u c t i o n 7. 6 2 5 12 1 9 5 9. 8 7 5 91 0 Vo l u m e t r i c 52 9 0 -3 5 7 3 -6 7 6 9 YE S 9/ 1 4 / 2 0 2 2 : M I T - I A t o 3 5 0 0 p s i US I T 5 - 2 8 - 2 0 0 5 f o u n d T O C a t 5 2 9 1 ' md S- 1 1 1 P B 3 Pr o d u c t i o n 7. 6 2 5 12 1 9 5 9. 8 7 5 91 0 Vo l u m e t r i c 52 9 0 -3 5 7 3 -6 7 6 9 YE S 9/ 1 4 / 2 0 2 2 : M I T - I A t o 3 5 0 0 p s i US I T 5 - 2 8 - 2 0 0 5 f o u n d T O C a t 5 2 9 1 ' md S- 1 2 1 Pr o d u c t i o n 7 99 9 3 8. 7 5 11 0 1 Vo l u m e t r i c 43 6 2 -3 4 4 1 -6 6 8 6 . 7 2 Ye s 7/ 2 7 / 2 0 1 7 T I F L p a s s e d , 2 / 2 3 / 2 0 1 4 MI T -I A t o 2 5 0 0 p s i Vo l u m e t r i c T O C f r o m s e c o n d s t a g e cm t j o b a s s u m i n g 3 0 % w a s h o u t . Ci r 7 0 b b l s c m t + m u d f / 1 s t s t g th r o u g h D V 5 / 1 9 / 2 0 0 6 S- 1 2 1 P B 1 Pr o d u c t i o n 7 99 9 3 8. 7 5 11 0 1 Vo l u m e t r i c 43 6 2 -3 4 4 1 -6 6 8 6 . 3 9 Ye s 7/ 2 7 / 2 0 1 7 T I F L p a s s e d , 2 / 2 3 / 2 0 1 4 MI T -I A t o 2 5 0 0 p s i Vo l u m e t r i c T O C f r o m s e c o n d s t a g e cm t j o b a s s u m i n g 3 0 % w a s h o u t . Ci r 7 0 b b l s c m t + m u d f / 1 s t s t g th r o u g h D V 5 / 1 9 / 2 0 0 6 S- 1 2 2 F r a c t u r e S t i m u l a t i o n PT D : 2 0 5 - 0 8 1 Pa g e 1 9 We l l Na m e Ca s i n g t y p e Ca s i n g Si z e Ca s i n g De p t h Ho l e Si z e Vo l cm t TO C e s t . vi a TO C TO C To p o f p a y In t e r v a l Zo n a l Is o l a t i o n ? La t e s t M I T Co m m e n t s in MD in Cu F t MD TV D s s TV D s s S- 1 2 2 In t e r m e d i a t e 7 10 7 0 1 8. 7 5 13 0 3 Vo l u m e t r i c 40 3 6 -3 2 7 6 -6 6 6 8 . 8 5 Ye s 6/ 0 9 / 2 0 2 3 : C M I T t o 3 7 5 0 p s i Vo l u m e t r i c c a l c T O C u s i n g 3 0 % as s u m e d w a s h o u t S- 1 2 2 P B 1 In t e r m e d i a t e 7 10 7 0 1 8. 7 5 13 0 3 Vo l u m e t r i c 40 3 6 -3 2 7 6 -6 6 6 8 . 8 1 Ye s 6/ 0 9 / 2 0 2 3 : C M I T t o 3 7 5 0 p s i Vo l u m e t r i c c a l c T O C u s i n g 3 0 % as s u m e d w a s h o u t S- 1 2 2 P B 2 In t e r m e d i a t e 7 10 7 0 1 8. 7 5 13 0 3 Vo l u m e t r i c 40 3 6 -3 2 7 6 -6 6 6 8 . 8 5 Ye s 6/ 0 9 / 2 0 2 3 : C M I T t o 3 7 5 0 p s i Vo l u m e t r i c c a l c T O C u s i n g 3 0 % as s u m e d w a s h o u t S- 1 2 2 P B 3 In t e r m e d i a t e 7 10 7 0 1 8. 7 5 13 0 3 Vo l u m e t r i c 40 3 6 -3 2 7 6 -6 6 6 8 . 8 5 Ye s 6/ 0 9 / 2 0 2 3 : C M I T t o 3 7 5 0 p s i Vo l u m e t r i c c a l c T O C u s i n g 3 0 % as s u m e d w a s h o u t 403 6 S-122 Fracture Stimulation PTD: 205-081 Page 20 SECTION 11: LOCATION OF, ORIENTATION OF AND GEOLOGICAL DATA FOR FAULTS AND FRACTURES THAT MAY TRANSECT THE CONFINING ZONES 20 AAC 25.283, A, 11 Hilcorp’s technical analysis based on seismic, well and other subsurface information available indicates that there are 11 mapped faults that transect the Kuparuk interval and enter the confining zone within the ½ radius of the production and confining zone trajectory for the planned S-122. Fracture gradients within the confining zone (HRZ) will not be exceeded during fracture stimulation and would therefore confine injected fluids to the pool. The HRZ in this area is predominately shale with some silts with an estimated fracture pressure of ~14ppg. Faults 1-11 intersect the production interval and confining zone within the ½ mile radius of the planned fracs. Their displacements, sense of throw, and zone in which they terminate upwards are given below. The wellbore trajectory is essentially a vertical/slant penetration. Maximum stress direction is estimated to be ~30 deg W of N. The frac stage should have sufficient offset to and should not intersect faults #1-11. The S-122 intersects fault #1 at 10840’md and the frac is 3690’ from fault #2, 2987’ from fault #3, 1530’ from fault #4, 1670’ from fault #5, 390’ from fault #6, 1840’ from fault #7, 1380’ from fault #8, 1160’ from fault #9, 2180’ from fault #10 and 1740’ from fault #11 and maximum anticipated fracture half length of 300’ is well short of this distance. Half length is modeled using hydraulic fracture modelling software and is corroborated by what we have seen in other frac treatments. If a sudden drop in treating pressure or increase in pump rate is seen during the stimulation that cannot be explaining by fluids pumped or annular pressure monitoring, pumping operation will stop until a plan forward and explanation can be put forth. Fault Throw Direction Upward Termination 1 0-20' DTW Colville 2 20-40' DTN Colville 3 50-100' DTW Colville 4 0-60' DTN Colville 5 30-70' DTW Colville 6 0-140' DTW Sagavanirktok 7 0-50' DTS Colville 8 0-60' DTS Colville 9 0-70' DTN Colville 10 0-30' DTN Colville 11 0-60' DTE Colville S- 1 2 2 F r a c t u r e S t i m u l a t i o n PT D : 2 0 5 - 0 8 1 Pa g e 2 1 SE C T I O N 1 2 : P R O P O S E D H Y D R A U L I C F R A C T U R I N G P R O G R A M 2 0 A A C 2 5 . 2 8 3 , a , 1 2 Fr a c t u r e S t i m u l a t i o n P u m p S c h e d u l e Pl e a s e s e e F r a c p r o g r a m i n c l u d e d w i t h t h i s s u n d r y a p p l i c a t i o n AT T A C H M E N T 1 : P U M P S C H E D U L E MI T - T 30 0 0 Pr e s s u r e T e s t 70 0 0 Ma x W H T P r e s s u r e 60 0 0 Sl u r r y R a t e 25 Pr o p p a n t D e n s i t y We l l N a m e S- 1 2 2 AF E MI T - I A 35 0 0 Pu m p T r i p s 57 0 0 An n P r e s s u r e 32 5 0 Fl u i d T y p e 28 # X - L i n k Pr o p p a n t U s e d ST E P S T A G E A V E R A G E C O M M E N T S F L U I D P U M P CF D I R T Y V O L U M E D I R T Y V O L U M E P R O P P A N T # # P P A T Y P E R A T E RA T E ST A G E C U M S T A G E C U M S T A G E C U M S I Z E G R O S S C U M (B P M ) (B P M ) (B B L ) ( B B L ) ( G A L ) ( G A L ) ( L B S ) ( L B S ) ( B B L ) ( B B L ) 0 28 # X - L i n k 0. 0 0 00 0 0 0 0. 0 0 St e p - R a t e - T e s t N/ A 0. 0 0 00 0 0 1 Pr i m e u p , p r e s s u r e t e s t Fr e e z e P r o t 5 5. 0 10 10 42 0 4 2 0 1 0 1 0 2 ~K C l 5 5. 0 0 10 04 2 0 0 1 0 3 In j e c t i o n t e s t ~K C l 2 5 25 . 0 75 85 3, 1 5 0 3 , 5 7 0 7 5 8 5 Sh u t d o w n a n d m o n i t o r p r e s s u r e 0 0. 0 85 03 , 5 7 0 0 8 5 4 Ca l i b r a t i o n T e s t 28 # X - L i n k 2 5 25 . 0 0 85 03 , 5 7 0 0 8 5 5 Fl u s h ~K C l 2 5 25 . 0 0 85 03 , 5 7 0 0 8 5 H A R D S H U T D O W N , M O N I T O R P R E S S U R E T I L L C L O S U R E . FL U I D P U M P CF D I R T Y V O L U M E D I R T Y V O L U M E P R O P P A N T C L E A N V O L U M E ST E P S T A G E A V E R A G E C O M M E N T S T Y P E R A T E RA T E ST A G E C U M T O T J O B S T A G E C U M S T A G E C U M S I Z E G R O S S C U M # # P P A ( B P M ) (B P M ) (B B L ) ( B B L ) ( B B L ) ( G A L ) ( G A L ) ( L B S ) ( L B S ) ( B B L ) ( B B L ) Vo l u m e t o T o p P e r f 1 1 3 6 1P A D 28 # X - L i n k 2 5 25 . 0 10 0 18 5 2 7 0 4, 2 0 0 7 , 7 7 0 0 0 1 0 0 1 8 5 7 2 1 FL A T 28 # X - L i n k 2 5 23 . 9 25 21 0 2 9 5 1, 0 5 0 8 , 8 2 0 1 , 0 0 6 1 , 0 0 6 16 / 2 0 C - L i t e 24 2 0 9 8 3 2 FL A T 28 # X - L i n k 2 5 23 . 0 25 23 5 3 2 0 1, 0 5 0 9 , 8 7 0 1 , 9 2 9 2 , 9 3 5 16 / 2 0 C - L i t e 23 2 3 1 9 4 3 FL A T 28 # X - L i n k 2 5 22 . 1 25 26 0 3 4 5 1, 0 5 0 1 0 , 9 2 0 2 , 7 8 1 5 , 7 1 6 16 / 2 0 C - L i t e 23 2 5 4 10 5 4 FL A T 28 # X - L i n k 2 5 21 . 2 25 28 5 3 7 0 1, 0 5 0 1 1 , 9 7 0 3 , 5 6 8 9 , 2 8 4 16 / 2 0 C - L i t e 22 2 7 6 11 6 5 FL A T 28 # X - L i n k 2 5 20 . 5 25 31 0 3 9 5 1, 0 5 0 1 3 , 0 2 0 4 , 2 9 9 1 3 , 5 8 3 16 / 2 0 C - L i t e 21 2 9 6 12 7 6 FL A T 28 # X - L i n k 2 5 19 . 8 25 33 5 4 2 0 1, 0 5 0 1 4 , 0 7 0 4 , 9 7 8 1 8 , 5 6 1 16 / 2 0 C - L i t e 20 3 1 7 13 8 7 FL A T 28 # X - L i n k 2 5 19 . 1 25 36 0 4 4 5 1, 0 5 0 1 5 , 1 2 0 5 , 6 1 2 2 4 , 1 7 3 16 / 2 0 C - L i t e 19 3 3 6 14 9 8 FL A T 28 # X - L i n k 2 5 18 . 5 15 0 51 0 5 9 5 6, 3 0 0 2 1 , 4 2 0 3 7 , 2 2 4 6 1 , 3 9 8 16 / 2 0 C - L i t e 11 3 4 4 9 15 10 9 FL A T 28 # X - L i n k 2 5 17 . 9 15 0 66 0 7 4 5 6, 3 0 0 2 7 , 7 2 0 4 0 , 5 5 2 1 0 1 , 9 4 9 16 / 2 0 C - L i t e 10 9 5 5 8 16 11 10 FL A T 28 # X - L i n k 2 5 17 . 3 15 0 81 0 8 9 5 6, 3 0 0 3 4 , 0 2 0 4 3 , 6 7 6 1 4 5 , 6 2 5 16 / 2 0 C B L 10 6 6 6 3 17 12 11 FL A T 28 # X - L i n k 2 5 16 . 8 15 0 96 0 1 , 0 4 5 6, 3 0 0 4 0 , 3 2 0 4 6 , 6 1 3 1 9 2 , 2 3 9 16 / 2 0 C B L 10 2 7 6 6 18 13 Fl u s h FL U S H ~K C l 2 5 25 . 0 13 0 1, 0 9 0 1 , 1 7 5 5, 4 6 0 4 5 , 7 8 0 0 1 9 2 , 2 3 9 1 3 0 8 9 6 19 14 F L U S H Fr e e z e P r o t 2 5 25 . 0 38 1, 1 2 8 1 , 2 1 3 1, 5 9 8 4 7 , 3 7 8 0 1 9 2 , 2 3 9 3 8 9 3 4 TO T A L S 11 2 8 19 2 , 2 3 9 9 3 4 T o t a l C h e m s SD a n d o b t a i n I S I P & 1 5 m i n S I P . Co s t CL E A N V O L U M E S-122 Fracture Stimulation PTD: 205-081 Page 22 Table 5 – Anticipated Pressures MIT-T 3000 psi MIT-IA 3500 psi Maximum Anticipated Treating Pressure:3000 psi @ 25 BPM IA Pop-off Set Pressure (~95% of MIT-IA):3250 psi IA Minimum Hold Pressure (POP-off – 300 psi):3000 psi Maximum Allowable Treating Pressure (MATP = Ann hold + MIT-T):6000 psi (using tree saver) Stagger Pump Kickouts Between 90 – 95% of MATP:5400 -5700 Global Kickout (95% of MATP):5700 psi N2 POP-off set pressure (MATP + 1000 psi):7000 psi Treating Line Test Pressure (MATP + 1000 psi):7000 psi OA Pressure:Monitor Max Anticipated Proppant Loading:11 PPA There are three overpressure devices that protect the surface equipment and wellbore from overpressure. 1) Each individual frac pump has an electronic kickout that will shift the pumps into neutral as soon as the set pressure is reached. Since there are multiple pumps, these set pressures are staggered between 90% and 95% of the maximum allowable treating pressure. 2) A primary pressure transducer in the treating line will trigger a global kickout that will shift all the pumps into neutral. 3) There is a manual kickout that is controlled from the frac van that can shift all pumps into neutral. All three of these shutdown systems will be individually tested prior to high pressure pumping operations. Additionally, the treating pressure, IA pressure and OA pressure will be monitored in the frac van. Based on a regional stress map, the maximum horizontal stress in the Kuparuk sands is determined to run ~30° W of N). The horizontal section of the well though the Kuparuk is drilled roughly perpendicular to the maximum horizontal stress meaning the induced fracture will also be directionally perpendicular to the wellbore. 3000 psi @ 25 BPM 4500 psi CDW 8/29/23 S-122 Fracture Stimulation PTD: 205-081 Page 23 Frac Dimensions: Frac #MD Location, ft TVDss top, ft TVDss Bottom, ft Frac Half-Length, ft 1 11,815 -6611 -6728 ~350’ Disclaimer Notice: This model was generated using commercially available modelling software and is based on engineering estimates of reservoir properties. Hilcorp is providing these model results as an informed prediction of actual results. Because of the inherent limitations in assumptions required to generate this model, and for other reasons, actual results may differ from the model results. S-122 Fracture Stimulation PTD: 205-081 Page 24 Frac Modelling: Maximum Anticipated Treating Pressure: ~4500 psi Surface pressure is calculated based on a closure pressure of ~0.63 psi/ ft or ~4200 psi. Closure pressure plus anticipated net pressure to be built (800 psi) and friction pressure minus hydrostatic results in a surface pressure of ~4400 psi at the time of flush. 4200 psi (closure)+ 800 psi (net) + 2415 psi (friction) - 3015 psi (hydrostatic)= 4400 psi (max surface press) The difference in closure pressures of the confining shale layers determines height of the fracture. Average confining layer stress is anticipated to be ~0.7 psi/ ft limiting fracture height to ~117 ft TVD. Fracture half-length is determined from confining layer stress as well as leak-off and formation modulus. The modeled frac is anticipated to reach a half-length of ~350 ft. 4400 psi (max surface press) ~4500 psi S-122 Fracture Stimulation PTD: 205-081 Page 25 S-122 Fracture Stimulation PTD: 205-081 Page 26 Pre-Job Anticipated Chemicals to be pumped: 39,215 gal S-122 Fracture Stimulation PTD: 205-081 Page 27 SECTION 13: POST FRACTURE WELLBORE CLEANUP AND FLUID RECOVERY PLAN 20 AAC 25.283, A, 13 After the fracture stimulation and potentially during the post frac coil fill cleanout, the well will be put on production through portable well testers. All liquids will be captured and either sent to production facilities or diverted to flowback tanks if solid % becomes too high for our facilities to manage. The initial flowback period is intended to produce back the fracture fluids to tanks as quickly as possible, until the well is produced less than 0.5% solids, at which time the produced fluids meet the GC2 acceptance criteria for start-up. There will be a tank farm on pad to store the produced fluids from flowback operations. The flowback fluids not suitable for GC2 processing will be hauled to another facility’s slop tanks for additional settling time and or disposal. Hilcorp will work to separate and recover fluid that meets the facility specification for the flowback fluids. A fluid manifest form will be completed for each load trucked offsite. Hi l c o r p N o r t h S l o p e , L L C Hi l c o r p N o r t h S l o p e , L L C Ch a n g e s t o A p p r o v e d W o r k O v e r S u n d r y P r o c e d u r e Da t e : A u g u s t 3 , 2 0 2 3 Su b j e c t : C h a n g e s t o A p p r o v e d S u n d r y P r o c e d u r e f o r W e l l S - 1 2 2 Su n d r y # : An y m o d i f i c a t i o n s t o a n a p p r o v e d s u n d r y w i l l b e d o c u m e n t e d a n d a p p r o v e d b e l o w . C h a n g e s t o a n a p p r o v e d s u n d r y w i l l b e c o m m u n i c a t e d t o t h e AO G C C b y t h e w o r k o v e r ( W O ) “ f i r s t c a l l ” e n g i n e e r . A O G C C w r i t t e n a p p r o v a l o f t h e c h a n g e i s r e q u i r e d b e f o r e i m p l e m e n t i n g t h e c h a n g e . St e p Pa g e Da t e P r o c e d u r e C h a n g e HNS Pr e p a r e d By ( I n i t i a ls ) HN S Ap p r o v e d By ( I n i t i a l s ) AO G C C W r i t t e n Ap p r o v a l R e c e i v e d (P e r s o n a n d D a t e ) Ap p r o v a l : As s e t T e a m O p e r a t i o n s M a n a g e r D a t e Pr e p a r e d : Fi r s t C a l l O p e r a t i o n s E n g i n e e r D a t e 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU S-122 Install, Cement Scab liner Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 205-081 50-029-23265-00-00 12173 Conductor Surface Intermediate Liner Scab Liner 6732 536 3630 10192 2108 2050 11950 13-3/8" 9-5/8" 7" 4-1/2" 3-1/4" 6751 27 - 562 28 - 3658 26 - 10217 9974 - 12082 9955 - 12005 26 - 561 28 - 3136 26 - 6738 6619 - 6741 6609 -6747 None 2260 3090 5410 7500 11950 5020 5750 7240 8430 11800 - 11830 4-1/2" 12.6# L80 23 - 9955 6760 - 6758 Structural 80 20" X 34" 27 - 107 26 - 106 2280 770 4-1/2" AHR Packer 9907, 6585 9907 6585 Torin Roschinger Operations Manager Claire Mayfield claire.mayfield@hilcorp.com 907-564-4375 PRUDHOE BAY, Aurora Oil Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028256 23 - 6609 9907 - 12039'MD Cement scab liner in place with 11-bbls of 15.8-ppg Class G Cement. Final treating pressure = 2195-psi. 85 Well Not Online 43 3200 1600 500 250 200 323-315, 323-357 13b. Pools active after work:Aurora Oil No SSSV STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.08.02 05:53:39 -08'00' Torin Roschinger (4662) By Grace Christianson at 8:57 am, Aug 02, 2023 RBDMS JSB 080323 DSR-8/4/23 SFD WCB 4-8-2024 ACTIVITY DATE SUMMARY 6/5/2023 T/I/O =250/1550/600. Temp = 92. PPPOT-IC (PASS), PPPOT-T (PASS). Pre RWO. PPPOT-IC: Stung into test port (1000 psi), bled void to 0 psi. Monitor for 10 min (0 psi). Pumped hyd oil across test void to opposite port. Pressured void to 3500 psi for 30 min test, lost 0 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. Did not function LDS. The packoff will not be pulled for this RWO. PPPOT-T: Stung into test port (1500 psi), bled to 0 psi. Monitor for 10 min (0 psi). Functioned LDS all moved freely. Re-torqued gland nuts and LDS to 500 ft/lbs. Pumped hyd oil across test void to opposite port, good returns. Pressured void to 5000 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi, RDMO. 6/7/2023 (Assist Slickline) TFS U-3. Spot Equitment and standby *Job continues to 6-8-23* 6/7/2023 ***WELL FLOWING ON ARRIVAL*** DRIFT TO 10,262' SLM W/ 2.80" CENT, 1-3/4" S.BAILER(empty) SET 3-1/2" PX PLUG BODY IN X-NIP @ 9,977' SLM (4 x 3/16 EQ PORTS) PULLED STA.# 2 @ 8,104' SLM PULLED STA. # 3 & 4 FROM 7,080 & 4878' SLM SET RK-DGLV IN STA. 4 @ 4,878' SLM ***CONTINUE ON 6-8-23 WSR*** 6/8/2023 ***CONTINUE ON FROM 6-7-23 WSR*** SET RK-DGLV IN STA.# 3 @ 7,087' SLM T-BIRD LOADED IA AND SET RK-DGLV IN STA.# 2 @ 8,104' SLM PULLED 3-1/2" X-CATCHER FROM X-NIPPLE @ 9,977' SLM T-BIRD LOADED TBG AND WE SET 3-1/2" PX PLUG BODY IN X-NIP @ 9,977' SLM SET P-PRONG IN PX-PLUG BODY @ 9,977' SLM T-BIRD PERFORMED PASSING COMBO MIT-T-IA TO 3500psi T-BIRD PERFORMED PASSING MIT-T AS WELL ***CONTINUE ON 6-9-23 WSR*** 6/8/2023 *Job continues from 6-7-23* T/I/O=1256/1216/0 (Assist Slickline, MIT-T, CMIT- TxIA) TFS U-3. Pumped 5 bbls of 60/40 followed by 172 bbls of 1% KCL followed by 47 bbls of DSL down the IA to load and freeze protect. Pumped 112 bbls of 1% KCL followed by 2 bbls of 60/40 followed by 40 bbls of DSL to load and freeze protect. Pumped 47 bbls of DSL down the IA and TBG to reach test pressure for a CMIT-TxIA MAP @3750 psi. Started test at 3725 TBG and 3742 IA. First 15 minutes TBG lost 11 psi, IA lost 19 psi. Second 15 minutes TBG lost 7 psi, IA lost 6 psi *PASS*. Pumped 2 bbls of DSL down the TBG to MIT-T MAP @3750 psi. Started test at 3753 psi. First 15 minutes TBG lost 73 psi. Second 15 minutes TBG lost 18 psi. *PASS*. ***Job continues to 6-9-23*** Daily Report of Well Operations PBU S-122 yy Pumped 47 bbls of DSL down the IA and TBG to reach test pressure for a CMIT-TxIA MAP @3750 psi. Started test at 3725 TBG and 3742 IA. First 15 minutes TBG lost 11@ psi, IA lost 19 psi. Second 15 minutes TBG lost 7 psi, IA lost 6 psi *PASS* Daily Report of Well Operations PBU S-122 6/9/2023 *Job continues from 6-8-23* (Assist slickline, MIT-IA, CMIT-TxIA) TFS U-3. Pumped 21 bbls of DSL down the IA and TBG to pressure up for Multiple MIT-IA's *FAILED* (see log). Pressured up TBG and IA for a CMIT-TxIA MAP @ 3750 psi *PASS*. Reached test pressure at 3748 TBG and 3752 IA. First 15 minutes TBG lost 8 psi, IA lost 7 psi. Second 15 minutes TBG lost 5 psi, IA lost 6 psi *PASS*. Bled back TBG and IA to Starting pressures 878/949/0. Well left in control of Slickline upon departure Flags and tags hung 6/9/2023 ***CONTINUE ON FROM 6-8-23 WSR*** PULL P-PRONG FROM 3-1/2" PX @ 9,967' MD PULL 3-1/2" PX FROM X-NIPPLE @ 9,967' MD ***WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED ON WELL STATUS*** **POSSIBLE 2.6" ROLLER STEM WHEEL LEFT IN HOLE*** 6/10/2023 ***WELL S/I ON ARRIVAL*** PRESSURE TEST PCE TO 200#LP-3,000#HP RIH W/ 1-7/16 CHD (1" FN), BAKER CUTTER (19' OAL, 2-1/8" MAX OD) CUT DEPTH=9,925.2' GOOD INDICATION ON BAKER TOOL NO CHANGE IN T/I PRESSURES T-BIRD UNABLE TO PUMP FLUID PAST PACKER RIH W/ 1-9/16" CHD (1" FN), 2" WB, 2-1/8" CCL, BOW SPRING, MAGNET, 2" PUNCHER (LOADED 3' W/ 7 GRAM PUNCHER CHARGES), MAGNET BULLNOSE (2-1/8" MAX OD, 17' OAL) CCL OFFSET=6.7', PUNCHER DEPTH=9,913'-9,916', CCL STOP DEPTH=9,906.3' T-BIRD ABLE TO INJECT DOWN IA @ 3 BPM (see pump report) TREECAP INSTALLED & PRESSURE TESTED TREE VALVES NORMAL ***WELL LEFT S/I*** 6/10/2023 T/I/O=100/700/0 Temp=SI TFS Unit#3 Assist E-Line Pumped 8 BBLS down the IA to check Packer cut pressured up to 3300 psi. Pumped 42 BBLS of crude down the TBG to verify injectivity into TBG 1 BPM @ 425 psi 2 BPM @ 425 psi 3 BPM @ 425 psi 4 BPM @ 350 psi 5 BPM @ 350 psi Well left in control of Eline upon departure 6/11/2023 TB-1 RWO Job Scope: TBG Swap/TBG Deployed Scab LNR. Rig on location Standby. ...Continue WSR on 6/12/2023... 6/11/2023 T/I/O= Circ Out Well (RWO) ***Job Continued 6/12/23*** 6/12/2023 ***Job Continued 6/11/23*** (RWO CAPITAL) T/I/O=103/175/0. Circ out well w/ 5 bbls 60/40 Spear down Tbg. Pumped 102 bbls Deep Clean Sol. Down TBG. Pumped 393 bbls 9.9 Brine Down TBG taking returns up IA to S-117 FL. FWHP=0/0/0 Casing valves OTG Pumped () 21 bbls of DSL down the IA and TBG to pressure up for Multiple MIT-IA's *FAILED Pumped 8 BBLS down the IA to check Packer cut TB-1 RWO Job Scope: TBG Swap/TBG Deployed Scab LNR. Rig on location Pressured up TBG and IA for a CMIT-TxIA MAP @ 3750 psi *PASS* Daily Report of Well Operations PBU S-122 6/12/2023 TBird-1 RWO Job Scope: Pull Tbg. Clean out Liner. Run New Completion w/ Scab Liner Standby for Well Kill and BOPE installation. Well kill pumped by LRS. Tbg on Vac Ia @ 190 psi. Bleed to bleed trailer from 190 psi to 30 psi in 2 hrs (all gas). Stop for I&E to reconnect S-117 and RU flowback tank. Continue bleeding to zero ~15 bbls retuned (gas and diesel). Monitor Tbg and IA for 1 hour - no flow. Set BPV/CTS. Well Sppt ND tree and NU BOP. Lay down rig mats and spot rig, choke/kill manifold, Pits, UR tanks. Spot Koomy Unit. ...Continue WSR on 6/13/2023 6/12/2023 S/B for LRS to kill well. Set 4" CTSHBPV. Check void for pressure. Assist WWS N/D tree. **SBMS stayed in THA** Clean void, inspect TBG HGR neck and lift threads. Terminate (1) 1/4" tecwire. Install CTS plug. M/U 4 1/2" TCII test sub, test CTS plug to 4M for 10 min. PASSED. Bleed off pressure and recover fluid. **LDS out = 4 3/8" ** N/U DSA and BOP. 6/12/2023 T/I/O = Vac/80/Vac. Temp = SI. T & IA FL (RWO request). Flowline & GLT line discnnected, Wellhouse removed. T FL @ 170'. IA FL @ 450'. LRS incontrol of well upon departure. SV = O. WV = C. SSV, MV = O. IA, OA = OTG. 10:00 6/13/2023 Make up 4-1/2" TC-II landing joint to tubing hanger lift threads 8 RH turns, mark top of BOP on landing joint, check IA for pressure (0 psi.), loosen gland nuts, back out upper lock down screws to 4-3/8" min., tighten gland nuts, open IA valve, pull hanger to floor, cut ¼" I wire that was run through tubing hanger body, remove tubing hanger & pup from string, lay down landing joint, take tubing hanger to tool service for redress & pup swap. 6/13/2023 TB-1 RWO Job Scope: Pull TBG, Drift/Mill LNR, Run New Completon w/Scab LNR attached. ...Continue WSR from 6/12/2023... Finsh RU, Function test BOPE and shell test to 250 psi Low/ 3000 psi High. Test BOPE to 250/3000 psi. 5 hours no failures. Witness Waived by Sully Sullivan. Tbg and IA at zero pressure. Pump125 bbls 4.3 bpm @ 255 psi down tbg (Tbg Vol 118 bbls) IA open to kill tank while pumping with no returns. Tbg dead. Pump 313 bbls down IA (1.2x volume to bttm perfs) 4.3 bpm @ 360 psi. Flow check. T and IA strong vac. Unable to filll hole @ 1.3 bpm. Close blinds and start minimum continuous hole fill @ 31 bbls/hr. Set-up to pull completion. MU Landing Jt, BOLDS, PU on completion with TBG hanger moving up. Pulled up to 140k-lbs with no movement at PKR. Cycle up/down 5 times to 14Ok-lbs seen PKR release on down swing of last cycle. Pull TBG haner to floor.94K). Cut i-wire and lay down TBG Hanger. Bullhead kill down the TBG 50 bbls and 75 bbls down the IA 2x the PKR to bottom perf volume. Start de-completion of well. ...Continue WSR on 6/14/2023... 6/14/2023 TBird-1 RWO Job Scope: Pull 4-1/2" x 3-1/2" Completion w/PKR, Drift w/MIll to TD, Run New 4-1/2" Completion w/ Scab LNR Continue pulling 4-1/2" x 3-1/2" completion w/ i-wire. Pull & L/D 116 4-1/2" IBT joints and 159 3-1/2" IBT joints. Recovered all completion components, 250 OTC Canon Clamps, 13 half clamps, and 1 SS Band. M/U BOT clean out BHA & RIH. ......Continued on 6/15/23 Make up 4-1/2" TC-II landing joint to tubing hanger lift threads 8 RH turns, mark top gj g g of BOP on landing joint, check IA for pressure (0 psi.), loosen gland nuts, back out gj ( ) g upper lock down screws to 4-3/8" min., tighten gland nuts, open IA valve, pull hanger gg g to floor, cut ¼" I wire that was run through tubing hanger body, remove tubing hanger g & pup from string, lay down landing joint Continue pulling 4-1/2" x 3-1/2" completion w/ i-wire. Pull & L/D 116 4-1/2" IBT joints g and 159 3-1/2" IBT joints. Recovered all completion components Daily Report of Well Operations PBU S-122 6/15/2023 TBird-1 RWO Job Scope: Pull 4-1/2" x 3-1/2" Completion w/PKR, Drift w/MIll to TD, Run New 4-1/2" Completion w/ Scab LNR Continue RIH w/BOT Cleanout BHA # 1 on 2-7/8" PH-6 workstring. CHF 38 BPH. Tagged up 20' in on joint # 333 = 10,260' ORKB. R/U power swivel. Establish baseline parameters, milled approximately 5' and BHA plugged off 500 psi to 1500 psi. Attempt to establish circulation through BHA with no success. Discuss plan forward w/Wells Foreman & OE. TOH to above Liner Top 9,934' ORKB. BH 75 bbls down IA at 5 bpm / 300 psi. Attempt to circulate down workstring, pressured up to 3000 psi. TOH w/BHA # 1 RBWS. .....Continued on 6/16/23 WSR 6/16/2023 TBird-1 RWO Job Scope: Pull 4-1/2" x 3-1/2" Completion w/PKR, Drift w/MIll to TD, Run New 4-1/2" Completion w/ Scab LNR Continue TOH w/BHA # 1 RBWS. L/D BHA. Mill & boot BSK internally plugged w/ scale & debris. M/U BHA # 2 = 3.75" Smooth OD mill, boot BSK, LBS , Oil jar & circ sub. TIH w/BHA # 2. At Liner Top 9,938', verify circulation down WS 2.5 bpm / 620 psi. PU joint # 333 = 10,245' ORKB. R/U power swivel. Establish baseline milling parameters and milled through tight spot 10,265' ORKB. Tbird pipe wrangler lost hydraulics. Continue working mill in hole picking up single joints w/tugger. ...........Continued on 6/17/23 WSR 6/17/2023 TBird-1 RWO Job Scope: Pull 4-1/2" x 3-1/2" Completion w/PKR, Drift w/MIll to TD, Run New 4-1/2" Completion w/ Scab LNR Continue working mill in hole picking up single joints w/tugger. Replace pipe wrangler. Wash & ream to PBTD at 12,039' ORKB, PUW 100k. Pulled up 140k, 40k over off bottom. Increase pump rate down WS 2.5 bpm. Back ream up and pulled free. TOH w/BHA # 2. At liner top, swap from hole fill on WS to CHF down IA 35 BPH. Prep completion. RIH 4-1/2" JFE bear x 3-1/4" TC-II scab liner completion as per approved run tally. 6/18/2023 TBird-1 RWO Job Scope: Pull 4-1/2" x 3-1/2" Completion w/PKR, Drift w/MIll to TD, Run New 4-1/2" Completion w/ Scab LNR Continue RIH 4-1/2" JFE bear x 3-1/4" TC-II scab liner completion as per approved run tally. TB-1 TTS. CHF down IA 34 BPH. Current depth = 11,580'. .......Continued on 6/19/23 WSR 6/19/2023 Clean void & ring groove, install new RX-54, inspect THA ID & SBMS that remained in THA upon removal, install & torque up THA, test void 500 psi/ 5 min., 0 psi. loss, test 5,000 psi/30 min., lost 200 psi first 15 min., lost 0 psi second 15 min., bleed off test psi., monitor SBMS port while well support test tree, leaked a drop about every two seconds while pressure was on tree, no void psi. while tree had 5,000 psi on it, appears SBMS only leaking from tree side, RDMO 6/19/2023 Well is on a vac, bop is drained & IA valve open. Land tubing hanger with H- TWC installed at 13.5', visually verify though IA valve. Torque gland nuts & LDS. Pressure test tubing hanger primary seal and TWC against the blind rams at 2500 psi for 5 min, good test. Run New 4-1/2" Completion w/ Scab LNR Continue RIH 4-1/2" JFE bear x 3-1/4" TC-II scab liner completion as per approved run tally. TB-1 TTS. CHF down IA 34 BPH. Current depth = 11,580'. Run New 4-1/2" Completion w/ Scab LNR Daily Report of Well Operations PBU S-122 6/19/2023 TBrid-1 RWO Job Scope: Pull 4-1/2" x 3-1/2" Completion w/ PKR, Drift w/ Mill to PBTD, Run New 4-1/2" Completion w/ Scab LNR. Continue RIH 4-1/2" JFE Bear x 3-1/4" TC-II scab liner completion as per appproved run tally. TB-1 TTS. M/U hanger & landing JT. Land hanger, PUW 125k, SOW 55k. RILDS. Test hanger primary seals against blinds & TWC 250 psi low / 2500 psi high. RDMO TB-1. .......RWO Program Completed 6/19/2023 T/I/O=TWC/0/0. Post TB #01. RU 11" FMC Gen 5 THA and 4" CIW tree with Halliburton LEO actuatro. Pressure tested tree against TWC to 500/5000 psi. Pass. Pull 4" "H" TW with Dryrod. Install poduction and GLT piping on S-122 and S-115. Set floor kits and wellhouses on 122/115/117. ***Job Complete***. Final WHP's 0/0/0. 6/19/2023 T/I/O/=0/0/0 (RWO CAPITAL) Freeze Protect IA 2 bbls 60/40, 22 bbls crude. ***Job Continued 6/20/23*** 6/20/2023 ***Job Continued 6/19/23*** (RWO CAPITAL) Started Pumping @ 22 bbls Crude down IA for FP. Pumped 2bbls 60/40, 38 bbls crude down TBG. FWHP=165/140/0. SV,SSV,WV=Closed MV,IA,OA=Open upon departure left well in dso control. 7/18/2023 LRS CTU #2 1.75" Blue Coil. Job Objective: Cement Liner/Perforate MIRU & RIH with GR/CCL in 2.20" carrier & 2.25" DJN. Tag fill at 11939' CTM. Log at 50 FPM up to 9700' CTM. Paint red/yellow flag at 11840' CTM. Start POOH. ***Job In Progress*** 7/19/2023 TFS U3 (Assist coil). Pumped 3 bbls of dsl down the IA to pressure up to 3000 psi to rupture sheer disc for coil. Pumped another 37 bbls of DSL down the IA at rate to clean out bottom GLVM. Pumped an additional 44 bbls of dsl down the IA at Minimum rate to maintain flow while coil POOH. Well left in control of LRS CTU#2 upon departure. 7/19/2023 LRS CTU #2 1.75" Blue Coil. Job Objective: Cement Liner, Perforate Continue POOH with HES GR/CCL logging tools and confirm good data (+10' correction). RIH with slim LRS FCO BHA & 1.75" JSN. Jet hard fill from 11950' to 12042' MD. Pump gel and chase OOH. Verify TxIA communication at surface (1 BPM down TBG / 0.5 BPM from IA). MU 2-7/8" NSAK 1-trip cement retainer. RIH and set at 11950'. PT the retainer to ~ 500 psi. Circulate 200 BBL's of diesel behind liner / into the IA. Circulate in 10 bbls of Inhibitted FW and 10 bbls of 15.8 ppg cement. Squeeze away 1.0 bbl of additional cement (total of 11 behind pipe) and unsting from retainer with 1.4 bbls of cement still in the coil. Set packer by pressuring tubing to 3300 psi with good indication of set. Circulate out residual cement and contimate with powervis. Once above GLM #1, pressure up IA to 3100 psi until shear out valve opened. Circulate 40 bbls from IA into tubing at 3.5 bpm to flush IA and GLM. After 40 bbls reduce rate to 0.3 bpm and continue circulating down IA and up tubing, while coil continueing to ciculate KCl and powervis to ensure the tubing is clean. ...Continued on WSR 7-20-23... 7/20/2023 LRS CTU #2 - 1.75" Blue Coil ***Continued from WSR 7-19-23*** Job Objective: Cement Liner, Set Packer, AddPerf Jet BOP and wellhead. Standby for cement to reach compressive strength. ...Continued on WSR 7-21-23... gg g g ( RIH with slim LRS FCO BHA & 1.75" JSN. Jet hard fill from 11950' to ) 12042' MD. Pump gel and chase OOH. Verify TxIA communication at surface (1 BPM gy ( down TBG / 0.5 BPM from IA). MU 2-7/8" NSAK 1-trip cement retainer. RIH and set) at 11950'. PT the retainer to ~ 500 psi. Circulate 200 BBL's of diesel behind liner / into the IA. Circulate in 10 bbls of Inhibitted FW and 10 bbls of 15.8 ppg cement. Squeeze g away 1.0 bbl of additional cement (total of 11 behind pipe) and unsting from retainer y()g with 1.4 bbls of cement still in the coil. Set packer by pressuring tubing to 3300 psiygg with good indication of set. Circulate out residual cement and contimate withg powervis. Once above GLM #1, pressure up IA to 3100 psi until shear out valve opened Circulate 40 bbls from IA into tubing at 3.5 bpm to flush IA and GLM. Afterg 40 bbls reduce rate to 0.3 bpm and continue circulating down IA and up tubing, whileg coil continueing to ciculate KCl and powervis to ensure the tubing is clean Continue RIH 4-1/2" JFE Bear x 3-1/4" TC-II scab liner completion as per appproved run tally M/U hanger & landing JT. Land hanger, Standby for cement to reach compressive strength LRS CTU #2 1.75" Blue Coil. Job Objective: Cement Liner/Perforatej MIRU & RIH with GR/CCL in 2.20" carrier & 2.25" DJN. Tag fill at 11939' CTM. Log at g 50 FPM up to 9700' CTM. Paint red/yellow flag at 11840' CTM. Start POOH. Daily Report of Well Operations PBU S-122 7/21/2023 LRS CTU #2 - 1.75" Blue Coil ***Continued from WSR 7-20-23*** Job Objective: Cement Liner, Set Packer, AddPerf Make up 30' of 2.5" millenium perf guns, 6 spf, 0.32" entry hole, and RIH. Tie-in to X- O and perforate 11800-11830'. POOH and FP tubing. RDMO CTU. ***Job Complete**** j Make up 30' of 2.5" millenium perf guns, 6 spf, 0.32" entry hole, and RIH. Tie-in to X-g O and perforate 11800-11830'. POOH 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will planned perforations require a spacing exception?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStrastigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other: Post Initial Injection MIT Req'd? Spacing Exception Required?Yes Yes No No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU S-122 Install, Cement Scab liner Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 205-081 50-029-23265-00-00 457B ADL 0028256 12173 Conductor Surface Intermediate Production Liner 6732 536 3630 10192 2108 12039 13-3/8" 9-5/8" 7" 4-1/2" 6744 27 - 562 28 - 3658 26 - 10217 9974 - 12082 2539 26 - 561 28 - 3136 26 - 6738 6619 - 6741 none 2260 3090 5410 7500 none 5020 5750 7240 8430 10220 - 12030 4-1/2" 12.6# x 3-1/2" 9.2# L80 24 - 99796739 - 6745 Structural 80 20" X 34" 27 - 107 26 - 106 2280 770 3-1/2" Baker Premier No SSSV 9920, 6592 Date: Torin Roschinger Area Operations Manager Claire Mayfield Claire.Mayfield@hilcorp.com 907-564-4375 PRUDHOE BAY 6/29/2023 Current Pools: AURORA OIL Proposed Pools: AURORA OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 10/2022 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 11:46 am, Jun 22, 2023 323-357 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.06.22 11:30:19 -08'00' Torin Roschinger (4662) 10-404 Perforate DSR-6/23/23MDG 6/23/2023 ADL0028257, ADL0047448 MGR22JUN23 2539 BWH 6/26/23 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2023.06.26 11:51:50 -08'00'06/26/23 RBDMS JSB 062723 Cement Scab Liner Well: S-122 PTD: 205-081 Well Name:S-122 API Number:50-029-23265-00 Current Status:Producer Estimated Start Date:6/29/2023 Rig:Thunderbird 1 Sundry #323-315, TBD Date Reg. Approval Rec’vd:6/9/23, TBD Regulatory Contact:Abbie Barker Permit to Drill Number:205-081 First Call Engineer:Claire Mayfield (907) 564-4375 (O)(713) 443-3631 (M) Second Call Engineer:Brodie Wages (907) 564-5006 (O)(713) 380-9836 (M) Rev.2 (changed fullbore cement job to coil cement job) Current Bottom Hole Pressure:3209 psi @ 6700 TVD 9.21 PPG | (06/15/2022 static) 11.1 PPG with 2500’ diesel freeze protect Max. Anticipated Surface Pressure:2539 psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:500 psi (Taken on 11/27/21) Min ID:2.813” @ 9856’ Sliding Sleeve Max Angle:99 Deg @ 11200’ MD 70 deg: 10269’ MD High DLS from 10269-10332 MD Formation Tops: HRZ: 9979’ MD, 6622’ TVD Kalubik: 10197’ MD, 6728’ TVD Kuparuk: 10207’MD, 6733’TVD MITs: CMIT: 2250 psi on 4/27/2016 MIT-IA: 2633 psi on 5/28/2016 Objective: x RWO pull tubing, run 3-1/4” liner deployed with 4-1/2” tubing to isolate high water cut perfs x Coil cement liner post RWO x Coil perforate toe post RWO prep for future frac Brief Well Summary: S-122 is a Kuparuk producer that was drilled in 2005. The well has a ~2000ft horizontal cemented liner in the Kuparuk with 1140’ of perforations in 12 intervals. The well has consistently made ~3000bfpd but the water cut increased from ~50% to ~90% between 2005 and 2013. In 2013, a PPROF log was run along the liner and found the heel-ward perfs to be making the majority of the production and most of the water. The toe perfs showed the lowest rate but ~100% oil. The supporting water injectors around S-122 are much closer to the heel rather than the toe, which further supports the theory that the heel perfs are more swept than the toe perfs. The well was treated with acid for scale in 2011 and 2014 but neither caused flow rates to change significantly. Going forward, the plan is to isolate all perfs except the deepest perf interval at the toe with a cemented scab liner, then perform a single stage frac through the liner to stimulate production at the toe. The existing 3-1/2” tubing will be removed, and the new completion will include a 3-1/4” scab liner deployed beneath 4-1/2” tubing. then perform a single stage frac through the liner to stimulate production at the toe. Cement Scab Liner Well: S-122 PTD: 205-081 S-122 Drilling History: The S-122 well was spudded on July 30, 2005. The 20” conductor, previously set at 80’ MD, was cleaned out with a12 ¼” bit however upon drilling the first several hundred feet, several S pad wells (S-216, S-117, S-120) showed signs that S-122 drilling was communicating to their 20” x 9-5/8” annuluses. Work was stopped and after discussions with the AOGCC, it was decided to run a 13 3/8” casing string from surface to 535’ to isolate S-122 from other nearby wells on the pad. The 12 ¼” BHA was pulled, a 16” bit picked up, and the hole opened to 16” to 535’ MD. Thirteen joints of 68# L- 80 BTC 13 3/8” casing were run to 532’. The casing was cemented with 148 bbls of 15.7 ppg Arctic Set l cement, with returns to surface. The diverter was nippled down, the well head dressed, and the 20”x 9 5/8” annulus topped off with 1.5 bbls of cement. The diverter was nippled back up in preparation to drill ahead. The 12 ¼” hole drilled ahead to the base shales in SV2 to set casing at 3665” MD (-2819’ Tvdss). 9 5/8” casing was run to 3658’ MD (40 # L-80/K-55/L-80 ERW. The casing was cemented with 341 bbls of 10.7 ppg Arctic Lite lead cement and 98 bbls 15.8 ppg tail slurry. Returns were to surface and the plug bumped and 1500 psi held for 5 minutes. An 8 ¾” BHA was assembled and run in hole, drilling out the shoe and new formation down to 3685 MD. Following a FIT test to 12.2# EMW, drilling resumed in the intermediate hole section. TD for the intermediate pilot hole was called in the Kuparuk B at 10731 MD, 6985 TVD, 6921 TVDSS. 7” casing was run to 10701 MD, set and cemented with 232 bbls of Arctic lite cement. A plug was set at 10233’ MD, then awhipstock was set on top of the plug at 10217’ MD. The window was milled from 10217-10229’ MD near the top of the Kuparuk in the C3C interval. The 6.125” build section was drilledto 86º by 10345 MD, 6711 TVDSS. The lateral BHA was tripped in the hole and drilled upward into the overlying C3C before abruptly entering the HRZ at 10700 MD, 6749 TVD, 6685 TVDSS, and a decision was made to sidetrack so as to avoid exposed HRZ shales in the wellbore. Total depth encountered in the PB-2 hole was 10854 MD, 6750 TVD, 6685 TVDSS. The drill string was pulled back to 10420 MD, and trenching commenced for a low side sidetrack. By 10450 MD, the sidetrack had successfully kicked off, and the well drilled ahead, maintaining a sub horizontal profile in the C3B interval at 6765-70 TVD, 6700-6705 TVDSS. At 10836 MD, the well abruptly reentered the HRZ. This time, while discussing options with town, the well was steered downward, and abruptly reentered the C3B at 10994 MD, 6771 TVD, 6707 TVDSS. Drilling continued while dropping in the section, but with HRZ shales exposed, the decision was made to plug back this section of the well, and attempt to pass underneath the erosional surface. TD of PB #3 was called at 11460 MD, 6804 TVD, 6739 TVDSS in C2E sands. A sidetrack was successfully kicked off by 10380 MD. The sidetrack was drilled ahead to 12084 MD, 6740 TVD, 6676 TVDSS, when the wellbore exited the TKUP. Final TD for the well was called at 12173 MD, 6732 TVD, 6668 TVDSS in the HRZ. After laying down the BHA, the 4.5” liner was run in the hole and cemented with 57bbls 15.8 ppg Class G cement with gasblok. After displacing the cement, the plug bumped and increased pressure to 3500psi to set the hanger. Released from hanger and circulated out cement with 23 bbls cement returned to surface indicating good cement job. The rig perforated 12 intervals with 2 ½” 6spf guns underbalanced by 200psi. Notes Regarding Wellbore Condition x 5/2/2006: CTU set IBP at 10270’ x 7/11/2009: CTU pulled IBP x 11/13/2010: CTU mill scale, had to cut coil during ops Cement Scab Liner Well: S-122 PTD: 205-081 x 3/13/2011: CTU fished cut coil x 3/29/2011: Acid wash x 5/2/2011: SIT x 6/15/2012: EL Tractor PPROF x 12/19/2014: CTU mill scale, acid treatment x 1/4/2015: SIT x 4/26/2016: GLV C/O DHD 1. Obtain updated pressure tests on WH seals Slickline & Fullbore 6. Drift to deviation for 3-1/2” S plug, broach scale as needed 7. Set plug in X nipple at 9967’ MD 8. Dummy stations 3 & 4 9. Pull Sta. 2 S/O 10. Load tbg & IA with 1% KCl or SW + Freeze protect a. Total IA volume to St#1: 227 bbls b. Tubing volume to lowest X nip: 118 bbls c. Freeze protect volume to 2500’: tbg + IA = 38 + 47bbls = 85 bbls 11. Set dummy in Sta. 2 12. Obtain 3500 psi CMIT 13. Obtain 3500 psi MIT-IA, hold 1000psi on tubing 14. Obtain 3500 psi MIT-T, hold 1000psi on IA 15. Bleed off tubing and IA. 16. Pull X plug ----------------------------------------------Sundry Required Before Proceeding-------------------------------------------------- Eline & Fullbore 1. MU mechanical tubing cutter and RIH. Correlate to tubing tally dated 8/20/2005 (attached). 2. Pick up and cut in the packer cut zone a. The Premier packer is cut to release b. The window is 21” long starting 47” from the top of the upper pin threads, see drawing (attached) c. Contact OE Claire Mayfield 1(713)443-3631 prior to cut for final approval of tie in. d. Correlate to Tubing Tally dated 08/20/05. 3. Fullbore confirm good packer release by establishing circulation around the packer on the IA a. Pump 30 bbls freeze protect down IA at 1-2 bpm, do not exceed 3500psi i. Note: drilling was able to reverse circulate 120 bbls of 9.7 ppg brine at 3bpm and 475psi after landing the tubing but before setting the baker premier packer Cement Scab Liner Well: S-122 PTD: 205-081 b. Call OE Claire Mayfield at 713-443-3631 if injectivity/circulation is not confirmed or is tight (contingent hole punch and/or caliper if cannot confirm packer released) 4. RDMO Eline. Pre-RWO*Note: Depending on timing of rig move, well kill and BOP installation steps may be performed on rig rather than pre-rig. Most recent static was obtained in 2022 and measured 3209 psi @ 6700 TVD after 15 days SI. This equates to 9.21 PPG KWF for the entire well, but if diesel is used as freeze protect to 2500’, the required KWF below the diesel is 11.1 ppg. Recommend circulating KWF just before rig arrives to enable consistent use of 9.8 brine as kill weight fluid. 9.8ppg fluid will overbalance the well by 200psi. 1. Spot Pump Truck, RU and PT. a. Circulate in at least 395 bbls of 9.8ppg brine around tubing tail b. Annular Volume to tubing tail: 226 bbls c. Tubing Volume to tubing tail: 118 bbls d. Total volume to tubing tail: 344 bbls 1. RDMOpumpers 2. RD well house and flowlines. Clear and level area around well. 3. Set BPV w/insert (TWC) and test. ND Tree and THA. 4. NU BOPE configured top down: Annular, 2-7/8” x 5-1/2” VBRs, Blinds and integral flow cross. RWO Procedure: 1. MIRU Thunderbird 1 workover rig and ancillary equipment 2. Bleed TBG/IA pressures to ~0psi. Kill well w/9.8ppg brine as needed. 3. Test BOPE to 250 psi Low/ 3,000 psi High, annular to 250 psi Low/ 2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Notify AOGCC 24 hours in advance of BOP test. b. Perform Test per “Thunderbird 1 Test Procedure” c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR ram and Annular on 2-7/8” and 4-1/2”test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 4. Pull TWC insert and BPV. a. Assess risk of pressure under the valve and utilize lubricator for BPV removal if potential for trapped pressure exists. 5. MU landing joint or spear, BOLDS and PU on the tubing hanger. a. ~4806’ of 4-1/2” 12.6# and 5173’ of 3-1/2” 9.2# tubing weighs ~ 92klbs (buoyed by 9.8 ppg fluid) b. If pulled up to 165 Klbs (80% of 3-1/2” yield strength) with no hanger movement, RU eline and perform 2nd tubing cut, discuss with OE. 6. POOH and lay down the completion. 7. Rig up SL if bands/clamps were lost while pulling completion, Cement Scab Liner Well: S-122 PTD: 205-081 8. MU ~3.80” mill to drift/clean out4-1/2” liner for new 3-1/4” completion to PBTD. 9. PU 4-1/2” x 3-1/4” completion and run per S-122 Proposed Completion Running Order. a. Load IA with inhibited KWF brine b. Land tubing with production packer @ ~9900’ MD c. Ensure shear valve installed in deepest GLM 10. Land the tubing hanger and RILDS. Lay down landing joint. Note Pick-up and slack-off weights on tally. 11. Ensure we do not exceed a DP of 1200psi on the tubing to IA, a DP of 1360 psi will preset the packer before cementing 12. Bleed tubing pressure back to ~0 psi. Set BPV with TWC insert. 13. Since packer will be set post rig, test tubing hanger void to 2500 psi by closing blinds on BOP. 14. RDMOThunderbird 1 WO Rig and ancillary equipment. Move to next well location. 15. RU crane. ND BOPE. 16. NU the tubing head adapter and tree. Test tubing hanger void and tree to 500 psi low/5,000 psi high. 17. Pull BPV with TWC insert. 18. Replace wellhouse and gauge(s) if removed.ALL RWO Activity Complete 6/19/23 Post-Rig Procedure (10-403 Change to Approved Program Sundry approval required before proceeding): Coil 1. MIRU, PT. 2. Have hardline crew rig up return line from IA with tee: one end going to choke manifold and other end for pump truck hookup. Initially line up to take returns from IA through the choke skid. 3. RIH with NSAK 1 trip 2-7/8” cement retainer 4. Set cement retainer at ~11950’ MD at the toe of the liner 5. Pressure test coil x tubing annulus to 500 psi above IA pressure to ensure retainer set (do not exceed DP > ~900psi across tbg x IA, start to set pressure of packer is 1360 psi) 2. RU Cementers, PT lines to leaktight at 4700 psi, set pump trips at 4700 psi 3. Line up cementers to pump down the coil, pump as follows at max rate taking returns up IA: a. ~180 bbl diesel (minimum 165 bbls diesel to circ out completion brine) b. 20 bbl CI freshwater spacer c. 11 bbls cement d. 5 bbl freshwater spacer e. 10-15 bbls Contam pill f. Powervis pill or 1% KCL for tubing cleanout – as needed Cement Blend Details: Density, ppg 15.3 (+/- 0.25 ppg) Fluid Loss (mL/30 min):100-200 Free water (mL):0 Rheology:Yield Point: 15-25 Thickening Time (HRS):7-8 hours Mix on the fly WSL Preference 8-9 hours Batch Mixed WSL Preference Cement Scab Liner Well: S-122 PTD: 205-081 Compressive Strength:Minimum 500 psi achieved 4. With 10bbls cement behind pipe through retainer, close the IA return line. IA pressure should be between ~500-1000psi. 5. Line up pump to tubing, pressure up the tubing x coil annulus, set packer by pressuring up tubing to 3000psi (packer should set at 2750psi, but can go up to 4000 psi on tubing if needed). 6. Line up pump back to coil reel, can squeeze ~ ½ of last bbl of cement through retainer, but unsting before water spacer gets to bottom of coil 7. Unsting from retainer, pump freshwater displacement followed by contam pill and 1% KCL as needed to chase out any remaining cement from the liner and up tubing. 8. Once coil has cleaned out the liner, pull up to above GLM station 1. 9. Have pump truck lined up to IA, pressure up IA to 3000psi to shear the SOV in GLM Sta. 1. (SOV should shear with ~2750psi, but IA pressure can go up to 3600 psi if needed). 10. After valve has sheared, have pump truck pump down IA with ~30 bbls crude or diesel at 3-5 bpm. Then go down to minimum rates (1/4 bpm) to keep pressure on IA while coil finishes cleaning out tubing. 11. Once cleanout is complete, confirm cement thickening time and compressive strength with cement engineer to make call on whether to RDMO to WOC or continue with job to log and add perfs. 12. Once cement is at compressive strength, RIH with GR/CCL and nozzle to PBTD. Flag coil as needed. POOH for tie in (Tie in Log: S-122 2012-06-16 PDS Production Profile Log). 13. MU 30’ of 2.5” max force guns (large hole size), 6spf, 60deg phase – priority on large hole size for frac 14. Perforate 11800-11830’ md 15. POOH. Consider freeze protect pending portable testers timing. Slickline 1. Spot Slickline unit, RU and PT. 2. Set LGLV’s. Portable Test Unit 3. POP well 4. Initially use 0.5 – 1 mmscfd gas lift, monitor returns for solids 5. Piggyback test with pad separator. NOTE: A separate frac sundry and program will be submitted. This program only covers the RWO. Details to be included in future frac program that will require a frac sundry: 1. Slickline dummy GLVs, load hole with 1% KCl and freeze protect, obtain 3500 psi MIT-IA 2. Special Projects frac well 3. Slickline install LGLVs 4. Contingent post frac coil FCO 5. Well testers POP well for frac flowback 6. Handover to OPs Perforate 11800-11830’ md Cement Scab Liner Well: S-122 PTD: 205-081 Current WBD: Cement Scab Liner Well: S-122 PTD: 205-081 Proposed WBD: Cement Scab Liner Well: S-122 PTD: 205-081 Thunderbird 1 BOP Schematic 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will planned perforations require a spacing exception?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStrastigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other: Post Initial Injection MIT Req'd? Spacing Exception Required?Yes Yes No No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU S-122 Install, Cement Scab liner Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 205-081 50-029-23265-00-00 457B ADL 0028256 12173 Conductor Surface Intermediate Production Liner 6732 536 3630 10192 2108 12039 13-3/8" 9-5/8" 7" 4-1/2" 6744 27 - 562 28 - 3658 26 - 10217 9974 - 12082 2539 26 - 561 28 - 3136 26 - 6738 6619 - 6741 none 2260 3090 5410 7500 none 5020 5750 7240 8430 10220 - 12030 4-1/2" 12.6# x 3-1/2" 9.2# L80 24 - 99796739 - 6745 Structural 80 20" X 34" 27 - 107 26 - 106 2280 770 3-1/2" Baker Premier No SSSV 9920, 6592 Date: Torin Roschinger Area Operations Manager Claire Mayfield Claire.Mayfield@hilcorp.com 907-564-4375 PRUDHOE BAY 6/15/2023 Current Pools: AURORA OIL Proposed Pools: AURORA OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 10/2022 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 3:49 pm, May 30, 2023 323-315 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.05.30 14:34:08 -08'00' Torin Roschinger (4662) X 2539 BOPE test to 3000 psi. Annular to 2500 psi. 10-404 MGR31MAY23 SFD 6/8/2023 DSR-5/31/23GCW 06/09/2023 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2023.06.09 08:45:32 -08'00'06/09/23 RBDMS JSB 060923 Run Scab Liner Well: S-122 PTD: 205-081 Well Name:S-122 API Number:50-029-23265-00 Current Status:Producer Estimated Start Date:6/15/2023 Rig:Thunderbird 1 Sundry #Date Reg. Approval Rec’vd: Regulatory Contact:Abbie Barker Permit to Drill Number:205-081 First Call Engineer:Claire Mayfield (907) 564-4375 (O)(713) 443-3631 (M) Second Call Engineer:Brodie Wages (907) 564-5006 (O)(713) 380-9836 (M) Current Bottom Hole Pressure:3209 psi @ 6700 TVD 9.21 PPG | (06/15/2022 static) 11.1 PPG with 2500’ diesel freeze protect Max. Anticipated Surface Pressure:2539 psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:500 psi (Taken on 11/27/21) Min ID:2.813” @ 9856’ Sliding Sleeve Max Angle:99 Deg @ 11200’ MD 70 deg: 10269’ MD High DLS from 10269-10332 MD Formation Tops: HRZ: 9979’ MD, 6622’ TVD Kalubik: 10197’ MD, 6728’ TVD Kuparuk: 10207’MD, 6733’TVD MITs: CMIT: 2250 psi on 4/27/2016 MIT-IA: 2633 psi on 5/28/2016 Objective: x RWO pull tubing, run 3-1/4” liner deployed with 4-1/2” tubing to isolate high water cut perfs x Fullbore cement liner post RWO x Coil perforate toe post RWO prep for future frac Brief Well Summary: S-122 is a Kuparuk producer that was drilled in 2005. The well has a ~2000ft horizontal cemented liner in the Kuparuk with 1140’ of perforations in 12 intervals. The well has consistently made ~3000bfpd but the water cut increased from ~50% to ~90% between 2005 and 2013. In 2013, a PPROF log was run along the liner and found the heel-ward perfs to be making the majority of the production and most of the water. The toe perfs showed the lowest rate but ~100% oil. The supporting water injectors around S-122 are much closer to the heel rather than the toe, which further supports the theory that the heel perfs are more swept than the toe perfs. The well was treated with acid for scale in 2011 and 2014 but neither caused flow rates to change significantly. Going forward, the plan is to isolate all perfs except the deepest perf interval at the toe with a cemented scab liner, then perform a single stage frac through the liner to stimulate production at the toe. The existing 3-1/2” tubing will be removed, and the new completion will include a 3-1/4” scab liner deployed beneath 4-1/2” tubing. S-122 Drilling History: The S-122 well was spudded on July 30, 2005. The 20” conductor, previously set at 80’ MD, was cleaned out with a 12 ¼” bithowever upon drilling the first several hundred feet, several S pad wells (S-216, S-117, S-120) showed signs that S-122 drilling was communicating to their 20” x 9-5/8” annuluses. Work was stopped and after discussions with the AOGCC, it was decided to run a 13 3/8” casing string from surface to 535’ to isolate S-122 from other nearby wells on the pad. 11.1 PPG perform a single stage frac through the liner to stimulate production at the toe. |9.21 PPG Run Scab Liner Well: S-122 PTD: 205-081 The 12 ¼” BHA was pulled, a 16” bit picked up, and the hole opened to 16” to 535’ MD. Thirteen joints of 68# L- 80 BTC 13 3/8” casing were run to 532’. The casing was cemented with 148 bbls of 15.7 ppg Arctic Set l cement, with returns to surface. The diverter was nippled down, the well head dressed, and the 20”x 9 5/8” annulus topped off with 1.5 bbls of cement. The diverter was nippled back up in preparation to drill ahead. The 12 ¼” hole drilled ahead to the base shales in SV2 to set casing at 3665” MD (-2819’ Tvdss). 9 5/8” casing was run to 3658’ MD (40 # L-80/K-55/L-80 ERW. The casing was cemented with 341 bbls of 10.7 ppg Arctic Lite lead cement and 98 bbls 15.8 ppg tailslurry. Returns were to surface and the plug bumped and 1500 psi held for 5 minutes. An 8 ¾” BHA was assembled and run in hole, drilling out the shoe and new formation down to 3685 MD. Following a FIT test to 12.2# EMW, drilling resumed in the intermediate hole section. TD for the intermediate pilot hole was called in the Kuparuk B at 10731 MD, 6985 TVD, 6921 TVDSS. 7” casing was run to 10701 MD, set and cemented with 232 bbls of Arctic lite cement. A plug was set at 10233’ MD, thena whipstockwas set on top of the plug at 10217’ MD. Thewindow was milled from 10217-10229’MD near the top of the Kuparuk in the C3C interval. The 6.125” build section was drilledto 86º by 10345 MD, 6711 TVDSS. The lateral BHA was tripped in the hole and drilledupward into the overlying C3C before abruptly entering the HRZ at 10700 MD, 6749 TVD, 6685 TVDSS,and a decision was made to sidetrack so as to avoid exposed HRZ shales in the wellbore. Total depth encountered in the PB-2 hole was 10854 MD, 6750 TVD, 6685 TVDSS. The drill string was pulled back to 10420 MD, and trenching commenced for a low side sidetrack. By 10450 MD, the sidetrack had successfully kicked off, and the well drilled ahead, maintaining a sub horizontal profile in the C3B interval at 6765-70 TVD, 6700-6705 TVDSS. At 10836 MD, the well abruptly reentered the HRZ. This time, while discussing options with town, the well was steered downward, and abruptly reentered the C3B at 10994 MD, 6771 TVD, 6707 TVDSS. Drilling continued while dropping in the section, but with HRZ shales exposed, the decision was made to plug back this section of the well, and attempt to pass underneath the erosional surface. TD of PB #3 was called at 11460 MD, 6804 TVD, 6739 TVDSS in C2E sands. A sidetrack was successfully kicked off by 10380 MD. The sidetrack was drilled ahead to 12084 MD, 6740 TVD, 6676 TVDSS, when the wellbore exited the TKUP. Final TD for the well was called at 12173 MD, 6732 TVD, 6668 TVDSS in the HRZ. After laying down the BHA, the 4.5” liner was run in the hole and cemented with 57bbls 15.8 ppg Class G cement with gasblok. After displacing the cement, the plug bumped and increased pressure to 3500psi to set the hanger. Released from hanger and circulated out cement with 23 bbls cement returned to surface indicating good cement job. The rig perforated 12 intervals with 2 ½” 6spf guns underbalanced by 200psi. Notes Regarding Wellbore Condition x 5/2/2006: CTU set IBP at 10270’ x 7/11/2009: CTU pulled IBP x 11/13/2010: CTU mill scale, had to cut coil during ops x 3/13/2011: CTU fished cut coil x 3/29/2011: Acid wash x 5/2/2011: SIT x 6/15/2012: EL Tractor PPROF x 12/19/2014: CTU mill scale, acid treatment x 1/4/2015: SIT x 4/26/2016: GLV C/O Run Scab Liner Well: S-122 PTD: 205-081 DHD 1. Obtain updated pressure tests on WH seals Slickline & Fullbore 6. Drift to deviation for 3-1/2” X plug, broach scale as needed 7. Set plug in X nipple at 9967’ MD 8. Dummy stations 3 & 4 9. Pull Sta. 2 S/O 10. Load tbg & IA with 1% KCl or SW + Freeze protect a. Total IA volume to St#1: 227 bbls b. Tubing volume to lowest X nip: 118 bbls c. Freeze protect volume to 2500’: tbg + IA = 38 + 47bbls = 85 bbls 11. Set dummy in Sta. 2 12. Obtain 3500 psi CMIT 13. Obtain 3500 psi MIT-IA, hold 1000psi on tubing 14. Obtain 3500 psi MIT-T, hold 1000psi on IA 15. Bleed off tubing and IA. 16. Pull X plug ----------------------------------------------Sundry Required Before Proceeding-------------------------------------------------- Eline & Fullbore 1. MU mechanical tubing cutter and RIH. Correlate to tubing tally dated 8/20/2005 (attached). 2. Pick up and cut in the packer cut zone a. The Premier packer is cut to release b. The window is 21” long starting 47” from the top of the upper pin threads, see drawing (attached) c. Contact OE Claire Mayfield 1(713)443-3631 prior to cut for final approval of tie in. d. Correlate to Tubing Tally dated 08/20/05. 3. Fullbore confirm good packer release by establishing circulation around the packer on the IA a. Pump 30 bbls freeze protect down IA at 1-2 bpm, do not exceed 3500psi i. Note: drilling was able to reverse circulate 120 bbls of 9.7 ppg brine at 3bpm and 475psi after landing the tubing but before setting the baker premier packer b. Call OE Claire Mayfield at 713-443-3631 if injectivity/circulation is not confirmed or is tight (contingent hole punch and/or caliper if cannot confirm packer released) 4. RDMO Eline. Pre-RWO*Note: Depending on timing of rig move, well kill and BOP installation steps may be performed on rig rather than pre-rig. Most recent static was obtained in 2022 and measured 3209 psi @ 6700 TVD after 15 days SI. This equates to 9.21 PPG KWF for the entire well, but if diesel is used as freeze protect to 2500’, the required KWF below the diesel is 11.1 ppg. Recommend circulating KWF just before rig arrives to enable consistent use of 9.8 brine as kill weight fluid. 9.8ppg fluid will overbalance the well by 200psi. 3209 psi @ 6700 TVD a Run Scab Liner Well: S-122 PTD: 205-081 1. Spot Pump Truck, RU and PT. a. Circulate in at least 395 bbls of 9.8ppg brine around tubing tail b. Annular Volume to tubing tail: 226 bbls c. Tubing Volume to tubing tail: 118 bbls d. Total volume to tubing tail: 344 bbls 1. RDMO pumpers 2. RD well house and flowlines. Clear and level area around well. 3. Set BPV w/insert (TWC) and test. ND Tree and THA. 4. NU BOPE configured top down: Annular, 2-7/8” x 5-1/2” VBRs, Blinds and integral flow cross. RWO Procedure: 1. MIRU Thunderbird 1 workover rig and ancillary equipment 2. Bleed TBG/IA pressures to ~0psi. Kill well w/9.8ppg brine as needed. 3. Test BOPE to 250 psi Low/ 3,000 psi High, annular to 250 psi Low/ 2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Notify AOGCC 24 hours in advance of BOP test. b. Perform Test per “Thunderbird 1 Test Procedure” c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR ram and Annular on 2-7/8” and 4-1/2”test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 4. Pull TWC insert and BPV. a. Assess risk of pressure under the valve and utilize lubricator for BPV removal if potential for trapped pressure exists. 5. MU landing joint or spear, BOLDS and PU on the tubing hanger. a. ~4806’ of 4-1/2” 12.6# and 5173’ of 3-1/2” 9.2# tubing weighs ~ 92klbs (buoyed by 9.8 ppg fluid) b. If pulled up to 165 Klbs (80% of 3-1/2” yield strength) with no hanger movement, RU eline and perform 2nd tubing cut, discuss with OE. 6. POOH and lay down the completion. 7. Rig up SL if bands/clamps were lost while pulling completion, 8. MU ~3.80” mill to drift/clean out 4-1/2” liner for new 3-1/4” completion to PBTD. 9. PU 4-1/2” x 3-1/4” completion and run per S-122 Proposed Completion Running Order. a. Load IA with inhibited KWF brine b. Land tubing with production packer @ ~9900’ MD c. Ensure shear valve installed in deepest GLM 10. Land the tubing hanger and RILDS. Lay down landing joint. Note Pick-up and slack-off weights on tally. 11. Bullhead freeze protect down IA and down tubing to ~2500’ MD. Do not exceed tubing to IA differential pressure greater than 3000psi while pumping. 12. Bleed tubing pressure back to ~0 psi. Set BPV with TWC insert. 13. Since packer will be set post rig, test tubing hanger void to 2500 psi by closing blinds on BOP. 14. RDMO Thunderbird 1 WO Rig and ancillary equipment. Move to next well location. Run Scab Liner Well: S-122 PTD: 205-081 15. RU crane. ND BOPE. 16. NU the tubing head adapter and tree. Test tubing hanger void and tree to 500 psi low/5,000 psi high. 17. Pull BPV with TWC insert. 18. Replace wellhouse and gauge(s) if removed. Post-Rig Procedure: Fullbore w/ SL standing by 1. Circulate well tbg to IA with diesel, note pump pressure required for 1-2bpm. 2. RU Cementers, PT lines to leaktight at 4700 psi, set pump trips at 4700 psi 3. Line up cementers and pump cement as follows at max rate not exceeding 3000psi on tbg: a. 5 bbl freshwater spacer b. 10 bbls cement c. Drop plug d. 15bbl contam pill e. ~153bbl 1% KCL displacement until bumping plug Cement Blend Details: Density, ppg 15.3 (+/- 0.25 ppg) Fluid Loss (mL/30 min):100-200 Free water (mL):0 Rheology:Yield Point: 15-25 Thickening Time (HRS):7-8 hours Mix on the fly WSL Preference 8-9 hours Batch Mixed WSL Preference Compressive Strength:Minimum 500 psi achieved 4. Once plug bumps (167bbl total estimated displacement), set packer by pressuring up tubing ~3500psi. a. If cannot pressure up to 3500psi with float shoe plug, RIH with SL and set set X plug in lower nipple profile at ~9920’ MD below packer, then re-attempt packer set. 5. Shear circ valve in lower GLM just above packer to circulate out remaining cement in IA. 6. Once circulation is established, circulate second 15bbl contam pill down tubing up IA followed by 15bbl of powervis to clean up any cement in the IA above GLMs. 7. Once returns are clean, circulate in or u-tube freeze protect on tubing and IA to ~2500’. Slickline Pending 1. Spot Slickline unit, RU and PT. 2. Set LGLV’s. 3. RIH and pull plug from X profile at ±9920’ MD if needed. Coil 1. Rig up coil 2. RIH with GR/CCL and nozzle to PBTD. Flag coil as needed. POOH for tie in. 3. MU 30’ of 2.5” max force guns (large hole size), 6spf, 60deg phase – priority on large hole size for frac 4. Perforate 11,800' to 11,830' MD per Claire Mayfield. SFD 6/8/2023Perforate Run Scab Liner Well: S-122 PTD: 205-081 5. POOH. Operations 4. POP well 5. Obtain AOGCC witnessed SVS test within 5 days of putting well online. NOTE: A separate frac sundry and program will be submitted. This program only covers the RWO. Details to be included in future frac program that will require a frac sundry: 1. Slickline dummy GLVs, load hole with 1% KCl and freeze protect, obtain 3500 psi MIT-IA 2. Special Projects frac well 3. Slickline install LGLVs 4. Contingent post frac coil FCO 5. Well testers POP well for frac flowback 6. Handover to Ops Attachments: x Current Wellbore Schematic x Proposed Wellbore Schematic x TB-1 BOP Schematic x Baker Premier Packer Diagram x Current Tubing Tally x Sundry Change Form Run Scab Liner Well: S-122 PTD: 205-081 Current WBD: Run Scab Liner Well: S-122 PTD: 205-081 Proposed WBD: Run Scab Liner Well: S-122 PTD: 205-081 Thunderbird 1 BOP Schematic Run Scab Liner Well: S-122 PTD: 205-081 Baker Premier Packer Schematic Run Scab Liner Well: S-122 PTD: 205-081 Current Tubing Tally Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Rig Workover Sundry ProcedureDate: May 30, 2023Subject: Changes to Approved Sundry Procedure for Well S-122Sundry #:Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.StepPageDate Procedure ChangeHNSPreparedBy (Initials)HNSApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date 0 • pro 07 0 5---el I Loepp, Victoria T (DOA) From: Regg,James B (DOA) Sent: Monday,April 30, 2018 1:37 PM To: Loepp,Victoria T(DOA) Subject: FW: Producer J-01B (PTD#2022010) Similar Construction Geometry to 02-03 Follow Up Flag: Follow up Flag Status: Flagged f. Jim Regg Supervisor, Inspections AOGCC 333 W.7tt'Ave,Suite 100 Anchorage,AK 99501 907-793-1236 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 informaticin. 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 Jim Regg at 907- 793-1236 or iim.regg@alaska.gov. From:AK,GWO SUPT Well Integrity<AKDCWelllntegrityCoordinator@bp.com> Sent: Monday,April 30,2018 1:35 PM To: Regg,James B(DOA)<jim.regg@alaska.gov> Cc: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov>; Foerster,Catherine P(DOA)<cathy.foerster@alaska.gov>; Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov>; Rixse, Melvin G (DOA)<melvin.rixse@alaska.gov>; Daniel, Ryan <Ryan.Daniel@bp.com>; Cismoski, Doug A<CismosDA@BP.com>; Romo, Louis A<Louis.Romo@bp.com>;AK,GWO Well Integrity Engineer<AKGWOWellSiteEnginee@bp.com> Subject: RE: Producer1-01B(PTD#2022010)Similar Construction Geometry to 02-03 Jim, Per my voicemail,we will reclassify the wells with gravel protection strings Not Operable: • Producer S-122 (13T6 2050810 .• Injector W-209 (PTD 2031280) • Injector W-214(PTD 2071420) • Injector W-216(PTD 2071680) Our surface casing depth verification project identified 2 other wells with surface casing set in the permafrost(both Lcng Term Shut Ins): • Producer E-28A(PTD 1990610)—will reclassify Not Operable • Injector M-01(PTD 1690780)—already Not Operable due to remaining shut in past its 4-year witnessed test date BPXA's Tubular Design Advisor will review all of these wells. Upon completion,we'll present the findings to the AOGCC. In the meantime,all will remain Not Operable and shut in. 1 Thanks, • • Adrienne McVey Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) 0:(907)659-5102 C:(907)943-0296 H:2376 From: Regg,James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Friday, April 27, 2018 2:18 PM To: AK, GWO SUPT Well Integrity Cc: Loepp, Victoria T(DOA); Foerster, Catherine P (DOA); Schwartz, Guy L(DOA); Rixse, Melvin G (DOA) Subject: RE: Producer J-01B(PTD #2022010) Similar Construction Geometry to 02-03 Thank you for the follow-up email. Just to be clear,are the S-pad and W-pad wells with gravel protection strings also going to be reclassified as"not operable"to verify they are not at risk for failure like PBU 02-03B? When BP is finished with the reviews of the wells, please arrange for a meeting to present your findings to the AOGCC. That can be coordinated with Victoria. Jim Regg Supervisor, Inspections AOGCC 333 With Ave,Suite 100 Anchorage,AK 99501 907-793-1236 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 Jim Regg at 907- 793-1236 or iim.regg@alaska.gov. From:AK,GWO SUPT Well Integrity<AKDCWeIIlntegrityCoordinator@bp.com> Sent: Friday,April 27,2018 1:51 PM To: Regg,James B (DOA)<jim.regg@alaska.gov> Cc: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov>; Cismoski, Doug A<CismosDA@BP.com>; Daniel, Ryan <Rvan.Daniel@bp.com>;AK, GWO Well Integrity Engineer<AKGWOWelISiteEnginee@bp.com> Subject: Producer.1-01B(PTD#2022010)Similar Construction Geometry to 02-03 Jim, To summarize our phone conversation today: • After the 02-03 incident,we reported to the AOGCC 14 wells with similar construction geometry; i.e. a 3-string casing design,and the surface casing shoe set in the permafrost. • Yesterday,we identified one additional well with similar construction geometry:J-01. • We do not believe that J-01 is at risk of an event similar to 02-03, because, unlike 02-03,all three strings of casing are anchored together with cement.We believe this eliminates the potential for differential force loading at the wellhead. 2 • • However,we are going taTeclassify J-01 Not Operable, shut it in,an ecure it, until we can perform modeling!, to verify. • We also identified 4 wells on S-Pad and W-Pad that have 13-3/8"gravel protection strings set in the permafrost, and 2 casing strings within. I'm investigating the details now, but I do not believe these wells present a risk.The 13-3/8" is a second conductor,and not coupled to the inner casing strings at the wellhead. In the event the 13,- 3/8" 3*3/8"were to subside, it would not impart a load to the inner casing strings via the wellhead. I will follow up on, these wells as soon as possible. Thanks, Adrienne McVey Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) O:(907)659-5102 C:(907)943-0296 H:2376 3 II • • 7_71 %51 WELL LOG TRANSMITTAL PROACTIVE DIAgNOSTIC SERVICES, INC. DATA LOGGED Q Ai/2016 �t C I M.K.BENDER To: AOGCC JUL 0 6 2b1‘) Makana Bender AOGCC 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Merion Kendall LR2— 1 900 Benson Blvd. Anchorage, AK 99508 dancpdc@bp.corn and ProActive Diagnostic Services, Inc. r Attn: Diane F. Williams j, NOV a R KIR 130 West International Airport Road Suite C Anchorage,AK 99518 Fax: (907) 245-8952 1) LeakPointT" Survey 28-May-16 S-122 BL/CD 50-029-23265-00 2) Signed : A.164200zikiDate Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE@U MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\Achives\MasterTemplateFiles\Templates\Distribution\TransmittalSheets\BP_Transmit.docx Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Thursday, June 02, 2016 3:05 PM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers; AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan;AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS WELL PAD S;Zoesch, Eric; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Sayers, Jessica; Dickerman, Eric; Morrison, Spencer; Munk, Corey; Odom, Kristine; Regg, James B (DOA); Pettus, Whitney; Julian, Jennifer Y; AK, OPS Gas Lift Engr; McVey, Adrienne; Zoesch, Eric;AK, D&C Well Integrity Coordinator Subject: OPERABLE: Producer S-122 (PTD#2050810) MIT-IA Proves Two Competent Barriers All- Producer S-122 (PTD#2050810) had been Not Operable for TxIA communication. The well was secured by installing a tubing tail plug and pressure testing verified two competent barriers to formation. A subsequent leak detect log located TxIA leak at the sliding sleeve. An MIT-IA passed after troubleshooting sliding sleeve. The TTP has been pulled. This well is now classified as Operable. Please mind the liquid packed annuli when putting on production. Thanks! Jack Lau (Alternate:Adrienne McVey) BP Alaska -Well Integrity Superintendent W: 907.564.5102 C: 907.943.0296 H: x2376 From: A14-.1)&C Well Integrity Coordinator Sent: Saturd y-Apr-i130, 2016 7:36 PM To: AK, OPS GC2 OSM; AK,OP&GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan;; AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS WELL PAD S; Zoesch, Eric; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Project Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Sayers, Jessica; Dickerman, Eric; Morrison`;Sencer; Munk, Corey; Odom, Kristine; 'Regg, James B (DOA)'; Pettus, Whitney; Julian, Jennifer Y; AK, OPS Gas Lift Engr;Mcyey, Adrienne Subject: NOT OPERABLE: Producer S-122 (PTD #2050810) Sustained Irine,r Annulus Casing Pressure over MOASP All, Producer S-122 (PTD#2050810) has been Under Evaluation for TxIA communication. Pressuretesting confirms TxIA communication that has not been resolved with basic slickline intervention.The well has been secu?e4 by installing a 1 • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Saturday, April 30, 2016 7:36 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers;AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Superintendent;AK, D&C Well Services Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS WELL PAD 5;Zoesch, Eric; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Sayers, Jessica; Dickerman, Eric; Morrison, Spencer; Munk, Corey; Odom, Kristine; Regg, James B (DOA); Pettus, Whitney; Julian, Jennifer Y; AK, OPS Gas Lift Engr; McVey, Adrienne Subject: NOT OPERABLE: Producer S-122 (PTD #2050810) Sustained Inner Annulus Casing Pressure over MOASP All, Producer S-122 (PTD#2050810) has been Under Evaluation for TxIA communication. Pressure testing confirms TxIA communication that has not been resolved with basic slickline intervention.The well has been secured by installing a tubing tail plug and pressure testing verifies two competent barriers to formation.The well status has been changed to Not Operable and will remain shut in until tubing integrity is restored. Please call with any questions or concerns. Thank you, Ryan Holt 9 LG 16 (Alternate:Lee Grey) BP Alaska-Well Integrity Coordinator sCl►pHEp [a1l�Y 0 G WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@BP.com From: AK, D&C�ltfell tegrity Coordinator Sent: Wednesday, April 16 2:27 PM To: AK, D&C Well Integrity Coordinator; AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; AK, OPS PCC Ops Le ismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS WELL PAD S; Zoesch, Eric; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Sayers, Jessica; Dickerman, Eric; Morrison, Spencer; Mun , rey; Odom, Kristine; 'Regg, James B (DOA)'; Pettus, Whitney; Julian, Jennifer Y; AK, OPS Gas Lift Engr; McVey, Adrienne Subject: UPDATE: UNDER EVALUATION: Producer S-122 (PTD #2050810) Sustained Inner ulus Casing Pressure over MOASP All, \. • I Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Wednesday, April 27, 2016 2:27 PM To: AK, D&C Well Integrity Coordinator;AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers;AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS WELL PAD S;Zoesch, Eric; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Sayers, Jessica; Dickerman, Eric; Morrison, Spencer; Munk, Corey; Odom, Kristine; Regg, James B (DOA); Pettus, Whitney; Julian, Jennifer Y; AK, OPS Gas Lift Engr; McVey, Adrienne Subject: UPDATE: UNDER EVALUATION: Producer S-122 (PTD#2050810) Sustained Inner Annulus Casing Pressure over MOASP All, Producer S-122 (PTD#2050810) has been Under Evaluation for 27 days. Due to frequent spells of inclement weather, and a recent field-wide power outage, diagnostic work was delayed, and the well's operability has not yet been determined.The well will remain Under Evaluation for an additional two weeks in order to complete diagnostics. Plan Forward: 1. Slickline: Set TTP, change out gas lift valves—DONE 4/25/16 2. Fullbore: Perform MIT-T& CMIT-TxIA—In Progress 3. Well Integrity Engineer: Additional diagnostics as needed Thanks, Adrienne McVey SCAMMED MAY 0 9 2016 Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) Office: (907)659-5102 Email: AKDCWellIntegrityCoordinator@BP.com From: AK, D&C Well Integrity Coordinator Sent: Thursday, March 31, 2016 3:31 PM To: AK, OPS GC2-OS1LAK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; AK, OPS PCC Ops Lead; Cismoski, Doug A;-Daniel, Ryan; AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS WELL PAD S; Zoesch, Eric; 'chris.wallace@alaska.gov' '\ Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHELIltell Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Sayers;Jessica; Dickerman, Eric; Morrison, Spencer; Munk, Corey; Odom, Kristine; 'Regg, James B (DOA)'; Pettus, Whitney; Julian, Jennifer Y; AK, OPS Gas Lift Engr Subject: UNDER EVALUATION: Producer S-122 (PTD #2050810) Sustained Inner Annulus Casing Pressure over MOASP All, Producer S-122 (PTD#2050810)was reported to have sustained inner annulus (IA) casing pressure ov OASP on March 30, 2016. The pressures were confirmed to be 2010/2010/vac psi. A warm TIFL passed on March 22, 16 but 1 • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Thursday, March 31, 2016 3:31 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers;AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan;AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr; AK, OPS WELL PAD S; Zoesch, Eric; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Sayers, Jessica; Dickerman, Eric; Morrison, Spencer; Munk, Corey; Odom, Kristine; Regg, James B (DOA); Pettus, Whitney;Julian, Jennifer Y; AK, OPS Gas Lift Engr Subject: UNDER EVALUATION: Producer S-122 (PTD #2050810) Sustained Inner Annulus Casing Pressure over MOASP All, Producer S-122 (PTD#2050810) was reported to have sustained inner annulus (IA) casing pressure over MOASP on March 30, 2016. The pressures were confirmed to be 2010/2010/vac psi. A warm TIFL passed on March 22, 2016 but the well continues to show signs of IA repressurization indicating a lack of two competent barriers in the wellbore. At this time,the well has been reclassified as Under Evaluation for additional diagnostics. Plan Forward: 1. Slickline: Set TTP, change out gas lift valves 2. Fullbore: Perform MIT-T&CMIT-TxIA 3. Well Integrity Engineer: Additional diagnostics as needed Please call with any questions or concerns. Thank you, Whitney Pettus (Alternate:Kevin Parks) �r BP Alaska Well Integrity Coordinator SCANNED APR 2016 WIC Office: 907.659.5102 WIC Email: AKDCWeIlIntegrityCoordinator@BP.com From: AK;D Well Integrity Coordinator Sent: Tuesday, March 22, 2016 7:42 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan .AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS WELL PAD S; Zoesch, Eric; 'chris.wallace@alaska.gov' '���-�_ Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well IntegrityFngineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Sayers, Jessica; Dickerman,-Eric; Glasheen, Brian P; Morrison, 1 • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Tuesday, March 22, 2016 7:42 PM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M TL;AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers; AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Superintendent;AK, D&C Well Services Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr;AK, OPS WELL PAD 5;Zoesch, Eric;Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Sayers, Jessica; Dickerman, Eric; Glasheen, Brian P; Morrison, Spencer; Munk, Corey; Odom, Kristine; Regg,James B (DOA) Subject: OPERABLE: Producer S-122 (PTD#2050810) TIFL Passed All, Producer S-122 (PTD#2050810) passed a TIFL on March 22, 2016. The passing TIFL confirms two competent downhole barriers. The well is reclassified as Operable. • Well status is Operable • A SSSV is not required Please call with any questions or concerns. Thank you, Kevin Parks (Alternate' Whitney Pert', KAMER APR 0 $ 2016 BP Alaska-Well Integrity Coordinator GINGlobal Wells Organization Office: 907.659.5102 From: AK, D&C Well Integrity Coordinator Sent-Friday, March 18, 2016 4:41 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS WELL PAD S; Zoesch, Eric; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator;yW, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver�R; Sayers, Jessica; Dickerman, Eric; Glasheen, Brian P; Morrison, Spencer; Munk, Corey; Odom, Kristine; 'Regg, Ja111eS B (DOA) (jim.regg@alaska.gov)' Subject: UNDER EVALUATION: Producer S-122 (PTD #2050810) Sustained Inner Annulus Casing Pressure Above MOASP All, Producer 5-122 (PTD#2050810)was reported to have sustained inner annulus casing pressure above MOASP on March 16, 2016. The pressures were reported to be tubing/inner annulus/outer annulus 2040/2020/0. A cold TIFL failed on March 18, 2016. The failing TIFL indicates a lack of two competent downhole barriers.The well is reclassified as Under Evaluation and is placed on a 28 day clock. 1 • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Friday, March 18, 2016 4:41 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL;AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers;AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr; AK, OPS WELL PAD 5; Zoesch, Eric;Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Sayers, Jessica; Dickerman, Eric; Glasheen, Brian P; Morrison, Spencer; Munk, Corey; Odom, Kristine; Regg, James B (DOA) Subject: UNDER EVALUATION: Producer S-122 (PTD #2050810) Sustained Inner Annulus Casing Pressure Above MOASP Attachments: Producer S-122 (PTD #2050810) TIO Plot.docx All, Producer S-122 (PTD#2050810)was reported to have sustained inner annulus casing pressure above MOASP on March 16, 2016. The pressures were reported to be tubing/inner annulus/outer annulus 2040/2020/0. A cold TIFL failed on March 18, 2016. The failing TIFL indicates a lack of two competent downhole barriers.The well is reclassified as Under Evaluation and is placed on a 28 day clock. Plan forward: 1. Operations: Place well on production 2. DHD: Re-TIFL 3. Slickline: Change out orifice gas lift valve (if necessary) W MAR 2 1 2016 SCO A copy of the TIO plot is included for reference. Thank you, Kevin Parks (Alternate: Whitney Pettus, BP Alaska-Well Integrity Coordinator GWGlobal Wells Organization Office: 907.659.5102 WIC Email:AKDCWellIntegrityCoordinator@bp.com 1 • • Producer S-122 (PTD#2050810)TIO Plot —0—Y» —x mom p.N+6 p�Ti'+4 Ot^1N P.Ya'N N,Y4'+f pfpi'%p+.x r{@x+x GwTx ptuft tlP.M @529%tl if+4 pY.3Y tlx%p2n.M�N%0..t%p51Y2 4'db%p3Y.'N pi0.f p3lDN pJpi%d126•u 9W{'+i M+JY6 p9tdfi pYfa%O1Y4x N'+i f STATE OF ALASKA RECEIVED ED • ASKA OIL AND GAS CONSERVATION COI.. SSION REPORT OF SUNDRY WELL OPERATIONS JAN 13 2015 1 Operations Abandon❑ Repair Well El Plug Perforations ❑ Perforate❑ Other tr`ACaGLielil/1 Performed Alter Casing El Pull Tubing ❑ Stimulate-Frac ❑ Waiver I=1 Time Extension❑ Change Approved Program❑ Operat Shutdown❑ Stimulate-Other I] Re-enter Suspended W❑ 2 Operator 4 Well Class Before Work 5 Permit to Drill Number BP Exploration(Alaska),Inc Name Development CI Exploratory 205-081-0 3 Address P.O Box 196612 Stratigraphic ❑ Service 6.API Number Anchorage,AK 99519-6612 50-029-23265-00-00 7 Property Designation(Lease Number) 8 Well Name and Number ADL0028256 AURA S-122 9 Logs(List logs and submit electronic and printed data per 20AAC25 071). 10 Field/Pool(s) PRUDHOE BAY,AURORA OIL 11 Present Well Condition Summary Total Depth measured 12173 feet Plugs measured None feet true vertical 6731 79 feet Junk measured None feet Effective Depth measured 12039 feet Packer measured See Attachment feet true vertical 6744 18 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 535 64 13-3/8"68#L-80 26 52-562 16 26 52-561 6 5020 2260 Surface 3630 9-5/8"40#L-80 28-3658 28-3136 33 5750 3090 Intermediate 3599 95 9-5/8"40#L-80 28 55-3628 5 28 55-3120 15 5750 3090 Production 10191 52 7"26#L-80 25 68-10217 2 25 68-6738 09 7240 5410 Liner 2108 16 4-1/2"12 6#L-80 9974 04-12082 2 6619 05-6740 59 8430 7500 Perforation depth Measured depth See Attachment feet True Vertical depth See Attachment feet SC4t4t4ED Il2 lb Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12.Stimulation or cement squeeze summary Intervals treated(measured) 10,220'-10,250', 10,300'-10,440', 10,500'-10,550', 10,600'-10,650', 10,700'-10,750', 10,890'-10,940', 10,980'-11,070', 11,120'-11,270',11,350'-11,400', 11,450'-11,550', 11,600'-11,750', 11,800'-12,030' Treatment descnptions including volumes used and final pressure 146 Bbls 9 1 DAD Acid, 130 Bbls 2%F103,74 psi 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 211 581 1898 1823 221 Subsequent to operation 160 698 3202 1920 358 14 Attachments 15 Well Class after work Copies of Logs and Surveys Run Exploratory ❑ Development 2 Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16 Well Status after work Oil 0 Gas El WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ SUSP ❑ SPLUG ❑ 17 I hereby certify that the foregoing is true and correct to the best of my knowledge Sundry Number or N/A if C 0 Exempt: N/A Contact Garry CatronEmail Garry.Catron aaBP.Com Printed Name Garry Catron Title PDC PE Signature Phone 564-4424 Date \\11`` 1/13/2015 vrL- 1/t5715— RBDMS• A JAN 1 4 2015 , *if Form 10-404 Revised 10/2012 Submit Original Only Packers and SSV's Attachment ADL0028256 SW Name Type MD TVD Depscription S-122 PACKER 9920.35 6591.8 3-1/2" Baker Premier Packer S-122 PACKER 9985.44 6624.77 5" Baker ZXP Top Packer Cl) 10 _ _ m CV N 0)CO CONCO ct 00CV C)) O O '- CO O) t Q M f- = N O O CA = O N M w y LC) f- OO 00 N- 00 N- OO CC) N- (O V ❑ N- ti 0OCOOOOOOOOCOCOO❑ F c W Z 0 0 0O Luz o H H J W ggY o0 o H V M (fl LO N N- M N- O 0 O w 0 0 W W L V N M O LO M (fl (fl . 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N D O� a O O nj 0 ._.• a) a) Nco .- c) -0873. -0 U N (n C _ Ca C N- ° 2con- CN- OZU c a) cu N cu) .CU ° o U p U) u) 00 c c cc > o N- r..... DcH > H = c * D * ‘..-Y, c) U cUoUO * oDr- v -a % Q-rn 9-mUOUoUwU1` 0 -a " o 0 o 3 5 rY o a' N a' (y D LEDEE �-, a' N a' a' D 2 D E 0 U N J . <• U) QC) Q - 00 � ° mi, Ua ° � « < < 0 < < 0 < 00H—C i.-) CL •ct` - - - - - 0 ss- 0 0 0 0 0 0 0 0 N N N N N N N N N N O CON- 6) 0) 0 0 — N M -4- CV N N N N N N N V N N N N N N N N N N r- TREE= 4-1/16"CM! =TY NOTES: DISCREPANCIES IN 4-1/2"LNR WELLHEAD= FMC .. —LY WEIGHT&PIPE DESCRIPTIONS-PLEASE „ACTUATOR= LEO S-122 REVIEW TALLY FOR MORE DETAILS. KB.ELEV= 64.2' BF.ELEV= 35.7' KOP= 300' Max Angle= 99 @ 11200' Datum MD= 12257' Datum TVD= 6600'SS 13-3/8"CSG,68.0#,L-80 BTC,ID=12.415" — 532' , 2254' H4-1/2"HES X NIP,ID=3.813" 9-5/8"CSG,40#, L-80 BTC,ID=8.679" H 3658' I—A 4-1/2"TBG, 12.6#,L-80 IBT,.0152 bpf, ID=3.958" — 4806' I--1 4806' —14-1/2"X 3-1/2"XO, ID=2.992" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 4880 3822 55 MMG-9 DOME RK 16 03/25/11 Minimum ID = 2.813" 9856 3 7077 5019 56 MMG-9 DMY RK 0 08/20/05 2 8094 5593 57 MMG-9 SO RK 20 03/25/11 3-1/2" CMD SLIDING SLV w/BX PROFILE 1 9797 6528 59 MMG-9 DMY RK 0 08/20/05 9856' 13-1/2"CMD SLIDING SLV I I w/BX PROFILE,ID=2.813" ' ' 9880' —13-1/2"HES X NIP,ID=2.813" • In 9900' — 3-1/2"HES GAUGE CARRIER, ID=2.992" w/CABLE TO SURFACE IN IA X X 9920' —17"X 3-1/2"BKR PREMIER PKR, ID=2.87" 3-1/2"TBG,9.2#,L-80 IBT, .0087 bpf,ID=2.992" H 9979' ' 9946' —13-1/2"HES X NIP.ID=2.813" PERFORATION SUMMARY , ' 9967' —13-1/2"HES X NIP,ID=2.813" REF LOG: MWD ON 08/17/05 ANGLE AT TOP PERF: 61 @ 10220' 9974' 17"X 5"BKR ZXP LNR TOP PKR& Note:Refer to Production DB for historical perf data HMC LNR HNGR,ID=4.40" SIZE SPF INTERVAL Opn/Sqz DATE 2-1/2" 6 10220- 10250 0 08/19/05 9979' —13-1/2"FLUTED WLEG,ID=3.958" 2-1/2" 6 10300- 10440 0 08/19/05 ‘ _f ELMD TT NOT LOGGED 2-1/2" 6 10500- 10550 0 08/19/05 2-1/2" 6 10600-10650 0 08/19/05 9998' --15"X 4-1/2"XO,ID=3.950" 2-1/2" 6 10700-10750 0 08/19/05 MILLOUT 7"CSG WINDOW 2-1/2" 6 10890-10940 0 08/19/05 10217'-10229' 2-1/2" 6 10980- 11070 0 08/19/05 2-1/2" 6 11120- 11270 0 08/19/05 2-1/2" 6 11350- 11400 0 08/19/05 2-1/2" 6 11450- 11550 0 08/19/05 2-1/2" 6 11600- 11750 0 08/19/05 10839' 1 RA TAG w/SHORT 2-1/2" 6 11800- 12030 0 08/19/05 JOINT, ID=3.91" 11419' —1 RA TAG w/SHORT BKR WHIPSTOCK(08/12/05) H 10217' ` JOINT,ID=3.91" 7"HES EZSV —1 10233' 7"CSG,26#, L-80 BTC,ID=6.276" H 10702' .` 4-1/2"LNR,11.6#,L-80 LTC,.0149 bpf,ID=3.958" —I 12039' ===vi�� ir PBTD H 12039' '.% 4-1/2"LNR, 12.644, L-80,.0152 bpf, ID=3.958" —I 12082' DATE REV BY COMMENTS DATE REV BY COMMENTS AURORA UNIT 08/21/05 LV ORIGINAL COMPLETION 03/29/11 JLM/PJC GLV C/O(03/25/11) WELL: S-122 09/21/05 /TLH GLV C/O 03/31/11 JCM/PJC PULL COIL FISH(3/27/11) PERMIT No:'2050810 11/05/05 BMcN/TLH DRLG DRAFT CORRECTIONS API No: 50-029-23265-00 07/12/06 DFR/PJC PULL BKR IBP SEC 35,T12N,R12E,4391'FSL&4499'FEL 11/24/10 HJW/PJC FISH-COIL CUT(11/21/10) 02/11/11 SWC/PJC SET BAITED OVERSHOT(02/08/11) BP Exploration (Alaska) • • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original fife, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~.~j - ~ ~ ~ Well History File Identifier Organizing (done) RESCAN ^ Color Items: ^ Greyscale Items: ,.~,aee iiiuiiiiiuiiuii ae,~„~~nea iuumiviiliiili ^ Poor Quality Originals: ^ Other: NOTES: BY: DIGITAL DATA ~iskettes, No. ~.~- ^ Other, NolType: Date: ' ~ I OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: lsl Project Proofing III IIII() I)III II III BY: Maria Date: ~ © /s/ Scanning Preparafion ~_ x 30 = ~ + ~ =TOTAL PAGES~~ (Count does not include cover sheet) BY: Maria Date: ~ O /s/ Production Scanning IIIII~IiIIIIl VIII Stage 7 Page Count from Scanned File: 1 1 ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES NO BY: aria Date: ~ ~ ~ `a / ~ ~ ~ /s/ / r `~ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II'I II I II II I I III ReScanned III II ~I II I I III V III BY: Maria Date: /s/ Comments about this file: Quality Checked I) I II I) II III II') III 10/6/2005 Well History File Cover Page.doc OPERABLE: Producer S - 122 (PTD #40810) Passing MITT - Tubing integriestored Page 1 of 2 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelltntegrityCoordinator ©bp.com] G `? t t Sent: Sunday, March 27, 2011 10:14 AM r To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad SW; AK, OPS Prod Controllers; AK, RES GPB Central Prod Opt Engr; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr Cc: Walker, Greg (D &C); Greaves, Damien C; AK, D &C Well Integrity Coordinator Subject: OPERABLE: Producer S -122 (PTD #2050810) Passing MITT - Tubing integrity restored All, A coil string that was previously stuck in Producer S -122 (PTD #2050810) was retrieved on 03/13/11. On 03/26/11, an MITT passed after Slickline changed out the gas lift valves. The passing test verifies tubing integrity has been restored; therefore, the well has been reclassified as Operable and may be placed on production after coil completes the previously scheduled acid treatment. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 %MAW APR 4 4 2011 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Saturday, November 20, 2010 3:49 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS GC2 OSM; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad SW; AK, OPS Prod Controllers; AK, RES GPB Central Prod Opt Engr; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr Cc: King, Whitney; AK, D &C Well Integrity Coordinator; Greaves, Damien C Subject: NOT OPERABLE: Producer S -122 (PTD #2050810) Well secured w/ a load & kill All, Slickline was unable to secure S -122 (PTD #2050810) with a downhole plug due to scale build -up in the tubing. On 11/13/10, service coil rigged up in attempt to remove the scale and left a fish in the well. Prior to rigging off, coil killed the well with 9.8 ppg brine. The well has been temporarily secured with a load and kill, therefore, it has been reclassified as Not Operable and will remain shut -in until repaired. After the fish is retrieved and scale is removed from the wellbore, slickline will dummy off the gas lift valves in attempt to regain tubing integrity. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator 3/29/2011 OPERABLE: Producer S -122 (PTD #0810) Passing MITT - Tubing integri1estored Page 2 of 2 Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Friday, November 05, 2010 2:36 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS GC2 OSM; AK, OPS GC2 Facility OTL; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad SW; AK, OPS Prod Controllers; AK, RES GPB Central Prod Opt Engr; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, D &C Well Integrity Coordinator; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; Greaves, Damien C Cc: Janowski, Carrie; AK, D &C Well Integrity Coordinator Subject: UNDER EVALUATION: Producer S -122 (PTD #2050810) TxIA Communication Above MOASP All, Producer S -122 (PTD #2050810) has confirmed sustained IA casing pressure above MOASP. The wellhead pressures were tubing /IA/OA equal to 2040/2030/vac on 11/2/2010. The well has been reclassified as Under Evaluation. The well may remain online while work is conducted to attempt to restore integrity. The plan forward: 1. DHD: TIFL Pending results of the TIFL, if required 2. Coiled Tubing: Mill scale in tubing 3. Slickline: Set tubing tail plug 4. Pumping: MIT -T and MIT -IA to prove mechanical barriers A TIO plot and wellbore schematic have been included for reference. « File: Producer S -122 ( PTD #2050810) TIO Plot.doc » Please call if you have questions or concerns. Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 3/29/2011 STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISSI REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate❑ Other 0 ACID Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ waiver[] Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑r Exploratory ❑ 205 -0810 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519- 6612 — 50- 029 - 23265 -00 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 028256 S -122 10. Field /Pool(s): PRUDHOE BAY FIELD / AURORA OIL POOL 11. Present Well Condition Summary: Total Depth measured 12173 feet Plugs (measured) None feet true vertical 6731. feet Junk (measured) None feet Effective Depth measured 12039 feet Packer (measured) 9920 feet true vertical 6744 feet (true vertical) 6592 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 109' 20" 215.5# A -53 SURFACE - 109 SURFACE - 109 Surface 532' 13 -3/8" 68# L -80 SURFACE - 532 SURFACE - 532 5020 2260 Intermediate 3629' 9 -5/8" 40# L -80 29 - 3658 29 - 3136 5750 3090 Production Liner 10192' 7" 26# L -80 25 - 10217 25 - 6738 7240 5410 Liner 2108' 4 -1/2" 11.6 #/12.6# L -80 9974 - 12082 6619 - 6741 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - True Vertical depth: Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 SURFACE - 4806 SURFACE - 3781 3- 1/2 "9.2# L -80 4806 -9979 3781 -6622 Packers and SSSV (type, measured and true vertical depth) 7"X 3 -1/2" BKR PREMIER PKR 9920 6592 r',_ 12. Stimulation or cement squeeze summary: j `n' Intervals treated (measured): ��� ���� � ���� Treatment descriptions including volumes used and final pressure: y:d tiiS tk tip Can. " vute�a;�' 31019 13. Representative Daily Average Production or Inje v, Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 613 318 3540 216 Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil Gas WDSPL GSTOR ❑ WINJ ❑ WAG[:] GINJ ❑ SUSP❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Joe Lastufka Printed Na a Lastufk Title Data Manager Signat e , Phone 564 -4091 Date 11/23/2010 RBDms NOV to 10� Form 10 -404 Revised 10/2010 Submit Original Only S -122 205 -081 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth ToF Tvd Depth Bas S -122 8/19/05 PER 10,220. 10,250. 6,739.44 6,753.23 S -122 8/19/05 PER 11,450. 11,550. 6,777.73 6,772.17 S -122 8/19/05 PER 11,350. 11,400. 6,781.7 6,780.01 S -122 8/19/05 PER 11,120. 11,270. 6,779.67 6,781.02 S -122 8/19/05 PER 10,980. 11,070. 6,780.62 6,779.91 S -122 8/19/05 PER 10,890. 10,940. 6,780.31 6,780.64 S -122 8/19/05 PER 10,700. 10,750. 6,781.55 6,780.8 S -122 8/19/05 PER 10,600. 10,650. 6,782.9 6,782.34 S -122 8/19/05 PER 10,500. 10,550. 6,779.86 6,781.82 S -122 8119/05 PER 10,300. 10,440. 6,769.23 6,777.19 S -122 8/19/05 PER 11,600. 11,750. 6,770.47 6,763.28 • S -122 8/19/05 PER 11,800. 12,030. 6,759.84 6,744.92 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL I SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • S -122 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 11/7/2010'T/1/0= 230/1980/260. Temp =104 TIFL. FAIL (pre- acid). AL online. ALP =1980 psi. IA FL @ 8441'. Stacked TP with AL to 1870 in 1 hr 15 min.. Bled IAP to production from 1980 psi to 250 psi in 45 min. OA decreased 260 psi. IA FL @ 102', i IA FL rose 7992'. Monitor 1 hr. IAP increased 270 psi. IA FL dropped 310' . Final I WHPs= 1870/520Nac. j Job complete. SV,WV =C. SSV, MV =O. IA &OA =OTG. NOVP. 11/9/2010 ASRC Test unit #1, SB on snow removal to MIRU * *job in progress ** * *inlet well S -122, outlet S -112 ** * *conduct PSM /well control drill @ day shift safety meeting ** 11/10/2010ASRC Test Unit #1 Cont.SB for Snow removal, MIRU, Assist Unit #3, Re -rig outlet' dwells. * *Inlet well S -122, Outlet well S -200 ** ** *Job in progress * ** 11/11/2010 ASRC Test Unit #1 Cont RU outlet, SB for CTU. * *Outlet well Z -200 ** ** *Job in i 3 progress * ** * ** .. � 11/12/2010� C T ASRest Unit #1 Cont SB for CTU. **Outlet well S -200 ** * ** progress Job in 11/13/2010CTU 9, 1.75" 0.116" Wall CT. Job Scope: Mill scale, acid wash.. Move from Z pad to S pad. T 11/13/20101ASRC Test Unit #1 Cont. SB for CTU. * *Outlet well S- 200 ** ** *Job in progress * ** 11/14/2010,ASRC Test Unit #1, Assist CTU w /mill scale, acid treatment, DRIL, conduct well control drill, Conduct man down safety drill, ** *Job in progress * ** E 11/14/2010 °CTU 9, 1.75" 0.116" Wall CT. Job Scope: Mill scale, acid wash. RIH w/ Baker 2.13 motor & 2.80" Parabolic mill. Tagged and started milling @ 8073'. Steady ROP of 0.2 fpm. Motor stalls if ROP is increased. Continue milling <<< Job in progress >>> i 11/15/2010ASRC Test Unit #1, Assist CTU w /mill scale and acid treatment, Inlet S -122, Outlet �S 112, ** *Job in progress * ** I 11/15/2010 CTU 9,11.75" 0.116" Wall CT. Job Scope: Mill scale, acid wash. Continue milling. Mill Ito 9000ft with consistent ROP of 0.8 fpm. POOH to change out mills. At surface, Parabolic mill is in good condition with very little wear on cutting structures. <<< Job in progress >>> !{ 1 i ., 1.75" 0.116" Wall CT. Job Scope: Mill scale, wash. RIH w / 2.80" PARA� 11/16/2010 CTU 9, p , Iturbo mill. Resume milling @ 9000' POOH to change mills. RIH with 2.80 diamond (parabolic mill with side cuting structure. Tag scale at 9080 ft. Establish free spin at 1 1 1.5 bppm (1800 psi) Continue milling. Milled 3.5" tubing out the tubing tail RIH and drift to PBTD. Tagged @ 12025' CTM. <<< Job in progress >>> _ _ 11/16/2010ASRC Test Unit #1, Assist CTU w /scale mill prep for acid treatment, Conduct well control drill and Safety drill in both crews day /night safety meetings, ** *Job in progress * ** 11/17/2010iCTU 9, 1.75" 0.116" Wall CT. Job Scope: Mill scale, acid wash. At PBTD 12015' ctm Pump a 20 bbl pill of Flo Pro and chase to surface. Injector brakes will not release unable to pull out of hole or run in hole. Phase 2 called. Wait on wind. <<< i Job in progress >>> 11/17/2010 ASRC Test Unit #1, Assist CTU w /scale mill prep for acid treatment, Inlet S -122, Outlet S -112, ** *Job in progress * ** j 11/18/2010iCTU #9 w / 1.75" ct: Job scope: «< Continue WSR from 11/17/10 »> Dig out ,equipment. Troubleshoot injector. Prepare to kill well bleed down IA. <<< Job in i progress >>> 11/18/20101ASRC Test Unit #1, Assist CTU, Inlet S -122, Outlet S -112, ** *Job in progress*** I � 11/19/2010 T 11 /0 = 490/400/0. Temp =S1. TBG & IA FL (SLB Coil call -in). AL is connected, SI @ casing valve and in manifold. ALP =O psi. Upon arrival, PE only wanted IA FL. IA FL @ 30'. SLB Coil in control of valves. 11/19/2010 CCU #9 w / 1.57" ct. Job scope acid treatment. < Continue WSR from 11/18/10 >>> Rig up hard line to IA to bleed down before killing the well. Kill the w / 60 bbls 2 ? KCL 60 bbls Flo Pro 75 bbls 2% KCL 38 bbls 60/40 Methanol. Monitor well. 1 Determine that bottom hole pressure is —3200 psi and that tubing and IA are jcommunicating. Establish injectivity down backside (CT x tbg annulus) .Prepare to kill I well PJSM discuss well kill procedures. Pumped 176 bbls of 9.8 ppg brine down IA & 5 bbls Methanol & 181 bbls 9.8 ppg brine & 3 bbls methanol down tubing and monitor well head pressure. <<< Job in progress >>> 3 11/19/2010 AS RC Test Unit #1, S/B for CTU, Inlet S -122, Outlet S -112, ** *Job in progress * ** 11 /20 /2010iASRC Test Unit #1, S/B for CTU kill well, Start R/D, Inlef S -122, Outlet S -112, ***Job in progress * ** � 11/20/2010�CTU #9 w / 1.75" ct Job scope: Acid treatment. <<< Continue WSR from 11/19/10 I >>> Pumped kill wait brine 9.8 ppg and monitor the well head pressure. <<< Job in 1 'progress >>> ... 1 /20/20101CTU #9 w / 1.75" ct Job scope: Acid treatment. «< Continue WSR from 11/19/10 >>> Pumped kill wait brine 9.8 ppg and monitor the well head pressure. WHP !decrease to 100 psi. Decision made to cut CT using upper set of shear /seal rams. `Cut coil, verify all surface valves close. Close crown, swab and master valve. Re- lopen master and close surface safety valve. Two mechanical barriers confirmed so that CTU 9 and test separators may rig down. Pop off well. RDMO. Move to SLB Ishop. <<< Job in progress >>> 11/21/2010;T/I/O = 50/10/0 +. Temp = S1. �T & IA FL (post L &K). AL SI @ casing valve. T & IA t FL near surface. s SV, WV, SSV = C. MV = O. IA, OA = OTG. NOVP. 11/21/2010 ASRC Test Unit #1, Complete rig down, move unit to price pad, ***Job complete * ** i FLUIDS PUMPED BBLS 1647 1 % XS KCL 256 60/40 METH 82 FLO PRO 118 2% KCL 357 9.8 PPG BRINE 2460 TOTAL I I TREE= 4- 1/16" CM! WELLHEAD = FMC S TES: DISCREPANCIES IN 4-1!2" LNR ACTUATOR = LEO S T REVIEW TALLY FOR MORE DETAILS. - PLEASE KB. ELEV = 64.2' BF. ELEV = 35.7' KOP = 300' Max Angle = 99 @ 11200' Datum MD = 12257' Datum TVD = 6600' SS 4 -1/2" HES X NIP, ID = 3.813" 13 -3/8" CSG, 68.0 #, L -80 BTC, ID = 12.415" 532' 2254' 9 -5/8" CSG, 40 #, L -80 BTC, ID = 8.679" 3658' tr 4 -1/2" TBG, 12.6 #, L -80 IBT, .0152 bpf, ID = 3.958" 4806' GAS LIFT MANDRELS STI MD I TVD DEV TYPE VLV LATCH PORT DATE 4 4880 3822 55 MMG -9 DOME RK 16 09/21/05 Minimum ID = 2.813" 9856' 3 7077 5019 56 MMG -9 DMY RK 0 08/20/05 2 8094 5593 57 MMG -9 SO RK 20 09/21/05 3 -1/2" CMD SLIDING SLV w /BX PROFILE 1 9797 6528 59 MMG -9 DMY RK 0 08/20/05 I I 9856' 3 -1/2" CMD SLIDING SLV w /BX PROFILE, ID = 2.813" 9880' 3 -112" HES X NIP, 9900' 3 -1/2" HES GAUGE CARRIER, ID = 2.99 w /CABLE TO SURFACE IN IA 9920' 7 "X 3 -1/2" BKR PREMIER PKR, ID = 2.87" 1 3-1/2" TBG, 9.2 #, L -80 IBT, .0087 bpf, ID = 2.992" 9979' 9946 3 -1/2" HES X NIP, ID = 2.813" PERFORATION SUMMARY 9967' 3 -1/2" HES X NIP, ID = 2.813 REF LOG: MWD ON 08/17/05 _ ANGLE AT TOP PERF: 61 @ 10220' 9974' 7" X 5" BKR ZXP LNR TOP PKR & Note: Refer to Production DB for historical perf data HMC LNR HNGR, ID = 4. SIZE SPF INTERVAL Opn /Sqz DATE 2 -1/2" 6 10220 - 10250 0 08/19/05 9979' 3 -1/2 FLUTED WLEG, ID = 3.958" 2 -1/2" 6 10300 - 10440 0 08/19/05 ELMD TT NOT LOGGED 2 -1/2" 6 10500 - 10550 0 08/19/05 2 -1/2" 6 10600 - 10650 0 08/19/05 9998' 47X 4 -1/2" XO , I = 3.950" 2 -1/2" 6 10700 - 10750 0 08/19/05 F1110217'- ILLOUT 7" CSG WINDOW 2 -1/2" 6 10890 - 10940 0 08119105 10229' 2 -1/2" 6 10980 - 11070 0 08/19105 2 -1/2" 6 11120 - 11270 0 08/19/05 2 -1/2" 6 11350 - 11400 0 08/19/05 2 -1/2" 6 11450 - 11550 0 08/19/05 2 -1/2" 6 11600 - 11750 0 08/19/05 10839' RA TAG w /SHORT 2 -1/2" 6 11800 - 12030 0 08/19/05 JOINT, ID = 3.91" 11419' RA TAG w /SHORT JOINT, ID = 3.91" BKR WH (08/12/05) 10217' 7" HES EZSV 10233' 7" CSG, 26 #, L -80 BTC, ID = 6.276" 10702' AWMMft 4 -1/2" LNR, 11.6 #, L -80 LTC, .0149 bpf, ID = 3.958" 12039' PBTD 12039' 4 -1/2" LNR, 12.6 #, L -80, .0152 bpf, ID = 3.958" 12082' DATE REV BY COMMENTS DATE REV BY COMMENTS AURORA UNIT 08/21/05 LV ORIGINAL COMPLETION WELL: S -122 09/21/05 /TLH GLV C/O PERMIT No: 2050810 11/05/05 BMcN/TLH DRLG DRAFT CORRECTIONS API No: 50- 029 - 23265 -00 07/12106 DFR/PJC PULL BKR IBP SEC 35, T12N, R1 2E, 4391' FSL & 4499' FEL F - BP Exploration (Alaska) NOT OPERABLE: Producer S -122 (P #2050810) Well secured w/ a load 81 Page 1 of 2 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] Sent: Saturday, November 20, 2010 3:49 PM 4 To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad SW; AK, OPS Prod Controllers; AK, RES GPB Central Prod Opt Engr; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr Cc: King, Whitney; AK, D &C Well Integrity Coordinator; Greaves, Damien C Subject: NOT OPERABLE: Producer S -122 (PTD #2050810) Well secured w/ a load & kill Follow Up Flag: Follow up Flag Status: Red All, Slickline was unable to secure S -122 (PTD #2050810) w ith a downhole plu due to scale build -up in the tubing. On 11/ 3/1� 0, service coil rigged up in attempt to remove the scale and left _a fish in the well. Prior to rigging off, co il killed the well with 9.8 ppq brin The well has been tempor secured with a lo and kill, therefore, it has been reclassified as No tl_p rab le and will remain shut -in until repaired. After the fish is retrieved and scale is removed from the wellbore, slickline will dummy off the gas lift valves in attempt to regain tubing integrity. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 N OV Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Friday, November 05, 2010 2:36 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS GC2 OSM; AK, OPS GC2 Facility OTL; AK, OPS GC2 Field 0 &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad SW; AK, OPS Prod Controllers; AK, RES GPB Central Prod Opt Engr; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, D &C Well Integrity Coordinator; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; Greaves, Damien C Cc: Janowski, Carrie; AK, D &C Well Integrity Coordinator Subject: UNDER EVALUATION: Producer S -122 (PTD #2050810) TxIA Communication Above MOASP All, Producer S -122 (PTD #2050810) has confirmed sustained IA casing pressure above MOASP. The wellhead pressures were tubing /IA/OA equal to 2040/2030/vac on 11/2/2010. The well has been reclassified as Under Evaluation. The well may remain online while work is conducted to attempt to restore integrity. The plan forward: 1. DHD: TIFL Pending results of the TIFL, if required 2. Coiled Tubing: Mill scale in tubing 3. Slickline: Set tubing tail plug 11/22/2010 NOT OPERABLE: Producer S -122 (P #2050810) Well secured w/ a load 8-'16 Page 2 of 2 4. Pumping: MIT -T and MIT -IA to prove mechanical barriers A TIO plot and wellbore schematic have been included for reference. << File: Producer S -122 ( PTD #2050810) TIO Plot.doc >> Please call if you have questions or concerns. Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 11/22/2010 UNDER EVALUATION: Producer S-122 (PTD #2050810) TxIA Communica�n Above MOASP Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] / Sent: Friday, November 05, 2010 2:36 PMT To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Facility OTL; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad SW; AK, OPS Prod Controllers; AK, RES GPB Central Prod Opt Engr; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, D &C Well Integrity Coordinator; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; Greaves, Damien C Cc: Janowski, Carrie; AK, D &C Well Integrity Coordinator Subject: UNDER EVALUATION: Producer S -122 (PTD #2050810) TxIA Communication Above MOASP Attachments: Producer S -122 ( PTD #2050810) TIO Plot.doc; S -122 (PTD #2050810) wellbore schematic.pdf All, Producer S -122 (PTD #2050810) has confirmed sus tained IA casing pressure above MOASP. The wellhead pressures were tubing /IA/OA equal to 2040/2030/vac on 11/2/2010. The well has been reclassified as Under Evaluation. The well may remain online while work is conducted to attempt to restore integrity. The plan forward: g, 1. DHD: TIFL # NOV 201D Pending results of the TIFL, if required 2. Coiled Tubing: Mill scale in tubing 3. Slickline: Set tubing tail plug 4. Pumping: MIT -T and MIT -IA to prove mechanical barriers A TIO plot and wellbore schematic have been included for reference. <<Producer S -122 ( PTD #2050810) TIO Plot.doc>> <<S -122 (PTD #2050810) wellbore schematic.pdf>> Please call if you have questions or concerns. Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659 -5102 Cell 907 752 -0755 Pager (907) 659 -5100 Ext. 1154 11/5/2010 PBU S -122 PTD #2050810 11/5/2010 TIO Pressures Plot _ Weil 5 -122 4,000 i — • 3.000 — Tbg —F IA 2,000 — OA OOA — OOOA On 1.000 i I 08/14110 08/28/10 09/11/10 09/25/10 10/09/10 10/23/10 TREE= 4 -1/16" CNV WELLHEAD = FMC SATES: DISCREPANCIES IN 4 -112" LNR ACTUATOR= LEO S 2 2 REVIEW TALLY FOR MORE DETAILS. - PLEASE KB. ELEV = 64.2' BF. ELEV = 35.7' KOP = 300' Max Angle = 99 @ 11200' i Datum MD = 12257' Datum TV = 6600' SS 13 -3/8" CSG, 68.0 #, L -80 BTC, ID = 12.415" 532' 2254' 4 -1/2" HES X NIP, ID = 3.813" 9 -58" CSG, 40 #, L -80 BTC, ID = 8.679" 3658' 4-1/2" TBG, 12.6 #, L -80 IBT, .0152 bpf, ID = 3.958" 4806' 4806' 4 -1/2" — )(3-1/2' XO, ID = 2.992" GAS LIFT MANDRELS STI MD I TVD DEV TYPE VLV LATCH PORT DATE L28094 3822 55 MMG -9 DOME RK 16 09/21/05 Minimum ID = 2.813" 9856 5019 56 MMG -9 DMY RK 0 08/20/05 5593 57 MMG -9 SO RK 20 09/21 /05 3 -112" CMD SLIDING SLV w1BX PROFILE 6528 59 MMG -9 DMY RK 0 08/20/05 —f--98-5v---1—f3-1/2- CMD SLIDING SLV w /BX PROFILE, ID = 2.813" 9880' — 3 -1i2" HES X NiP, I D = 2.813" 9900' 3- 1 /2 "HES GAUGE CARRIER, ID= 2.992" w /CABLE TO SURFACE IN IA 9920' 7" X 3-1/2" BKR PREMIER PKR, ID = 2.87" 3 -1/2" TBG, 9.2 #, L -80 IBT, .0087 bpf, ID = 2.992" 1 9979' 9946 3 -1/2" HES X NI P, ID = 2.813" PERFORATION SUMMARY 9967' 3 -1/2" HES X N IP, ID = 2.8 REF LOG: MWD ON 08/17/05 ANGLE AT TOP PERF: 61 @ 10220' 9974 7" X 5" BKR ZXP LNR TOP PKR & Note: Refer to Production DB for historical perf data H M C LNR HN I D = 4,4 SIZE SPF INTERVAL Opn /Sqz DATE 2 -1/2" 6 10220 - 10250 O 08/19/05 9979 3 -1/2" FLUTED WLEG, ID = 3.958" 2 -1/2" 6 10300 - 10440 O 08/19/05 ELMD TT NOT LOGGED 2 -1/2" 6 10500 - 10550 O 08/19/05 2 -1/2" 6 10600 - 10650 O 08/19/05 9998' -1/2'" XO, ID = 3.950" 2 -1/2" 6 10700- 10750 O 08/19/05 MILLOUT 7" CSG WINDOW 2 -1/2" 6 10890 - 10940 O 08/19/05 F10217'- 10229' 2 -1/2" 6 10980 -11070 O 08/19/05 2 -1/2" 6 11120 - 11270 O 08/19/05 2 -1/2" 6 11350 - 11400 O 08/19/05 2 -1/2" 6 11450 - 11550 O 08/19/05 2 -1/2" 6 11600 - 11750 O 08/19/05 10839' RA TAG w /SHORT 2 -1/2" 6 11800 - 12030 O 08/19/05 JOINT, ID = 3.91" 11419 RA TAG w /SHORT BKR WHIPSTOCK (08/12105 10217' JOINT, ID = 3.91" F HES EZSV 10233' 7" CSG, 26 #, L -80 BTC, ID = 6.276" 10702' 4 -1/2" LNR, 11.0, L -80 LTG, .0149 bpf, ID = 3.958" 12039' PBTD 12039' 4 -1/2" LNR, 12.6 #, L-80_0152 bpf, ID = 3.958" 12082' DATE REV BY COMMENTS DATE REV BY C OM M ENT S AURORA UNIT 08/21/05 LV ORIGINAL COMPLETION WELL: S -122 09/21/05 /TLH GLV C/O PERMIT No: 2050810 11/05/05 BMcN/TLH DRLG DRAFT CORRECTIONS API No: 50- 029 - 23265 -00 07/12/06 DFR/PJC PULL BKR IBP SEC 35, T12N, R12E, 4391' FSL & 4Q99' FEL EET F — ' I I I I BP Exploration (Alaska) • • June 25, 2009 1~~. ~~~ ~~t~~~~~ Mr. Tom Maunder~ ~1~L ~ ~. 2009 Alaska Oil and Gas Conservation Commission p;u~~~p~~ ~~~ ~~,~, ~o~ce ~~~nmi~si~~ 333 West 7t~' Avenue ~n~~~r~~f~ Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of S-Pad ~~~ ~~~ ~ s~- ~aa. Dear Mr. Maunder, Enclosed please find a spreadsheet with a(ist of wefis from S-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, 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, ~~~~~~~ ~~~. ~~ ~> 2~G~ Torin Roschinger BPXA, Well Integrity Coordinator • BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report ot Sundry Operatio~s (10-404) S-pad ~ n~a C~/25/2009 Well Name PTD k Initial top of cement Vol. of cement um ed Final top of cement Cement top oif date Cortosion inhibitor Corrosion inhibitod sealant date ft bbls f~ na al S-01B 1952020 025 NA 025 NA 2.6 5/30/2009 S-02A 1941090 025 NA 0.25 NA 17 5/25/2009 5-03 1811900 1325 NA 1325 NA 92.65 5/20Y2009 S-04 1830790 0 NA 0 NA 0.9 5/25/2009 S-OSA 1951890 0 NA 0 NA 0.9 5/26/2009 5-06 1827650 0 NA 0 NA 0.9 5/26I2009 S-07A 1920980 0 NA 0 NA 0.9 5/26/2009 S•08B 2070520 0 NA 0 NA 0.85 5/27I2009 5-09 1921040 1.5 NA 1.5 NA 9.4 5/31I2009 S-10A 1911230 0.5 NA 0.5 NA 3.4 5/31/2009 S-11B 1990530 025 NA 025 NA 1.7 5/27/2009 S-12A 1851930 025 NA 025 NA 1.7 6/1/2009 5-13 1821350 8 NA 8 NA 55.3 6/12009 S-t5 1840170 025 NA 025 NA 3 6/2/2009 S-77C 2020070 0.25 NA 0.25 NA 2.6 6/1/2009 S-18A 2021630 0.5 NA 0.5 NA 3 6/2I2009 5-19 1861160 0.~5 NA 0.75 NA 2.2 5/19/2009 S-20A 2010450 025 NA 0.25 NA 13 5/19/2009 S-21 1900470 0.5 NA 0.5 NA 3.4 5l25/2009 5-228 1970510 0.75 NA 0.75 NA 3 5/19/2009 5-23 1907270 025 NA Q25 NA 7.7 5/25l2009 5-248 2031630 0.5 NA 0.5 NA 2.6 5/25/2009 S-25A 1982140 0.5 NA 0.5 NA 2.6 5/25/2009 5-26 1900580 0.75 NA 0.75 NA 3.4 5/26/2009 S-27B 2031680 0.5 NA 0.5 NA 2.6 5/31/2009 S-288 2030020 0.5 NA 0.5 NA 2.6 5/37/2009 S-29AL7 1960120 0 NA 0 NA 0.85 5/27/2009 5-30 1900660 0.5 NA 0.5 NA 5.7 5/31/2009 S-31A 1982200 0.5 NA 0.5 NA 3.4 5/26/2009 S32 1901490 0.5 NA 0.5 NA 3.4 5/31/2009 S-33 1921020 Ob ~ NA 0.5 NA 4.3 5/26/2009 S-aa 1921360 0.5 NA 0.5 NA 3.a 5/31/2009 S35 1921480 0 NA 0 NA .85in 5/31/2009 S36 1921160 0.75 NA 0.75 NA 4.25 5/27/2009 5-37 1920990 125 NA 125 NA 11.9 5/27/2009 S38 1921270 0.25 NA 025 NA 102 5/27/2009 5-41 1960240 1.5 NA 1.5 NA 11.1 5/30/2009 5-42 1960540 0 NA 0 NA 0.9 5/30/2009 S-43 1970530 0.5 NA 0.5 NA t 7 5/28/2009 S-44 1970070 ~ 0.25 NA 0.25 NA 1J 5/2&2009 S•i00 2000780 2 NA 2 NA 21.3 5/29/2009 5-101 2001750 125 NA 1.25 NA 11.9 5/29/2009 5-102L7 2031560 125 NA 125 NA 17.1 5/31/2009 5-103 2001680 1.5 NA 1.5 NA 17.9 5/18/2009 S-104 2001960 1.75 NA 1.75 NA 15.3 5/20/2009 5-105 2001520 4 NA 4 NA 32.7 5/20/2009 5406 2010120 1625 ~ NA 1625 NA 774.3 6/2/2009 S-107 2011130 225 NA 225 NA 28.9 5/18/2009 S-ioe 2071000 3.5 NA 3.5 NA a0 5/30/2009 S-109 2022450 2 NA 2 NA 21.3 5/30/2009 5-110 2011290 11.75 NA 11.75 NA 98.6 5/30/2009 S-tt7 2050510 2 NA 2 NA 79.6 5J30/2009 S-1t2 2021350 0 NA 0 NA 0.5 5/30/2009 S-113 2021430 1.75 NA 1.75 NA 22.1 5/18/2009 S-tiaA 2021980 1.25 NA 125 NA 102 5/30M1009 5-~75 2022300 2.5 NA 2.5 NA 272 5/29/2009 S-716 2031810 1.5 NA 1.5 NA 13.6 5/28/2009 S-117 2030120 1.5 NA 1.5 NA 15.3 5/29/2009 S-118 2032000 5 NA 5 NA 76.5 5/2&2009 5-119 2041620 1 NA 1 NA 52 5/30/2009 5-120 2031980 5.5 NA 5.5 NA 672 5/29/2009 S-12i 2060470 4.5 NA 4.5 NA 53.6 5/28/2009 -i22 2050810 3 NA 3 NA 27.3 5/29/2009 S-~23 2041370 1.5 NA 1.5 NA 20.4 5/26/2009 5-124 2061360 1.75 NA 1.75 NA 71.9 5/26/2009 5-125 2070830 2.25 NA 225 NA 20.4 5/28/2009 5-126 20710970 125 NA 125 NA 15.3 6/1/2009 S-200 1972390 125 NA 125 NA 14.5 5/28/2009 5-207 2001840 0 NA 0 NA 0.85 6/19/2009 S-213A 2042130 2 NA 2 NA 73.6 5/29/2009 5-215 2021540 2 NA 2 NA 18.7 6/1l2009 5-276 2001970 4J5 NA ~ 4J5 NA 5t 5/29/2009 5-277 2070950 025 NA 025 NA t.~ 6/1/2009 5-400 2070740 2 NA 2 NA 9.4 5/28/2009 S-407 2060780 16 NA 16 NA 99.5 6/2/2009 S-504 0 NA 0 NA 0.85 5/28/2009 • DC) N4T PLACE. ANY NEW. MATERIAL: UNDER THIS PAGE F: ~[.aserFiehe\CvrPgs_Inseri slMicrofil m_Marker. doc ~ a. ~~- DATA SUBMITTAL COMPLIANCE REPORT 10/25/2007 Permit to Drill 2050810 Well Name/No. PRUDHOE BAY UN AURO S-122 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23265-00-00 MD 12173 TVD 6732 Completion Date 8/22/2005 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION M d L N l N S D i N og o u amp es o irect onal Surrey Yes DATA INFORMATI ON Types Electric or Other Log s Run: MWD / GR, MWD / GR /RES /DEN / NEU / PWD, MWD / GR /RES / (data taken from Logs Portio n of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ~ D Asc Directional Survey 0 12173 Open 9/8/2005 R .t D Directional Survey 0 12173 Open 9/8/2005 D Asc Directional Survey 0 10731 Open 9/8/2005 P61 I~(it Directional Survey 0 10731 Open 9/8/2005 PB1 D Asc Directional Survey 0 10853 Open 9/8/2005 P62 ~R'pt Directional Survey 0 10853 Open 9/8/2005 P62 ICED D Asc Directional Survey 0 11460 Open 9/8/2005 PB3 ''~pt Directional Survey 0 11460 Open 9/8/2005 PB3 C Pds 14066 See Notes 10479 10480 Case 8/29/2006 Coil Flag -For Pref 2-May- 2006 :.~ C Lis 15071 Induction/Resistivity 250 12172 Open 4/30/2007 LIS Veri, FET, ROP, GR, ~, DRHO, NPHI w/Graphics PDS &TXT ~/~ !Log 15071 Induction/Resistivity 25 Blu 250 12173 Open 4/30/2007 MD Vision Service 17-Aug- /' ' 2005 Log 15071 Induction/Resistivity 25 Blu 250 12173 Open 4/30/2007 TVD Vision Service 17- Aug-2005 ED~ C Lis 15072 Induction/Resistivity 250 10731 Open 4/30/2007 PB1 LIS Veri, FET, ROP, GR, DRHO, NPHI w/Graphics PDS &TXT "~l og 15072 Induction/Resistivity 25 Blu 250 10731 Open 4/30/2007 PB1 MD Vision Service 9- Aug-2005 ~~ f -Cog 15072 Induction/Resistivity 25 Blu 250 10731 Open 4/30/2007 PB1 TVD Vision Service 9- Aug-2005 -~~ C Lis 15073 Induction/Resistivity 250 10853 Open 4/30/2007 P62 LIS Veri, FET, ROP, GR, DRHO, NPHI w/Graphics PDS &TXT DATA SUBMITTAL COMPLIANCE REPORT 10/25/2007 Permit to Drill 2050810 Well Name/No. PRUDHOE BAY UN AURO S-122 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23265-00-00 MD 12173 TVD 6732 Completion Date 8/22/2005 Completion Status 1-OIL ?'Log 15073 Induction/Resistivity 25 Blu i Log 15073 Induction/Resistivity 25 Blu C Lis 15074 Induction/Resistivity i ~og 15074 Induction/Resistivity i ;.tog 15074 Induction/Resistivity (Well Cores/Samples Information: Name 25 Blu 25 Blu Current Status 1-OIL UIC N 10000 10853 Open 4/30/2007 PB2 MD Vision Service 14- Aug-2005 10000 10853 Open 4/30/2007 PB2 TD Vision Service 14- Aug-2005 250 11459 Open 4130!2007 PB3 LIS Veri, FET, ROP, GR, DRHO, NPHI w/Graphics PDS & TXT 10000 11460 Open 4/30/2007 PB3 MD Vision Service 15- Aug-2007 10000 11460 Open 4/30/2007 PB3 TVD Vision Service 15-Aug-2007 Sample Interval Set Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y Chips Received? •~'-~ Analysis ~F~{-N""~ Received? Comments: Daily History Received? (~N Formation Tops V/ N Compliance Reviewed By: ____ ___-__ _ Date: ~~ 04/25iG7 Schtum~erger Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well ~,}~ Job # Log Description NO. 4223 Company: Alaska Oil 8 Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Aurora Orion Date BL Color CD L-213 11649950 MEMORY (PROF 03I17IOi 1 -- W-210 S-104 11626075 10563057 USIT INJECTION PROFILE 03106/07 05103103 1 1 L-218 L-218 10913045 10913045 CEMENT/PERF EVALUATION MDT 09104105 09/04/05 1 1 5-111P61 S-111P62 40011960 40011960 OH EDIT MWDILWD _ OH EDIT MWDILWD 05124/05 06106/05 2 2 1 1 L-202 L-202L1 40012011 40012011 OH EDIT MWDILWD OH EDIT MWD/LWD 06/17/05 06124/05 2 2 1 1 L-202L2 A0012011 OH EDIT MWD/LWD 06129105 2 1 L-202L3 S-122 S-122P81 5-122P82 5-722P63 40012011 40012137 40012137 40012137 40012137 OH EDIT MWDILWD OH EDIT MWD/LWD OH EDIT MWD/LWD OH EDIT MWDILWD OH EDIT MWDILWD 07105105 08/17/05 08109/05 08114105 08115165 2 2 2 2 2 1 1 1 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc ~'_ "'' - {~ - ~V ~ ~~~ Petrotechnical Da[a Center LR2-1 °-- Schlumberger-DCS 2525 Gambell St, Suite 400 900 E Benson Blvd. Anchorage,.AK 99503-2838 Anchorage AK 99508-4254 ATTN: Beth /gff !'1T`~~ «~ ~yji `` ~ ~U~9~ Date Delivered: Received by. 1°H1c~a 11C~ i a"~ ~~ `~ f.. ',. ~. 68~Y~~~49o'i8 ~...~. 1/r/ELL LL7G ~CEiV~~ 1 "R~4N~SM/TT~4L ~~ ~c {' `~ coos ------i~• ~ilaska C)il & Gas ~;cm~:. (~cnnr~~i~siur~ PROACTIVE DIAf~NOS11C SERVICES, INC. Ancharaye 70: State of Alaska - AOGCC. Attn: Helen J. Warman 333 W. 7th Ave. Suite 100 Anchorage, Alaska 99501 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to ProActive Diagnositc Services, Inc, Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax : (907) 245 - 8952 1 } S-122 02-May-06 Coil Flag 2) 3) 4) 5) 6) 7J Signed : ~_ Date : "~"~~~n ~o Print Name: ~n ~ ~,5 ~) ~ c~ l I l.c~..~n In ~.P,, PROACTIVE DIAfINOSTIC SERVICES, INC.., 13O W. INIERNATIONAI All(Ix)RT IZ(I SUITE C, ANC.I(Ol(A(jE, /~K 995Itf PhoNE: (907)245.23951 Fnx: (907)245-tj952 Gmnil : ~xlsnNCJl~mnyl ~~m~m~~uyluc~.i_um WE~SIIE MEMORYIOfj.COM ~~~! ~~~(' I ~ ~ 1 / D~ ` C:\My Documents\Work\ DistributionlablesNew\ Tra~ismit_O(iginal.Joc .~ ~ ~~CEIVEt~ STATE OF ALASKA SEP 2 6 zpp~ ALASKA OIL AND GAS CONSERVATION COMMI 'ION WELL COMPLETION OR RECOMPLETION REPORT AND LOA'~ska Oil & Gas Cons. Comrnissia-~ Revised: 09/26/t~$>~(~Production 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG 20AAC 25.105 20AAC 25.110 ^ GINJ ^ WINJ ^ WDSPL No. of Com letions One p Other 1b. Well Class: ®Development ^ Exploratory ^ Stratigraphic ^ Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 8/22/2005 12. Permit to Drill Number 205-081 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 7!30!2005 13. API Number 50-029-23265-00-00 4a. Location of Well (Governmental Section): Surface: 43 1' FSL 9' FE 7. Date T.D. Reached 8/17/2005 14. Well Name and Number: PBU S-122 9 , 449 L, SEC. 35, T12N, R12E, UM Top of Productive Horizon: 172' FSL, 1337' FEL, SEC. 22, T12N, R12E, UM g. KB Elevation (ft): 64.25' 15. Field /Pool(s): Prudhoe Bay Field /Aurora Pool Total Depth: 1215' FSL, 2919' FEL, SEC. 22, T12N, R12E, UM 9. Plug Back Depth (MD+TVD) 12039 + 6744 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 618930 y- 5980595 Zone- ASP4 10. Total Depth (MD+TVD) 12173 + 6732 Ft 16. Property Designation: ADL 028256 _ TPI: x-_ 616704 __ y- 5986901 Zone- ASP4 Total Depth: x- 615104 Y- 5987920 Zone- ASP4 11. Depth where SSSV set (Nipple) 2254' 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: MWD / GR, MWD / GR /RES /DEN /NEU / PWD, MWD / GR /RES /DEN /NEU / ABI 22. CASING, LINER AND EMENTING RECORD CASING ETTING ' EPTH MD ETTING' EP7H TVD f jOLE AMOUNT SIZE WT. PER FT. GRADE OP OTTOM OP OTTOM SIZE CEMENTING RECORD PULLED 20" 215.5# A-53 Surface 109' Surface 109' 42" 260 sx Arctic Set A rox. 13-3/8" 68# L-80 Surface 532' Surface 532' 12-114• x,s• 894 sx Arcticset 9-5/8" 40# L-80 29' 3658' 29' 3136' 12-1/4" 7 sx Arcticset Lite, 470 sx'G' 7" 26# L-80 25' 10217' 25' 6738' 8-3/4" 342 sx LiteCrete, 293 sx Class 'G' 4-1/2" 11.6# / 12.6# L-80 9974' 12082' 6619' 6741' 6-1/8" 209 sx Class 'G' 23. Perforations open to Produc tion (MD + TV D of Top and " " 24. TueING RECORD Bottom Interval, Size and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 2-1/2" Gun Diameter, 6 spf 2-1/2" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 4806' MD TVD MD TVD 3-1/2", 9.2#, L-80 4806' - 9979' 9920' 10220' -10250' 6739' - 6753' 10980' -11070' 6781' - 6780' 10300' - 10440' 6769' - 6777' 11120' - 11270' 6780' - 6781' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 10500' - 10550' 6780' - 6782' 11350' - 11400' 6782' - 6780' 10600' - 10650' 6783' - 6782' 11450' 11550' 6778' 6772' DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED - - 10700' -10750' 6782' - 6781' 11600' -11750' 6770' - 6763' 10233' Set EZSV (for Kickoff from PB1) 10890' - 10940' 6780' - 6781' 11800' - 12030' 6760' - 6745' 10217' Set W hipstock 4840' Freeze Protect with 165 Bbls Diesel 26• PRODUCTION TEST Date First Production: September 24, 2005 Method of Operation (Flowing, Gas Lift, etc.): Gas Lift Date of Test 9/24/2005 Hours Tested 4 PRODUCTION FOR TEST PERIOD OIL-BBL 258 GAS-McF 239 WATER-BBL 255 CHOKE SIZE 77° GAS-OIL RATIO 926 Flow Tubing Press. 24 Casing Pressure 1,280 CALCULATED 24-HOUR RATE OIL-BBL 1,549 GAS-MCF 1,435 WATER-BBL 1,530 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). Subm_ it core chips; 'rf none, state "none". ~~ ~., ~ ~ ®INS BFh. s~~ ~ ~ 200 None ~2?~~ _I ' "i [i~ r ~~*~~ n°..' i ,. x Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE _ ..... • ~ 28. GEOLOGIC MARKERS 29' RMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Ugnu 4429' 3562' None Ugnu M Sands 6580' 4741' Schrader Bluff N Sandstones 6971' 4960' Schrader Bluff O Sandstones 7173' 5073' Base Schrader /Top Colville 7727' 5390' HRZ 9979' 6622' Kalubik 10197' 6728' Kuparuk C 10207' 6733' 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 ~ -o~~'~ PBU S-122 205-081 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Shane Gagliardi, 564-5251 Permit No. / A royal No. INSTRUCTIONS GeNeRA~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00}. IreM 20: True vertical thickness. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-fn, or Other (explain). IreM 27: If no cores taken, indicate "None". IreM 29: List all test information. If none, state "None". Form 10-407 Revised 12!2003 Submit Original Only ' ~ STATE OF ALASKA ALASKA UIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG 1b. Well Class: 20AAC 25.105 20AAC 25.110 ®Development ^ Exploratory ^ GINJ ^ WINJ ^ WDSPL No. of Com letions One p Other ^ Stratigraphic ^ Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 8/22/2005 ~05~1, ;~, 3. Address: 6. Date Spudded j~ ~ zap 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 7/~d/2005 ~_~' 50-029-23265-00-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: ' ' 8/17/2005 PBU S-122 4391 FSL, 4499 FEL, SEC. 35, T12N, R12E, UM Top of Productive Horizon: g, KB Elevation (ft): 15. Field /Pool(s): 172' FSL, 1337' FEL, SEC. 22, T12N, R12E, UM 64.25' Prudhoe Bay Field /Aurora Pool Total Depth: 9. Plug Back Depth (MD+TVD) 1215' FSL, 2919' FEL, SEC. 22, T12N, R12E, UM 12039 + 6744 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 618930 ~ y- 5980595 'Zone- ASP4 ~ 12173 + 6732 ' Ft ADL 028256 TPI: x- 616704 y- 5986901 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 615104 ^ Y- 5987920 ^ Zone- ASP4 (Nipple) 2254' MD 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey ®Yes ^ No N/A MSL 1900' (Approx.) 21. Logs Run: MWD / GR, MWD / GR /RES /DEN /NEU / PWD, MWD / GR /RES /DEN /NEU / ABI 22. ASING, LINER AND EMENTING ECORD CASING ETTING DEPTH MD ETTING EPTH TVD HOLE `' MOUNT SIZE WT. PER FT. GRADE OP TTOM OP OTTOM SIZE CEMENTING RECORD PULLED 20" 215.5# A-53 Surface 109' Surface 109' 42" 260 sx Arctic Set A rox. 13-3/8" 68# L-80 Surface 532' Surface 532' 12-1ia• X 1s^ 894 sx Arcticset I 9-5/8" 40# L-80 29' 3658' 29' 3136' 12-1/4" 7 sx Arcticset Lite, 470 sx'G' 7" 26# L-80 25' 10217' 25' 6738' 8-3/4" 342 sx LiteCrete, 293 sx Class 'G' 4-1/2" 11.6#/12.6# L-80 9974' 12082' 6619' 6741' 6-1/8" 209sxClass'G' 23. Perforations open to Produc tion (MD + TV D of Top and " " 24. TueING RI=_coRo Bottom Interval, Size and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 2-1/2" Gun Diameter, 6 spf 2-1/2" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 4806' MD TVD MD TVD 3-1/2", 9.2#, L-80 4806' - 9979' 9920' • 10220' - 10250' 6739' - 6753' 10980' - 11070' 6781' - 6780' ' ' ' ' ETC. . CEMENT SQUEEZE 25 ACID FRACTURE • 10300 - 10440 - 6777 6769 ~ 11120' - 11270' 6780' - 6781' , , , ' 10500' - 10550' 6780' - 6782' 11350' - 11400' 6782' - 6780' 10600' 10650' 6783' 6782' 11450' 11550' 6778' 6772' DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED . - - • - - 10700' - 10750' 6782' - 6781' 11600' - 11750' 6770' - 6763' 10233' Set EZSV (for Kickoff from P61) 10890' - 10940' 6780' - 6781' - 11800' - 12030' 6760' - 6745' 10217' et Whipstock 4840' Freeze Protect with 165 Bbls Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas lift, etc.): Not on Production Yet N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED E Ott-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORK) Press. 24-HOUR RAT 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". CL,':~,rt~~" i tN ~~~~cc None ~Dmaa ~ SAP ~ ~ Z~~rJ ~2 -v ~'_~ ~~~,~ t ~ ~ ., ~ . v ..--os Form 10-407 ReVISed 12/2003 CONTINUED ON REVERSE SIDE ti r~ ~ ~ ~^~ I ~ ~"' ~~~ ~""" ~$• GEOLOGIC MARKERS 29' FORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Ugnu 4429' 3562' None Ugnu M Sands 6580' 4741' Schrader Bluff N Sandstones 6971' 4960' Schrader Bluff O Sandstones 7173' 5073' Base Schrader /Top Colville 7727' 5390' HRZ 9979' 6622' Kalubik 10197' 6728' Kuparuk C 10207' 6733' 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. Si ned Terrie Hubble Title Technical Assistant Date °~ g ~ ~~ ~bS PBU S-122 205-081 Prepared By Name/Number.• Terrie Hubble, 564-4628 Well Number Permit No. (A royal No. Oniling Engineer: Shane Gagliardi, 564-5251 INSTRUCTIONS GeNew-L: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). Irene 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: True vertical thickness. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: If no cores taken, indicate "None". IreM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only Printed: 8/26/2005 11:37:52 AM BP EXPLORATfON Operations Summary Report Performed deflection survey on Spine road over culverts near W-pad access road with double mats and over 7 culverts -100 yards east of S-pad access road turn off. - Hydraulic pressure on moving system jacks: Driller's side front 1111 psi, Driller's side rear 1610 psi, off Driller's side front 761 psi, off Driller's side rear 1400 psi 7/29/2005 00:00 - 03:30 3.50 MOB P PRE -Move substructure from S-pad access road to location. 03:30 - 05:30 2.00 MOB P PRE -Spot & center rig over S-122. 05:30 - 07:30 2.00 MOB P PRE -Spot pit complex. - Hydraulic pressure on pit module moving system jacks: back left 1675 psi, back right 1575 psi, front left 1500 psi, front right 1500 psi. 07:30 - 08:00 0.50 MOB P PRE - PJSM on raising derrick. 08:00 - 11:00 3.00 RIGU P PRE -Raise & pin derrick, R/U cattle shoot, R/D bridle lines, & R/U kelly hose & standpipe. - Rig accepted @ 10:30 hrs. 11:00 - 18:00 7.00 RIGU P PRE -Orient knife valve on spool below annular preventer & M/U diverter line. - Calibrate gas monitors. - Held pre-spud meeting with crew & service personnel. 18:00 - 19:00 1.00 BOPSU P PRE -Function test knife valve on diverter system. Test witnessed by AOGCC Rep John Crisp, Tool Pusher Larry W urdeman, & WSL Mike Dinger. -Test low level & high level alarms on rig H2S detection system. 19:00 - 21:30 2.50 RIGU P PRE -Continue rigging up -set MWD & mud shacks, geology trailer, & cuttings tank. - Load pipeshed w/ 4" DP. 21:30 - 00:00 2.50 RIGU P PRE - P/U 4" DP 1 x 1 from pipeshed & rack back. - Held pre-spud meeting with crew & service personnel. 7/30/2005 00:00 - 03:00 3.00 RIGU P PRE - P/U 4" DP & 21 jts of 4" HWDP & rack back. 03:00 - 03:30 0.50 RIGU P PRE - R/U to P/U BHA. 03:30 - 05:00 1:50 RIGU P PRE - P/U BHA # 1 consisting of 12 1/4" MXC-1, 9 5/8" XP motor w/ 1.83 deg bend, UBHO sub, XO, XO, & 1 stand of 4" HWDP. 05:00 - 06:00 1.00 DRILL P SURF -Fill pipe & check for leaks. Close IBOP & test surface equip't to 3000 psi. - Clean out conductor & drill 12 1/4" hole to 140'. 06:00 - 08:00 2.00 DRILL P SURF - R/U gyro & survey check w/ both gyro tools. Confirm both tools calibrated. 08:00 - 10:00 2.00 DRILL P SURF -Drill 12 1/4" hole from 140' to 263'. - Lost 10 bbls fluid. 10:00 - 12:00 2.00 DRILL P SURF -Monitor well for losses. Discovered communication with well S-216 cellar while pumping. Shut down pumps & POH inside Page 1 of 12 Legal Well Name: S-122 Common Well Name: S-122 Spud Date: 7/30/2005 Event Name: DRILL+COMPL ETE Start: 7/29/2005 End: 8/21/2005 Contractor Name: NABOBS ALAS KA DRILLING I Rig Release: 8/21/2005 Rig Name: NABOBS 7ES Rig Number: Date ~~I From - To ! Hours ~ Task Code ~ NPT Phase j Description of Operations 7/28/2005 00:00 - 00:30 0.50 MOB P PRE -Disconnect pit module from substructure. 00:30 - 03:00 2.50 MOB P PRE - R/D rig floor to UD derrick - Move shop & Satellite camp to S-pad. 03:00 - 04:00 1.00 MOB P PRE -Move substructure off of Z-04 & move to west side of Z-pad. 04:00 - 06:00 2.00 MOB P PRE -Pull derrick pins & lower derrick. 06:00 - 12:00 6.00 MOB P PRE -Transport pit module to S-pad while troubleshooting hydraulic moving system on substructure. 12:00 - 00:00 12.00 MOB P PRE -Move substructure from Z-pad to S-pad access road. Printed: 8/26/2005 11:37:59 AM BP EXPLORATION Page 2 of 12 Operations Summary Report Legal Well Name: S-122 Common Well Name: S-122 Spud Date: 7/30/2005 Event Name: DRILL+COMPLETE Start: 7/29/2005 End: 8/21/2005 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 8/21/2005 Rig Name: NABORS 7ES Rig Number: I Date I From - To Nours i Task !~ Code'. NPT Phase 7/30/2005 110:00 - 12:00 2.OO~DRILL P ~ SURF 12:00 - 20:00 8.00 DRILL N DPRB SURF 20:00 - 22:30 I 2.501 DRILL I N I DPRB '.SURF 22:30 - 00:00 ~ 1.501 DRILL ~ N ~ DPRB i SURF 7/31/2005 00:00 - 03:30 3.50 DRILL X DPRB SURF 03:30 - 04:00 0.50 DRILL P SURF .04:00 - 05:00 1.00 DRILL P SURF 05:00 - 06:30 I 1.501 DRILL I P I I SURF 06:30 - 11:00 ~ 4.50 i DRILL P ~ ~ SURF 11:00 - 12:00 I 1.001 DRILL I N I DPRB I SURF 12:00 - 14:00 I 2.001 DRILL I N I DPRB I SURF 14:00 - 15:00 1.00 DRILL N DPRB SURF 15:00 - 18:00 3.00 DRILL N DPRB SURF 18:00 - 18:30 0.50 DRILL N DPRB SURF 18:30 - 20:00 1.50 DRILL N DPRB SURF 20:00 - 22:00 2.00 CASE N DPRB SURF 22:00 - 00:00 2.00 CASE N DPRB SURF 8/1/2005 00:00 - 00:30 0.50 CASE N DPRB SURF 00:30 - 01:30 1.00 CASE N DPRB SURF 01:30 - 03:30 I 2.001 CEMT I N I DPRB I SURF Description of Operations conductor. - Notify AOGCC & discuss options with Anchorage, Production, & Wells Group. Gather equip't to perform cement top job on S-216. Experienced some logistical delays due to ongoing rig move in field. - Receive 1" & 3/4" pipe. Cut muleshoe & additional holes on bottom 5' of first jt of top job pipe. - Run 80' of 1" pipe in 20" x 9 5/8" annulus on S-216. - R/U cementers & hold PJSM. - Pump 5 bbis water followed by 29 bbls. 15.4 ppg Arctic Set f cement. First 10 bbis cement treated w/ LCM Good returns throughout job with cement returns to surface after i8 bbls of cement pumped. CIP C~3 22:30 hrs -thickening time 2hrs. 39 mins. - No communication with S-122 while performing top job on S-216. - R/D cementers. - Wait on cement. -Wait on cement inside S-216 20" x 9 5/8" annulus. - RIH & tag bottom - no fill. - Drill to 316' in 12 1/4" hole. Lost i20 bbls mud in 30 minutes. Check for broaching on all S pad wells. No broaching. - POH & P/U MWD, NM lead collar, 3 NM stabs, & 2 NM drill collars. - Drill 12 1/4" hole to 535'. WOB 10K, 470 GPM, 800 psi, 40 RPM, Tq on & off bottom 3K, P/U wt 70K, S/O wt 55K, Rot wt 55K. ART .52 hrs, AST, 1.43 hrs, ADT 1.95 hrs. - POH due to communication with S-117 & S-120 conductor x surface casing annuli. - Notify AOGCC & discuss options w/ Anchorage, Production, & Wells Group personnel. - POH & UD MWD & mud motor. - P/U 16" BHA &RIH to 400'. - M/U top drive & open hole to 16" from 400' to 535'. 80 RPM, 400 GPM, 500 psi. - Circulate @ 200 GPM, 300 psi while preparing 13 3/8" casing. - POH to run 13 3/8" casing. - VD BHA. - R/U to run 13 3/8" casing. - Run 13 jts 68# L-80 BTC 13 3/8" casing to 532'. - M/U XO & cementing head. - Circulate & condition mud for cement job @ 300 GPM, 375 psi. Lost 26 bbls while circulating. - Pump 2 bbis water & test lines to 2,500 psi. Pump 8 bbls water w/ dye. Drop bottom plug & pump 148 bbls 15.7 ppg Arctic Set I cement. Drop top plug & wash up with 20 bbls water followed by 47.5 bbls mud with rig pumps. Bump plug W/ 500 psi over to 1000 psi. Bleed off pressure & check floats -floats holding. - During cement job lost full returns after 49 bbis of cement pumped. Regained returns after 70 bbls cement pumped & maintained returns throughout job. Red dye back after 102 bbis of cement pumped. No cement returns back to surface. CIP @ Printed: 8/26/2005 11:37:59 AM BP EXPLORATION Operations Summary Report Page 3 of 12 Legal Well Name: S-122 Common Well Name: S-122 Spud Date: 7/30/2005 Event Name: DRILL+COMPLETE Start: 7/29/2005 End: 8/21/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/21/2005 Rig Name: NABOBS 7ES Rig Number: Date ~ From - To ' Hours ~ Task ~ Code ~ NPT j Phase ~ Description of Operations 8/1/2005 _ 01:30 - 03:30.. 2.00 - -- - - - - - - - -- - CEMT ~ N DPRB SURF 103:30. 03:30 - 08:30 5.00 CEMT N DPRB ~ SURF 08:30 - 13:30 I 5.001 CEMT I N I DPRB I SURF 13:30 - 16:00 I 2.501 CEMT I N I DPRB I SURF 16:00 - 18:00 2.00 CEMT N DPRB SURF 18:00 - 19:30 1.50 CEMT N DPRB SURF 19:30 - 20:00 0.50 DRILL P SURF 20:00 - 23:30 3.50 DRILL P ~ SURF 23:30 - 00:00 0.50 DRILL P SURF 8/2!2005 00:00 - 12:00 12.00 DRILL P SURF 12:00 - 00:00 I 12.001 DRILL I P ( I SURF 8/3/2005 ~ 00:00 - 12:00 ~ 12.00 ~ DRILL ~ P ~ (SURF 12:00 - 13:30 1.50 DRILL P SURF 13:30 - 17:00 3.50 DRILL P SURF 17:00 - 19:00 2.00 DRILL P SURF - Flush out riser through 4" outlets -good indication of cement while flushing out stack. - Wait on cement. Unflange 16" diverter line from knife valve, remove turn buckles from diverter. - Pick up diverter from 20" conductor. Rough cut 13 3/8" casing, remove from welt and lay down. NOTE: The 13 3/8" casing is not suspended on surface but held in place by the cement. - Move diverer from over well with bridge crane. Welder make final cut and internal bevel on 13 3/8" casing 10" below top of 20" landing ring. - Top of cement in 20" x 13 3/8" annulus is 8' below the landing ring. Topped off the annulus space with 1.5 bbl cement to 4" outlets. - N/U diverter spool, annular preventer, riser, & 16" diverter line. - P/U 12 1/4" drilling ass'y &RIH. 12 1/4" MXC-1, 1.83 deg XP motor, NMLC, NM stab, MWD, UBHO sub, NM stab, NMLC, NMXO, NM spiral DC, NM stab, NM spiral DC, svaer sub, jars, & XO. - Tag float collar on depth. - Drill cement in shoe track to 532'. - Take survey w/ gyro. - Displace cement contaminate mud with 8.9 ppg spud mud & drill directional in 12 1/4" hole to 806'. - WOB 10-15K, 530 GPM, 1300 psi, Tq on & off bottom 3K, P/U wt 68K, S/O wt 65K, Rot wt 68K. - AST 1.4 hrs, ART .68 hrs, ADT 2.08 hrs -Take surveys w/ gyro. Drill directional in 12 1/4" hole from 806' to 1660' taking surveys w/ gyro as per program. PU wt. 85K, SO wt. 70K, rot wt. 80K, tq. on 4K, 475 gpm, 1300 psi. AST 4.97, ART 3.12, ADT 8.09. Drill directional in 12 1/4" hole from 1660' to 2807', 2646' TVD. 40 rpm, tq. on 6K, 550 gpm, 2225 psi, up wt. 105K, SO wt. 80K, rot. wt. 90K. AST 3.82, ART 3.15, ADT 6.97. Directional drill 12-1/4" surface hole to 3665'. Geo and town consulting on TD pick. Drill to TD at base of SV2. PU wt. 110K, SO wt 75K, Rot. wt. 95K, tq. on 5K, 587 gpm, 2450 psi. AST = 2.45, ART = 6.1, TDT = 8.55. Circulate bottoms up. 575 gpm, 2250 psi, 30 rpm. POH to f 3-3/8" shoe at 536'. Work the tight hole from 3300' to 3287' and at 1977' to 1860' w/25K overpull and swabbing. RIH to 3665'. Work the tight hole from 1860' to 1977'. Found no fill on bottom. 19:00 - 20:00 I 1.001 DRILL I P I I SURF Circulate bottoms up 530 gpm at 2150 psi, 30 rpm. Riciprocate pipe one stand. Printed: 8/26/2005 11:37:59 AM BP EXPLORATION Page 4 of 12 Operations Summary Report Legal Well Name: S-122 Common Well Name: S-122 Spud Date: 7/30/2005 Event Name: DRILL+COMPLETE Start: 7/29/2005 End: 8/21/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/21/2005 Rig Name: NABOBS 7ES Rig Number: Date ' -- From - To' Hours ! Task ~ Code i NPT I Phase 8/3/2005 20:00 - 23:00 3.00 DRILL P SURF 23:00 - 00:00 1.00 DRILL P SURF 8/4/2005 00:00 - 01:30 1.50 CASE P SURF 01:30 - 03:00 1.50 CASE P SURF 03:00 - 03:30 0.50 CASE P SURF 03:30 - 06:00 2.50 CASE P SURF 06:00 - 07:00 1.00 CASE P 07:00 - 16:00 9.00 CASE P 16:00 - 16:30 0.50 CASE P 16:30 - 18:15 1.75 CASE P 18:15 - 18:45 0.50 CASE P i 8:45 - 21:15 I 2.501 CEMT i P 21:15 - 23:00 1.75 CEMT P 23:00 - 00:00 1.00 DIVRTR P 00:00 - 03:00 3.00 BOPSU P 03:00 - 10:30 7.50 BOPSU P 10:30 - 12:00 1.50 BOPSU P 12:00 - 17:30 I 5.501 BOPSUR P 17:30- 18:00 I 0.501 BOPSURP 18:00 - 20:30 2.50 BOPSU P 20:30 - 21:00 0.50 DRILL P 21:00 - 22:00 1.00 DRILL P 22:00 - 00:00 2.00 DRILL P 8/6/2005 00:00 - 01:00 i.00 DRILL P SURF SURF SURF SURF SURF SURF SURF SURF SURF SURF SURF SURF SURF Description of Operations POH to BHA w/not overpull or swabbing. LD BHA #4 up to HWDP. Lay down BHA #4. Clear floor and RU to run 9-5/8" casing. PU 9-5/8" casing hanger/pup and make dummy run. PJSM and RIH w/9-5/8" 40# L-80/K-55/L-80ERW surface casing. Having difficulty w/each 9-5/8" collar at the top of the 13-3/8" casing point. Fill casing w/Franks tool and check floats. Wash down 13 jts. finding clay inside the 13-3/8". Circulate/condition mud 250 gpm @ 200 psi. 530' C~ shoe. Continue running in hole w/problems at each uncentralized jt. hanging at 13-3/8" stump. Lay down Franks fill up tool and fill w/xover. Run centralizers on every other jt. decreasing difficulty getting to bottom. PU 110K, SO 70K. R1H w/9-5/" hanger on split jt. and land at 3658'. RU to circulate. Circulate staging up to 6 bpm C~3 300 psi. PJSM w/Schlumberger, all hands, WSLs. Pressure test lines to 3500 psi. Pump 15 bbls CW 100, 80 bbls Mudpush II, dropped bottom plug and saw plug indicator trip. Mix and pump 341 bbls (448 sx) 10.7 ppg Artic Lite lead slurry,followed by 98 bbls (468 sx) 15.8 ppg tail slurry. Lost circulation for 5 bbls with lead cement past shoe. Pressure 128 psi to 362 psi back to 128 psi. Full returns regained. Dropped top plug and saw plug indicator trip. Displaced with rig pumps C~3 6 bbls/min. 885 psi, bump plug w/3790 stks. Cement returned to surface 148 bbl. Pressured to 1500 psi and held for 5 min. CIP C~ 21:15. Check floats, holding. RD lines, LD cement head. ND diverter and blooey line. Nipple down 20" diverter, flow linen and riser and 16" diverter line. Clean cement from diverter and prepare to NU BOP stack. Install and test FMC casing spool to 1 K psi. for 10 min. Install tubing spool and DSA flange. Prepare location to move satellite camp (Iliamna) to accomodate SIMOPS w/facilities construction crews. Move cement silos. Move dumpsters. Move supplies. Nipple up 13 5/8" BOP. Clean pits. Change pump liners to 5". RU to test BOP. Jeff Jones, AOGCC rep, waived witnessing SOP test. BOP test. Main electric test pump failed. Isolate main pump and rig up back-up air pump and perform test. Tets BOP and associated valves and equipment to 3500 psi high and 250 psi low, tests held for 5 minutes Install wear bushing. RD test equipment. SURF Replace and repair IBOP actuator on top drive. SURF RIH w/HWDP. SURF Cut and slip 117' of drilling line. SURF Pick up and RIH 45 singles of 4" drill pipe. PON and stand back, SURF LD HWDP Printed: 8/26/2005 11:37:59 AM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ~ From - To 8/6/2005 01:00 -04:00 04:00 - 05:00 05:00 - 06:30 06:30 - 07:00 07:00 - 09:00 09:00 - 12:00 12:00 - 13:30 13:30 - 15:30 15:30 - 16:00 16:00 - 17:00 17:00 - 17:30 17:30 - 00:00 S-122 S-122 DRILL+COMPLETE NABOBS ALASKA DRILLING I NABOBS 7ES Start: 7/29/2005 Rig Release: 8/21/2005 Rig Number: Hours Task Code ' NPT ~'~ Phase 3.00 DRILL P INT1 1.00 DRILL P INT1 1.50 DRILL P INT1 0.50 DRILL P INTi 2.00 DRILL P INTi 3.00 DRILL P INT1 1.50 DRILL P , INT1 2.00 DRILL P INT1 0.50 DRILL P INTi 1.00 DRILL P INT1 0.50 DRILL P INT1 6.50 DRILL P INT1 8/7/2005 00:00 - 06:00 6.00 DRILL P INTi 06:00 - 00:00 18.00 DRILL P INTi 8/8/2005 100:00 - 06:00 I 6.001 DRILL I P I I INT1 06:00 - 12:00 I 6.001 DRILL I P I l INT1 12:00 - 00:00 12.001 DRILL P INT1 Page 5 of 12 Spud Date: 7/30/2005 End: 8/21 /2005 Description of Operations PU 111 jts. of 4" drill pipe and RIH to 3532'. RU and test 9-5/8" casing to 3500 psi for 30 min. POH and stand back drill pipe Clear and clean rig floor. PJSM w/Schlumberger, WSL, all rig personnel on handling of BHA nuke sources. Pick up BHA #5. PU and RIH w/99 jts. 4" drill pipe and BHA #5. Tag cement @ 3569'. Drill cement, float equipment, and shoe C~ 3658. Displace hole to 8.8 ppg LSND mud while cleaning out rathole to 3665' ~ 60 rpm, 6K tq. on, 450 gpm, 1200 psi. Drill new hole to 3685'. 60 rpm, 4K tq. on, 450 gpm, 885 psi. RU and perform LOT to 563 psi, 8.8 ppg mud, 12.18 EMW. RD test equipment. Pump per Schlumberger to establish MWD baseline information. Directionally drill from 3685' to 4398'. 3547' TVD. Up wt. 105K, SO wt. 80K, rot. wt. 93K, 555 gpm, 1300 psi off,. 1400 psi on, 120 rpm, 3k tq. off, 4k tq. on. ECDs @ 4398' = 9.55 calculated vs. 10.0 actual. ECD average range from 3818' to 4398' calculated ECD vs. actual ECD = .39, highest calculated ECD vs. actual ECD = .54 @ 4105'. AST = .82, ART = 2.68, ADT = 3.5. Directionally drilling from 4398' to 5833'. Up wt. 115K, SO wt. 90K, rot. wt. 98K, 547 gpm, 1570 psi on, 1480 psi off, 95 rpm, 3k tq. off, 5k tq. on. ECD calc.= 9.56 vs ECD act. = 9.83. AST = 1.53, ART = 6.65, ADT = 8.18. Directionally drilling from 5833' to 7075'. Up wt. 145K, SO wt. 95K, rot. wt. 112K, 550 gpm, 2400 psi on, 2200 psi off, 120 rpm,7.5k tq. off, 9k tq. on. ECD calc.= 9.62 vs ECD act. _ 10.06. AST = 1.88, ART = 4.93, ADT = 6.81. Directionally drilling from 7075' to 7840'. Pump 30 bbl. hi vis sweep at 7080 w/no increase in cuttings. Up wt. 150K, SO wt. 103K, rot. wt. 118K, 547 gpm, 2595 psi on, 2520 psi off, 120 rpm, WOB 5-8K ,7k tq. oft, 8k tq. on. ECD calc.= 9.78 vs ECD act. = 10.29. Directionally drilling from 7840' to 8510'. Pump 40 bbl. hi vis sweep at 8130' w/50% increase in cuttings. Up wt. 155K, SO wt. 110K, rot. wt. 120K, 550 gpm, 2940 psi on, 2790 psi off, 120 rpm, WOB 10-15K, 7.5k tq. off, 9k tq. on. ECD calc.= 9.89 vs ECD act. = 10.34. Directionally drilling from 8510' to 9592'. Pump 35 bbl his vis sweep at 8701' w/25% increase in cuttings. Pump 14.7 ppg "spike" mud w/black products and bring mud wt. to 10.5 ppg. prior to HRZ entry as per program. Saw expectected fluctuation in ECDs while pumping "spike" fluid. ECDs stabilized w/mud stabilization at 10.5ppg. Up wt. 170K, SO wt. 110K, rot. wt. 133K, 550 gpm, 3500 psi on, 3425 psi off, 120 rpm, WOB 7-12K 7k tq. off, 8k tq. on. ECD catc.= 9.72 vs ECD act. = 10.25. 00:00 to 00:00 ADT = 14.99, AST = 2.37, ART = 12.62. Printed: 8/26/2005 11:37:59 AM BP EXPLORATION Operations Summary Report Page 6 of 12 Legal Well Name: S-122 Common Well Name: S-122 Spud Date: 7/30/2005 Event Name: DRILL+COMPLETE Start: 7/29/2005 End: 8/21/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/21/2005 Rig Name: NABOBS 7ES Rig Number: Date I From - To ~ Hours. Task Code NPT Phase Description of Operations 8/9/2005 `00:00 - 06:00 6.00 DRILL P { `INT1 I Directionally drilling 8.75" hole from 9592' to 10062'. Up wt. 06:00 - 12:30 I 6.501 DRILL I P I I INT1 12:30 - 14:00 1.50 DRILL P ~ INT1 14:00 - 19:00 5.00 DRILL P INT1 19:00 - 20:30 1.50 DRILL P INT1 20:30 - 21:00 0.50 DRILL P INT1 21:00 - 00:00 3.00 DRILL P INTi 8/10/2005 00:00 - 03:30 I 3.50 DRILL P INT1 03:30 - 08:00 4.50 DRILL P INT1 08:00 - 10:30 2.50 DRILL P INT1 10:30 - 12:00 1.50 CASE P INT1 12:00 - 12:30 0.50 CASE P INTi 12:30 - 14:15 i.75 CASE P INT1 14:15 - 15:00 0.75 CASE P INT1 15:00 - 19:00 4.00 CASE P INT1 19:00 - 20:00 1.00 CASE P INTi 20:00 - 00:00 4.00 CASE P INTi 8/11/2005 00:00 - 05:00 5.00 CASE P INT1 05:00 - 05:30 0.50 CASE P INT1 05:30 - 07:00 I 1.501 CASE I P I I INTi 07:00 - 09:30 2.501 CASE P INT1 09:30 - 10:30 1.00 CASE P INT1 10:30 - 12:00 1.50 CASE P ~ INT1 175K, SO wt. 113K, rot. wt. 130K, 550 gpm, 3840 psi on, 3680 psi off, 120 rpm, WOB 10-15K, 8k tq. off, 9k tq. on. ECD calc.= 11.28 vs ECD act. = 11.64. Directionally drilling from 10062' to 10731'. TD for 8.75" hole. Up wt. 190K, SO wt. 113K, rot. wt. 135K, 525 gpm, 4050 psi on, 3950 psi off, 120 rpm, WOB 10-15K, 11k tq. off, 13k tq. on. ECD calc.= 11.17 vs ECD act. = 11.56. Pump sweep and CBU @ 550 gpm, 4050 psi, 120 rpm, 10K tq. Reciprocate pipe. POH to 4009', working tight spots f/10500' to 10325' w/45K overpull. Work tight spots f/6900' 6750' 25K overpull. MAD Pass f/caliper data f/4000' to 3750' as per ODE. Continue POH to shoe @ 3658' Service top drive and rig. RIH to 10731' filling drill pipe every 2500'. 00:00 to 00:00 ADT = 8.98, ART = 6.38, AST =2.60. Wash down last stand and circulate 32 bbl hi vis sweep, add lubricants, CBU. 500 gpm, 4000 psi, 115 rpm, reciprocate pipe. Monitor well, pump dry job. POH w/BHA # 5. Hole looking good. PJSM before handling nukes and LD BHA # 5. Pull wear ring. Change rams to 7". RU to test. Body test BOP to 3500 psi, R/D Test equipment. RU to run 7" casing. Make dummy run w/hanger and mark landing jt. for measurement. Test and restart emergency shutdown. Test evacuation capabilities. PU shoe track and check floats. RIH w/ 7" casing to shoe @ 365i'. Fill each jt. wJFranks tool. Break circulation each 15 jts. Circulate 1.5 casing volumes at shoe, stage up to 6 bpm, 500 psi. Up wt. 105K, SO wt. 85K. RIH to 6888'. Up wt. 175K, SO 100K. No fluid losses to hole. RIH w/7" casing and land w/shoe at 10701'. Fill each joint w/Franks fill up tool. Break circulation each 15 jt. LD Franks tool. Blow down top drive. MU landing jt. and hanger. Land hanger. Rig up cement head w/Tee. Rig up Schlumberger. Break circulation, stage pumps up to 6 bpm at 950 psi. CBU and condition hole. PJSM w/Shchlumberger, all hands, and WSL. Test lines to 4000. Clear water from lines through Tee and pump 35 bbls mud push @ 11 ppg. Drop bottom plug. Pump 175 bbls. Arctic Lite lead cement @ 11.0 ppg. Pump 57 bbls tail cement Cal 15.8 ppg. Drop top plug. Clear cement from lines through Tee. Displace w/seawater w/rig pumps until plugs bump at 409 bbls. Pressure to 2500 psi and hold 5 minutes. Bleed off pressure and check floats. RD cement head. LD landing jt. RD casing equipment. RU top drive. Change rams. Install packoff and test to 3800 psi. Printed: 8/26/2005 11:37:59 AM BP EXPLORATION Operations Summary Report Page 7 of 12 Legal Well Name: S-122 Common Well Name: S-122 Spud Date: 7/30/2005 Event Name: DRILL+COMPLETE Start: 7/29/2005 End: 8/21/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/21/2005 Rig Name: NABOBS 7ES Rig Number: Date From - To i Hours j Task j Code - -- -'! - - r - -_ - 8/11/2005 (12:00 - 13:00 I 1.001 CASE ~ P 13:00 - 21:00 21:00 - 00:00 8/12/2005 00:00 - 03:00 8.00 STWHIP N 3.00 STWHIP C 3.00 STWHIP C 03:00 - 03:30 03:30 - 04:30 04:30 - 08:00 08:00 - 10:00 10:00 - 11:30 f 1:30 - 13:00 13:00 - 18:00 18:00 - 18:15 18:15 - 18:45 18:45 - 23:15 23:15 - 00:00 8/13/2005 00:00 - 02:30 02:30 - 03:30 03:30 - 04:00 04:00 - 05:00 05:00 - 08:00 08:00 - 10:30 10:30 - 11:30 11:30 - 13:30 13:30 - 14:30 14:30 - 15:00 15:00 - 18:30 0.50 STWHIP C 1.00 STWHIP P 3.50 STWHIP C 2.00 STWHIP P 1.50 STWHIP P 1.50 STWHIP P 5.00 STWHIP P 0.25 STWHIP P 0.50 STWHIP P 4.50 STWHIP P 0.75 STWHIP P 2.50 STWHIP P 1.00 STWHIP P 0.50 STWHIP P 1.00 STWHIP P 3.00 STWHIP P 2.50 STWHIP P 1.00 STWHIP P 2.00 DRILL P 1.00 DRILL P 0.50 DRILL P 3.501 DRILL I P NPT I Phase ~ Description of Operations INT1 RU and test upper pipe ram to 250 psi low and 3500 psi high. RD test. Install wear bushing. DFAL PROD1 PJSM w/Schlumberger wireline, all hands, and WSL. RIH w/6.115 gage ring and junk basket. RIH w/Halliburton 7" EZSV bridge plug and correlate to 10226 WL measurement. Firing head malfunctioned. Saw indication of burn at top of igniter but igniter did not go. POH and RD Schlumberger. PROD1 PU EZSV & RIH on 4" DP from derrick. Clear 7" x 9 5/8" annulus w/85 of 110 bbls mud. Took 2700 psi to break down, Avg pressure 1200 at 2 bpm. PRODi TIH w/EZSV on drill pipe to 10233' and set. While TIH pump remaining 25 bbls of 110 bbls mud down 7" x 9-5/8" annulus and use Hot Oil to put 65 barrels of diesel freeze protect down 9-5/8" x 7" annulus. PROD1 Set EZSV @ 10233' with mechanical release setting tool. PROD1 RU and perform 7" casing test to 3500 psi for 30 min. PROD1 POH w/ mechanical EZSV setting tool. PROD1 PU Whipstock BHA PRODi Engineers measure stabbing board and derrick for mods. PROD1 Continue w/PU Whipstock BHA. PU 9 spiral collars, 24 jts. HW DP. PROD1 RIH w/7" Whipstock BHA #6. PROD1 Orient MWD/Whipstock C~3 10195'. Up wt. 180K, do wt. 108K. PROD1 Tag EZSV @ 10,233' and set anchor w/18K down. PU 15K over string wt. to check anchor set. SO and see the lug shear at 35K down. Whipstock set at 24 degrees LOHS. PROD1 Circulate 9.4# Flo-Pro mud to well and mill window. 250 gpm, 2220 psi, rpm 75, WOB 1-f8K. TOW = 10217', 6738' TVD, BOW = 10229'. PROD1 Drilling in OH from 10229' to 10234'. Up wt 150K, dn. f07K, rot. wt. 125, 300 gpm, 1973 psi, 117 rpm, tq. on 6K, tq. off 4K, 15K WOB. PRODi Mill window + 20' OH to 10243'. PROD1 Pump hi vis sweep 350 gpm @ 2300 psi. Circulate hole clean and bring mud wt. to 9.4 ppg in and out. Total of 193# metal cuttings returned from wellbore. Work mills through window until smooth. PROD1 RU and do FIT to 11.0 # EMW w/9.4# mud Cam? 6738' TVD to 564 psi. PROD1 Cut and slip drilling line. PROD1 Monitor well, pump dry job and POH w/milling BHA #6. PROD1 LD BHA. Check mills in gauge. PROD1 Pull wear bushing and jet stack clean of mill cuttings. PROD1 PU BHA # 7 w/2.0 deg ShortPak motor and MXI8HDX PDC bit. PROD1 RIH w/ BHA # Ito 1640' and flow test MWD. PRODi Trace of oil observed in mud, small amount of gas breaking out in flow nipple. Shut well in and monitor. DP / CSG psi = 0. Open rams. WSL advised BPX ANC & AOGCC as required. MW cut by 0.2 ppg. PROD1 ~ RIH f/1640' to 10153'. After displacing 15 bbls out on trip in, +MW back to 9.4 ppg. Printed: 8/26!2005 11:37:59 AM BP EXPLORATION Page 8 of 12 Operations Summary Report Legal Well Name: S-122 Common Well Name: S-122 Spud Date: 7/30/2005 Event Name: DRILL+COMPLETE Start: 7/29/2005 End: 8/21/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/21/2005 Rig Name: NABOBS 7ES Rig Number: Date :From..- To ~ Hours I Task I Code NPT I Phase Description of Operations 8/13/2005 ~ 18:30 - 19:00 ~-- -t __-- - - _ -_ - - 0.50 DRILL P ~ ~PROD1 I Orient motor above window C~? 10 217 ft. Slide thru window w/ 19:00 - 20:30 I 1.501 DRILL 20:30 - 21:30 1.00 DRILL 21:30 - 00:00 2.50 DRILL 8/14/2005 00:00 - 02:00 2.00 DRILL 02:00 - 04:00 2.00 DRILL 04:00 - 05:30 1.50 ~ DRILL 05:30 - 06:30 ~ 1.00 DRILL 06:30 - 09:00 2.50 DRILL 09:00 - 23:30 I 14.501 DRILL 23:30 - 00:00 0.50 DRILL 5/2005 00:00 - 05:30 5.50 DRILL 05:30 - 21:45 I 16.251 DRILL 21:45 - 22:45 1.00 DRILL 22:45 - 23:15 0.50 DRILL 23:15 - 00:00 I 0.751 DRILL 8/16/2005 100:00 - 04:30 I 4.501 DRILL 04:30 - 12:00 ~ 7.50 ~ DRILL 12:00 - 00:00 I 12.001 DRILL pumps off. Wash to btm C~3 10243' P PROD1 Directionally drill f/10243' to 10345' and per DD achieve necessary angle. Up 165K, SO 115K, 2560 psi on, 2200 psi on, 280 gpm, tq. 0, rpm 0. Wt up Mud to 9.6 ppg w/ NaCL No gas at surface, no losses. ADT = 1.26, AST = 1.26. P PROD1 CBU, 254 bbls, 282 gpm, 2600 psi. Monitor well. P ~ PROD1 POH to window at 10217', monitor well, pump dry job, POH to 4609'. P PROD1 POH to BHA. Monitor well. P PROD1 PJSM w/Schlumberger and all hands to handle nukes. LD/stand back BHA #7. Clear floor. P i PROD1 PJSM w/Schlumberger and all hands to handle nukes. PU BHA # 8 w/1.5 deg. motor assy. P i PROD1 PU 30 jts. of drill pipe. P j PROD1 RIH to 10165' and orient w/MWD to 25 deg. LOHS. Run through window w/pumps off, no rotation. P PROD1 RIH and tag at 10345'. Drill to 10853'. Up wt. 168K, SO 105K, rot wt. 125K, tq. on 7K, tq. off 6K, 281 gpm, 2700 psi. 00:00 to 00:00 ADT = 7.75, AST = 7.07, ART = .68. C PROD1 Per geo HRZ penetrated. Town geo/engineer consulted. Pull back to 10,420' at 96 deg. and trench for KOP at 10450'. C PROD1 Trench 10420' to KOP @ 10450'. Per DD trench 1 hr, time drill 2'/hr f/2 hrs = 4', time drill 5'/hr for 2 hrs. = 10'. Drilling Q 10,485 ft. Inc at bit showing sucessful side track. Commence increasing WOB. C PRODi Drill in OH sidetrack f/10485' to 11460'. Drill into HRZ C~ 10836' MD, 6771' TVD. Consult w/town geo/engineer and continue to 11460' for logging purposes. Up wt. 165K, SO wt. 110K, rot. wt. 120K, tq. on 7-8K, tq. off 5K, 281 gpm, 2750 psi, C PROD1 POH to window C~3 10,217' and monitor well. No problems through window. C PRODf RIH to 10380' and orient motor low side for trench and sidetrack. No problems through window. C PROD1 Directional drill. Begin OH sidetrack #2. Trench 1 hr. f/10357' to KOP C~ 10380'. 00:00 to 00:00 ADT = 21.92, AST = 18.07, ART = 3.85. C PROD1 -Trench per DD from 10,355' to 10,381'. Time drill 2 FPH for 4', time drill 5 FPH for 10'. - Inc at bit showing successful sidetrack. OH sidetrack kick off point @ 10,381' - Commence increasing WOB. C PROD1 -Drill directional in 6 1/8" hole from 10,395' to 10,672'. WOB 20K, 295 GPM, 2550 psi, P/U wt 170K, S/O wt 110K, 100% slide. C PRODi -Drill directional in 6 1/8" hole from 10,672' to 11,121'. WOB 10-20K, 290 GPM, 2550 psi, 80 RPM, Tq on bottom 5K, Tq off bottom 4K, P/U wt 160K, S/O wt 110K, Rot wt 120K. - Pumped hi-vis sweep @ 10,898' w/ 100% excess cuttings seen @ shakers on B/U. - Last 24 hrs: AST 12.96 hrs, ART .89 hrs, ADT 13.85 hrs. Printed: 8/26/2005 11:37:59 AM BP EXPLORATION Page 9 of 12 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date ~ Name: ell Name: e: Name: From - To ~~ S-122 S-122 DRILL+C NABOB NABOB Hours ~ OMPLE S ALASK S 7ES Task ~'~ TE A DRI Code ~ LING NPT ~ Start I Rig Rig Phase j Spud Date: 7/30/2005 : 7/29/2005 End: 8/21/2005 Release: 8/21/2005 Number: Description of Operations 8/17/2005 00:00 - 15:30 6.00 ~ DRILL P PROD1 -Drill directional in 6 1/8" hole from 11,121' to 12,173'. WOB _.. 10-15K, 290 GPM, 2950 psi, 80 RPM, Tq on bottom 8K, Tq off bottom 5K, P/U wt 165K, S/O wt 110K, Rot wt 120K. Pumped hi-vis sweeps every 500'. - AST 2.8 hrs, ART 8.03 hrs, ADT 10.83 hrs. 15:30 - 17:00 1.50 DRILL P PROD1 - CBU @ 300 GPM, 2875 psi, 80 RPM & reciprocating drill string. - Monitor well. 17:00 - 18:30 ~ 1.50 DRILL P PROD1 - POH to above 7" window. Wipe tight spot w/ 40K drag C~ 11,654' & backream full stand (~3 tight spot at 11,565'. 18:30 - 19:00 0.50 DRILL P PROD1 -Service TD & lubricate rig. - Monitor well. 19:00 - 19:30 0.50 DRILL P PROD1 -RIH & tag up ~ 10,710'. Survey indicates wrong hole & log shows tag up area is where HRZ was originally encountered. 19:30 - 20:00 0.50 DRILL P PROD1 - POH to above sidetrack area. 20:00 - 22:30 2.50 DRILL P PROD1 -Orient motor low side & dress up sidetrack & trench area from 10,347 to 10,440'. 22:30 - 23:30 1.00 DRILL P PROD1 - RIH to bottom - no problems -hole slick. 23:30 - 00:00 0.50 DRILL P PROD1 -Pump hi-vis 2 Ib. over MW sweep & circulate ~ 320 GPM, 3100 psi, 80 RPM, & reciprocating string. 8/18/2005 00:00 - 01:00 1.00 DRILL P PROD1 -Circulate out hi-vis 2 Ib over MW sweep ~ 320 GPM, 3100 psi, 80 RPM, & reciprocating drill string. Approximately 15% excess cuttings on BlU. 01:00 - 02:00 1.00 DRILL P PROD1 -Monitor well - POH w/ no problems -hole slick. 02:00 - 02:30 0.50 DRILL P PROD1 -Orient motor high side &RIH to 10,440' to ensure access to proper hole. Survey confirmed in proper hole. 02:30 - 05:30 3.00 DRILL ~ P PROD1 - POH to window -pump dry job & drop rabbit. - Continue POH. 05:30 - 07:00 1.50 DRILL P PROD1 -PJSM for handling source. - Pull source & L/D BHA. 07:00 - 07:30 0.50 CASE P PRODi -Clear & clean rig floor. - R/U to run 4 1/2" liner. 07:30 - 10:30 3.00 CASE P PROD1 - M/U & run 52 jts of 4 1/2" N-80 11.6# LTC 8RD liner. M/U Tq - 2K ft/Ibs. - M/U C-2 hanger / ZXP packer. 10:30 - 11:00 0.50 CASE P PROD1 -Circulate 1 liner volume. P/U wt 55K, S/O wt 53K. - R/D tubing handling equip't. 11:00 - 17:00 6.00 CASE P PROD1 -RIH w/ 4 1/2" liner on 4" DP to above window filling every 10 stands. 17:00 - 17:15 0.25 CASE P PROD1 - P/U jt 4" DP & M/U to cement head. UD cement head on skate. 17:15 - 18:00 0.75 CASE P PROD1 -Stage up pumps & circ string volume. ICP @ 3 BPM 535 psi, ~ FCP @ 6 BPM 1105 psi. - P/U wt 150K, S/O wt 110K. 18:00 - 19:30 1.50 CASE P PROD1 -Continue running 4 1/2" liner on 4" DP. - M/U cement head, valves, tee, & hoses. 19:30 - 21:00 1.50 CASE P PROD1 -Stage up pumps from 1 BPM to 5.5 BPM & circulate in preparation for cement job. ICP C~ 1 BPM 390 psi, 5.5 BPM 1400 psi. Reciprocate string 30' while circulating. P/U wt 160K, S/O wt110K. - PJSM for cementing while circulating. 21:00 - 22:30 1.50 CEMT P PROD1 -Pump 3 bbls water & test lines to 4000 psi. Pump 25 bbls 10.7 ppg Mud push II followed by 57 bbls (209 sx) 15.8 ppg Printed: 8/26/2005 11:37:59 AM BP EXPLORATION Page 10 of 12 Operations Summary Report Legal Well Name: S-122 Common Well Name: S-122 Spud Date: 7/30/2005 Event Name: DRILL+COMPLETE Start: 7/29/2005 End: 8/21/2005 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 8/21/2005 Rig Name: NABORS 7ES Rig Number: Date i From - To ~I Hours I Task ~ Code ~ NPT I Phase - - - -_. _~ ~- _ 1 - - - 8l18/2005 121:00 - 22:30 1.501 CEMT P ~ I PROD1 22:30 - 23:30 I 1.001 CEMT I P 23:30 - 00:00 i 0.50 ~ CASE i P 8/19/2005 100:00 - 00:30 I 0.501 CASE I P 00:30 - 01:30 1.00 CASE P 01:30 - 03:00 1.50 CASE P 03:00 - 05:30 2.50 CASE P 05:30 - 06:00 0.50 CASE P 06:00 - 07:00 1.00 BOPSU P 07:00 - 10:00 I 3.001 BOPSUR P 10:00 - 10:30 0.50 BOPSU P 10:30 - 11:30 1.00 CASE P 11:30 - 12:30 1.00 CASE P 12:30 - 15:30 I 3.001 CASE I P 15:30 - 17:00 1.50 CASE P 17:00 - 17:30 0.50 CASE P 17:30 - 23:00 5.50 CASE P 23:00 - 23:30 I 0.501 CASE I P 23:30 - 00:00 I 0.501 CASE I P PROD1 Description of Operations Class G cement w/ gasblok. Wash up cementers via bypass line. Drop dart & turn over to rig pumps & displace cement w/ 35 bbl pert pill followed by 96.7 bbls of 9.7 ppg flo-pro mud. Bump plug & increase pressure to 3500 psi & set hanger. S/O 45K to ensure hanger set. Bleed off pressure & check floats - floats holding. - Reciprocated string throughout cement job. - Rotate string 15 revolutions to release from hanger. - Apply 1000 psi & P/U string 7'. Increase pump rate once packoff clear of extension &circ 30 bbls @ 7 BPM to clear cement. - Slack off 55K to set packer & saw indication of packer setting. Repeat sequence w/ rotation to ensure packer set. - P/U string 15' &circ out cement ~ 385 GPM 2635 psi. Approximately 23 bbls cement back to surface. - R/D cementing head, jt of DP, hoses, tee, & valves. - P/U & UD 1 additional jt of 4" DP to ensure Baker running tool clear of liner top PRODi -Displace well to 9.7 brine by pumping 50 bbl 9.7 ppg brine spacer w/ 1 drum of Safe Surf W followed by 9.7 ppg brine ~ 335 GPM 1475 psi & reciprocating string. PROD1 -Displace well to 9.7 ppg brine C~3 335 GPM, 1475 psi while reciprocating string. PROD1 -Slip & cut 114' of drilling line. PROD1 - POH & UD 66 jts 4" DP. PROD1 - POH & rack back 4" DP - Dog sub on Baker liner hanger running tool sheared. PROD1 -Make service breaks on hanger running tool. UD same. PROD1 -Pull bowl protector. - R/U equip't to test BOPE. PROD1 -Test BOPE per BP & AOGCC regs. Test all equip't to 250 psi / 3500 psi. Charted & held each test for 5 minutes. Test witnessed by WSL Lance Vaughan. Witness of test waived by AOGCC Rep John Crisp. PROD1 - R/D test equip't & B/D lines. PROD1 -PJSM for running pert guns. - R/U to run pert guns. PRODi - R/U & pressure test 4 1/2" x 7" liner /casing to 3500 psi. Charted & held for 30 minutes. - PJSM for running pert guns with new crew. PROD1 - M/U & RIH w/ 2 1/2" pert guns. - R/D pert gun handling equip't. PROD1 - R/U 2 7/8" handling equip't &RIH w! 12 jts 2 7/8" PAC DP. PROD1 - P/U & M/U Halliburton champ packer & bypass sub. PROD1 -RIH w/ pert guns on 4" DP. Tag landing collar on depth @ 12,039'. P/U & place guns on depth @ 12,030' PROD1 -Pump 34 bbls fresh water down DP to achieve 210 psi underbalance for perforating. 4 BPM 630 psi. PROD1 -Apply 4 turns to string & set champ packer. S/O 20K to ensure packer set. - Close annular preventer & apply 200 psi to ensure bypass sub above packer closed. Printed: 8/26!2005 11:37:59 AM ~~ BP EXPLORATION Page 11 of 12 Operations Summary Report Legal Weli Name: S-122 Common Well Name: S-122 Spud Date: 7/30/2005 Event Name: DRILL+COMPLETE Start: 7/29/2005 End: 8/21/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/21/2005 Rig Name: NABOBS 7ES Rig Number: I II From - To Date ~ Hours ~ Task Code ~ NPT I Phase Description of Operations 8/19/2005 23:30 - 00:00 - _ - 0.50 CASE P PROD1 -Follow perforation gun pressure sequence & fire guns. Good surface indication of guns detonating. - Planned perforations at 6 spf at the following intervals: 10,220' to 10,250' 10,300' to 10,440' 10,500' to 10,550' 10,600' to 10,650' 10,700' to 10,750' . 10,890' to 10,940' ' 10,980'to 11,070' ` 11,120' to 11,270' 11,350' to 11,400' i 11,450' to 11,550' - 11, 600' to 11, 750' 11,800'to 12,030' 8/20/2005 00:00 - 01:00 ~ 1.00 CASE P ' PROD1 -Open up bypass sub above packer by picking up string. -Reverse circulate 2 drill string volumes @ 5 BPM 1395 psi. 7 bbls oil contaminated brine seen at pits after first drill pipe volume circulated out. 01:00 - 02:00 1.00 CASE P PROD1 -Open annular preventer & unseat champ packer. - POH w/ 20 stands DP to above top perforations. - Monitor well -static losses @ 4 BPH -losses while POH ~ 4 BPH. 02:00 - 05:00 3.00 CASE P PROD1 - POH & UD 4" DP 1 x 1. 05:00 - 06:00 1.00 CASE P PROD1 -Replace hoses on TD pipehandler. 06:00 - 09:00 3.00 CASE P PROD1 - POH & UD 4" DP 1 x 1. - LD 7" HES 'Champ' packer. 09:00 - 10:00 1.00 CASE P PROD1 - RD 4" handling equip. RU 2 718" handling equip. - POH & UD 2 7/8" DP 1 x 1. 10:00 - 10:30 0.50 CASE P PROD1 -PJSM for LD perf guns 10:30 - 16:30 6.00 CASE P PROD1 - POH LD perf guns. Confirm all 100% fired. 16:30 - 18:00 1.50 CASE P PROD1 - RD perf gun handling equip. - Clear & clean rig floor 18:00 - 20:30 2.50 CASE P PROD1 - RIH w/ 20 stds of 4" DP from derrick. POH LD same. 20:30 - 22:30 2.00 BUNCO RUNCMP -Pull wear ring. - RU to run 3 1/2" x 4 1/2" completion. - PJSM with all parties 22:30 - 00:00 1.50 BUNCO RUNCMP - PU / MU &RIH completion - WLEG, pup, X nipple, pup, pup, X nipple, pup, pup, Baker 'Premier' pkr, pup, pup, 'Symphony' ~ gauge carrier, pup, pup, X nipple, pup, pup, 4140 CMD SSD, pup, 1 jt 3 1/2" L 80 9.2#, IBT tbg, pup, 3 1/2" x 1 1/2" MMG GLM w/dummy 8/21/2005 00:00 - 08:30 8.50 BUNCO RUNCMP -Run 3 1/2" 9.2# L-80 IBT-M tubing w/HES Symphony pressure /temperature gauge carrier, 1-wire & clamps. Ran a total of 159 jts 3 1 /2". 08:30 - 09:30 1.00 BUNCO RUNCMP - R/D 3 1/2" handling equip't & R/U 4 1!2" handling equip't. - M/U 3 1 /2" x 4 1 /2" X-over. 09:30 - 16:30 7.00 BUNCO RUNCMP -Run 4 1/2" 12.6# L-80 IBT-M tubing. w/HES Symphony ~ pressure /temperature gauge carrier, I-wire, & clamps. Printed: 8/26/2005 11:37:59 AM BP EXPLORATION Page 12 of 12 Operations Summary Report Legal Well Name: S-122 Common Well Name: S-122 Spud Date: 7/30/2005 Event Name: DRILL+COMPLETE Start: 7/29/2005 End: 8/21/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/21/2005 Rig Name: NABOBS 7ES Rig Number: - Task Code I NPT I Phase ~ Description of Operations Date i From - To it Hours I, - -_~ ~ _~ _- - _. _ -- -- - 8/21/2005 116:30 - 18:00 18:00 - 18:30 18:30 - 20:30 20:30 - 22:00 22:00 - 23:00 23:00 - 00:00 8/22/2005 00:00 - 01:30 01:30 - 03:30 03:30 - 04:00 04:00 - 05:00 05:00 - 07:00 07:00 - 08:00 1.50 BUNCO RUNCMP - M/U jt 117 & RIH & tag up inside of liner tie back sleeve C~3 9985'. UD jt 117 & M/U hanger & landing jt. Attach I-wire to hanger. Land hanger 5.5' inside of tie back sleeve @ 9980'. RlLDS. P/U wt 120K, S/O wt 80K. - Ran a total of 116 jts 4 1/2" tubing. - Total I-wire protectors run as follows: 164 3 1/2" over the collar protectors 11 3 1/2" mid jt protectors 116 4 1/2" over the collar protectors 2 4 1/2" mid jt protectors & 1 stainless steel band directly underneath tubing hanger. 0.50 BUNCO RUNCMP - M/U headpin & hose - R/U to reverse circulate. 2.00 BUNCO RUNCMP -Reverse circulate 120 bbls 9.7 ppg brine followed by 135 bbls 9.7 ppg inhibited brine and another 91 bbls 9.7 ppg non-treated brine. Rerverse circulate ~ 3 BPM 475 psi. 1.50 BUNCO RUNCMP -Drop ball & rod & apply pressure to tubing to 4200 psi. Set packer & hold 4200 psi on tubing for 30 minutes. Bleed off tubing pressure to 2000 psi & test annulus to 3500 psi. Hold pressure for 30 minutes. Bleed off annulus pressure to zero & follow by bleeding off tubing pressure to zero. Apply pressure to annulus and shear DCR valve in upper most GLM C~ 2450 psi. Reverse circulate 2 bbls -circulate through tubing 2 bbls to ensure DCR valve fully open. 1.00 BUNCO RUNCMP - R/D headpin & hose. UD landing jt. B/D lines. Dry rod in TWC valve & test to 1000 psi. 1.00 BOPSU P WHDTRE - N/D BOPE 1.50 BOPSU P WHDTRE - N/D BOPE. 2.00 WHSUR P WHDTRE -Test hanger seals to 5000 psi. - N/U tree & test to 5000 psi. 0.50 WHSUR P WHDTRE - R/U Drill Site Maintenance lubricator & pull TWC. 1.00 WHSUR P WHDTRE - R/U lines to freeze protect & U-tube. - Test lines to 2500 psi. 2.00 WHSUR P WHDTRE -Pump 165 bbls warm diesel down IA & allow to U-tube to balance point. (3800' TVD) - 380 psi on tubing & annulus once U-tube complete. 1.00 WHSUR P WHDTRE -Install BPV w/ lubricator & test BPV to 1000 psi. Install VR plugs in IA valves. - Secure cellar & release rig from S-122 C~ 0800 hrs. Printed: 8/26/2005 11:37:59 AM S-122PB1 Su Client: BP Exploration Alaska Field: Prudhoe Bay Unit - WOA Structure /Slot: S-PAD / S-122 Well: S-122 Borehole: S-122P81 UWIIAPI#: 500292326570 Survey Name /Date: S-122P61 /August 9, 2005 Tort /AHD / DDI / ERD ratio: 160.846° / 7293.05 ft / 6.256 / 1.044 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location LaVLong: N 70 21 20.292, W 149 2 2.940 location Grid WE YIX: N 5980594.899 ftUS, E 618929.906 ftUS Grid Convergence Angle: +0.90964481° Grid Scale Factor: 0.99991607 Report Sc~~~mbeger Vertical Section Azimuth: 334.950° Vertical Section Origin: N 0.000 ft, E 0.000 ft TVD Reference Datum: RKB TVD Reference Elevation: 64.25 ft relative to MSL Sea Bed /Ground Level Elevation: 35.70 ft relative to MSL Magnetic Declination: 24.689° Total Field Strength: 57588.817 nT Magnetic Dip: 80.881 ° Declination Date: July 27, 2005 Magnetic Declination Model: BGGM 2005 North Reference: True North Total Corr Mag North -> True North: +24.689° Local Coordinates Referenced To: Well Head Measured Vertical Along Hole Comments Inclination Azimuth Sutrtiea TVD TVp 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 Fi I t V.VV V.VV V.VV -t)4.Z5 V.VV V.VV V.VU V.VV U.VV V.VV V.VV b`J25Ub`J4.`JV bliS`JL`J.`JI IV /U Z I ZV.LyL W 14y Z Z.`J4U First GYD GC SS 76.00 0.46 357.51 11.75 76.00 0.28 0.31 0.31 0.30 -0.01 0.61 5980595.20 618929.89 N 70 21 20.295 W 149 2 2.940 100.00 0.35 24.42 35.75 100.00 0.42 0.47 0.47 0.47 .0.01 0.90 5980595.37 618929.91 N 70 21 20.297 W 149 2 2.940 198.00 0.14 17.76 133.75 198.00 0.70 0.89 0.87 0.85 0.17 0.22 5980595.76 618930.07 N 70 21 20.300 W 149 2 2.935 250.00 0.82 128.20 185.75 250.00 0.42 1.26 0.84 0.68 0.48 1.69 5980595.59 618930.38 N 70 21 20.299 W 149 2 2.926 300.00 1.38 131.84 235.74 299.99 -0.46 2.22 1.22 0.06 1.21 1.13 5980594.98 618931.12 N 70 21 20.293 W 149 2 2.904 349.00 2.46 116.46 284.71 348.96 -1.82 3.85 2.72 -0.80 2.60 2.42 5980594.14 618932.51 N 70 21 20.284 W 149 2 2.864 438.00 4.60 109.24 373.53 437.78 -5.81 9.33 8.18 -2.83 7.68 2.45 5980592.19 618937.63 N 70 21 20.264 W 149 2 2.716 500.00 4.50 121.68 435.34 499.59 -9.58 14.23 13.06 -4.92 12.09 1.60 5980590.17 618942.07 N 70 21 20.244 W 149 2 2.586 550.00 3.76 126.03 485.21 549.46 -12.66 17.83 16.60 -6.92 15.09 1.61 5980588.22 618945.10 N 70 21 20.224 W 149 2 2.499 650.00 2.62 149.64 585.06 649.31 -17.80 23.31 21.77 -10.82 18.90 1.72 5980584.38 618948.97 N 70 21 20.186 W 149 8 708.00 2.61 158.31 643.00 707.25 -20.44 25.96 24.00 -13.19 20.05 0.68 5980582.03 618950.16 N 70 21 20.162 W 149 4 800.00 2.20 159.68 734.92 799.17 -24.29 29.82 27.23 -16.79 21.44 0.45 5980578.45 618951.61 N 70 21 20.127 W 149 2 2.313 893.00 2.38 160.82 827.84 892.09 -27.99 33.53 30.44 -20.29 22.70 0.20 5980574.97 618952.92 N 70 21 20.092 W 149 2 2.277 925.00 2.29 157.96 859.82 924.07 -29.29 34.84 31.60 -21.51 23.15 0.46 5980573.76 618953.40 N 70 21 20.080 W 149 2 2.263 1000.00 1.65 172.65 934.77 999.02 -31.82 37.40 33.82 -23.97 23.85 1.08 5980571.31 618954.14 N 70 21 20.056 W 149 2 2.243 1079.00 1.59 290.46 1013.76 1078.01 -32.12 38.96 33.74 -24.72 22.97 3.51 5980570.55 618953.27 N 70 21 20.049 W 149 2 2.268 1100.00 1.85 294.16 1034.75 1099.00 -31.65 39.59 33.17 -24.48 22.39 1.35 5980570.78 618952.68 N 70 21 20.051 W 149 2 2.285 1200.00 2.59 300.25 1134.67 1198.92 -28.57 43.46 29.56 -22.68 18.97 0.78 5980572.53 618949.23 N 70 21 20.069 W 149 2 2.386 1250.00 2.69 299.72 1184.62 1248.87 -26.69 45.77 27.41 -21.53 16.97 0.21 5980573.65 618947.21 N 70 21 20.080 W 149 2 2.444 1300.00 3.79 296.81 1234.54 1298.79 -24.43 48.59 24.85 -20.20 14.48 2.22 5980574.93 618944.70 N 70 21 20.093 W 149 2 2.517 1350.00 5.35 295.83 1284.38 1348.63 -21.32 52.57 21.42 -18.44 10.90 3.12 5980576.64 618941.10 N 70 21 20.111 W 149 2 2.621 1400.00 6.74 295.32 1334.10 1398.35 -17.25 57.84 17.30 -16.17 6.15 2.78 5980578.83 618936.31 N 70 21 20.133 W 149 2 2.760 SurveyEditor Ver SP 1.0 Bld( doc40x_56) S-122\S-122\S-122PB1\S-122PB1 Generated 9/19!2005 11:58 AM Page 1 of 4 Comments Measured Inclination Azimuth Sub-Sea 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 145U.UU y.iSb L`J4.tSb 13253.5/ 144/.iSC -11./L liS.Uli 13.10 -1"3.11 -U.3y b.L4 5y2fU5251./t5 b1tS`JL`J./3 N /U"Ll LU.lb3 VV 14yL"L.y51 1500.00 11.78 293.85 1432.68 1496.93 -4.59 74.44 12.86 -9.25 -8.94 3.86 5980585.51 618921.12 N 70 21 20.201 W 149 2 3.201 Last GYD GC SS 1550.00 12.79 294.19 1481.53 1545.78 3.45 85.08 19.29 -4.92 -18.66 2.03 5980589.69 618911.33 N 70 21 20.244 W 149 2 3.485 First MW D+IFR+MS 1591.98 13.70 289.72 1522.39 1586.64 10.47 94.69 27.61 -1.33 -27.57 3.26 5980593.13 618902.36 N 70 21 20.279 W 149 2 3.746 1686.98 17.48 286.46 1613.88 1678.13 27.85 120.21 52.26 6.51 -51.86 4.08 5980600.58 618877.96 N 70 21 20.356 W 149 2 4.456 1782.38 19.02 296.93 1704.51 1768.76 49.60 150.01 81.39 17.61 -79.47 3.79 5980611.24 618850.18 N 70 21 20.465 W 149 2 5.263 1877.83 22.05 306.79 1793.91 1858.16 77.67 183.42 113.36 35.39 -107.70 4.81 5980628.58 618821.67 N 70 21 20.640 W 149 2 6.088 1972.81 23.31 311.47 1881.55 1945.80 110.62 220.03 148.11 58.52 -136.06 2.32 5980651.25 618792.95 N 70 21 20.868 W 149 2 6.917 2068.14 26.24 315.83 1968.10 2032.35 147.85 259.95 186.03 86.13 -164.88 3.62 5980678.40 618763.69 N 70 21 21.139 W 149 2 7.760 2164.41 28.11 320.93 2053.76 2118.01 189.97 303.90 227.61 119.01 -194.01 3.10 5980710.81 618734.04 N 70 21 21.462 W 149 2 8.612 2260.49 31.38 323.87 2137.17 2201.42 236.49 351.55 272.64 156.80 -223.04 3.73 5980748.13 618704.43 N 70 21 21.834 W 149 0 2355.35 31.69 328.13 2218.03 2282.28 285.47 401.15 319.46 197.92 -250.76 2.37 5980788.79 618676.06 N 70 21 22.238 W 149 2 0 2451.14 34.18 332.79 2298.43 2362.68 337.36 453.20 368.15 243.23 -276.36 3.71 5980833.69 618649.75 N 70 21 22.684 W 149 2 11.019 2545.77 36.71 338.59 2375.54 2439.79 392.17 508.05 418.67 293.22 -298.85 4.45 5980883.32 618626.47 N 70 21 23.176 W 149 2 11.676 2641.35 37.93 343.54 2451.57 2515.82 449.75 565.97 471.15 348.01 -317.60 3.39 5980937.79 618606.85 N 70 21 23.715 W 149 2 12.225 2737.32 40.82 347.09 2525.76 2590.01 509.60 626.83 525.76 406.89 -332.97 3.82 5980996.41 618590.54 N 70 21 24.294 W 149 2 12.674 2834.00 44.29 349.11 2596.97 2661.22 573.24 692.20 584.56 470.86 -346.41 3.86 5981060.16 618576.09 N 70 21 24.923 W 149 2 13.067 2929.79 48.27 348.08 2663.16 2727.41 640.51 761.42 647.99 538.70 -360.12 4.23 5981127.77 618561.31 N 70 21 25.590 W 149 2 13.468 3025.62 52.61 347.16 2724.18 2788.43 712.58 835.28 717.28 610.84 -375.98 4.59 5981199.64 618544.31 N 70 21 26.299 W 149 2 13.931 3121.73 56.59 347.01 2779.84 2844.09 789.15 913.61 791.87 687.19 -393.48 4.14 5981275.69 618525.60 N 70 21 27.050 W 149 2 14.443 3215.11 56.21 346.89 2831.51 2895.76 865.23 991.39 866.64 762.95 -411.05 0.42 5981351.17 618506.84 N 70 21 27.795 W 149 2 14.957 3312.60 57.35 346.96 2884.92 2949.17 945.01 1072.94 945.57 842.40 -429.50 1.17 5981430.30 618487.13 N 70 21 28.577 W 149 2 15.497 3407.74 56.76 346.62 2936.66 3000.91 1023.15 1152.78 1023.28 920.12 -447.74 0.69 5981507.72 618467.65 N 70 21 29.341 W 149 2 16.030 3503.23 58.05 346.96 2988.10 3052.35 1101.89 1233.23 1101.89 998.44 -466.12 1.38 5981585.73 618448.03 N 70 21 30.111 W 149 2 16.568 3599.06 56.73 346.43 3039.75 3104.00 1180.92 1313.95 1181.04 1077.00 -484.70 1.45 5981663.98 618428.22 N 70 21 30.884 W 149 2 17.111 3753.15 56,73 346.14 3124.28 3188.53 1307.24 1442.79 1307.92 1202.16 -515.24 0.16 5981788.62 618395.69 N 70 21 32.115 W 149 2 18.004 3850.14 58.63 344.67 3176.13 3240.38 1387.84 1524.75 1389.01 1281.47 -535.90 2.34 5981867.59 618373.77 N 70 21 32.895 W 149 2 18.608 3940.07 56.73 343.52 3224.21 3288.46 1462.86 1600.74 1464.50 1354.55 -556.72 2.37 5981940.33 618351.80 N 70 21 33.614 W 149 2 17 4041.51 57,32 343.24 3279.42 3343.67 1547.04 1685.84 1549.20 1436.10 -581.06 0.63 5982021.47 618326.17 N 70 21 34.416 W 149 29 4137.82 55.75 343.57 3332.53 3396.78 1626.51 1766.18 1629.19 1513.09 -604.01 1.66 5982098.08 618302.00 N 70 21 35.173 W 149 2 2.00 4239.59 55.12 343.37 3390.27 3454.52 1709.39 1849.98 1712.67 1593.43 -627.85 0.64 5982178.03 618276.89 N 70 21 35.963 W 149 2 21.297 4336.00 55.34 343.00 3445.25 3509.50 1787.77 1929.18 1791.61 1669.24 -650.76 0.39 5982253.46 618252.78 N 70 21 36.709 W 149 2 21.967 4431.67 55.86 342.64 3499.30 3563.55 1865.97 2008.12 1870.35 1744.66 -674.08 0.63 5982328.49 618228.27 N 70 21 37.450 W f 49 2 22.649 4527.17 55.68 342.74 3553.02 3617.27 1944.20 2087.08 1949.14 1820.04 -697.58 0.21 5982403.48 618203.59 N 70 21 38.192 W 149 2 23.337 4622.73 53.35 344.12 3608.49 3672.74 2021.16 2164.88 2026.73 1894.61 -719.78 2.71 5982477.68 618180.21 N 70 21 38.925 W 149 2 23.986 4718.75 53.53 343.18 3665.69 3729.94 2097.40 2242.01 2103.63 1968.61 -741.49 0.81 5982551.32 618157.32 N 70 21 39.653 W 149 2 24.621 4814.00 55.69 344.25 3720.85 3785.10 2174.13 2319.65 2181.05 2043.15 -763.25 2.45 5982625.50 618134.38 N 70 21 40.386 W 149 2 25.258 4909.67 54.87 344.63 3775.34 3839.59 2251.69 2398.29 2259.41 2118.90 -784.35 0.92 5982700.90 618112.09 N 70 21 41.131 W 149 2 25.875 5005.57 56.47 343.74 3829.42 3893.67 2329.86 2477.48 2338.36 2195.09 -805.93 1.84 5982776.73 618089.30 N 70 21 41.880 W 149 2 26.506 5100.25 56.74 343.76 3881.53 3945.78 2407.97 2556.53 2417.23 2270.98 •828.05 0.29 5982852.25 618065.98 N 70 21 42.626 W 149 2 27.153 5196.07 55.02 344.88 3935.28 3999.53 2486.24 2635.85 2496.33 2347.35 -849.50 2.04 5982928.26 618043.32 N 70 21 43.377 W 149 2 27.780 SurveyEditor Ver SP 1.0 Bld( doc40x_56) S-122\S-122\S-122P61\5-122P61 Generated 9/19/2005 f 1:58 AM Page 2 of 4 Measured Vertical Along Hole Comments Inclination Azimuth Sub-Sea ND ND Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft it k ft ft ft de 100 ft ftUS ftUS 5Ly1. yiS 5b.1tS :S4ti .Ll :i`Ji3y .4/ 4U53 ./1 15b4 .U1 5387. 00 57 .99 346 .00 4041 .10 4105 .35 2642 .28 5482. 93 58 .10 346 .33 4091 .87 4156 .12 2722 .11 5578. 41 58. 15 346 .17 4142 .29 4206 .54 2801 .62 5674. 01 57 .80 346 .96 4192 .99 4257 .24 2881 .02 5768. 78 57 .50 346 .99 4243 .70 4307 .95 2959 .32 5863. 88 56. 93 347 .26 4295 .19 4359 .44 3037 .47 5959. 54 57. 71 345. 07 4346. 85 4411. 10 3116. 44 6056. 21 57. 69 342 .53 4398 .51 4462 .76 3197 ,17 6152. 03 57. 99 342 .96 4449 .51 4513 .76 3277 .54 6247. 99 57. 75 343. 61 4500. 55 4564. 80 3357. 95 6341. 49 58. 20 343. 89 4550. 13 4614. 38 3436. 28 6438. 88 57. 50 343 .34 4601. 96 4666 .21 3517. 80 6534. 49 58. 21 341. 51 4652. 83 4717. 08 3598. 06 6631. 65 56. 35 340. 49 4705. 35 4769. 60 3679. 34 6725. 69 55. 29 339. 61 4758. 18 4822 .43 3756. 82 6821. 40 56. 39 339 .93 4811. 92 4876. 17 3835. 74 6916. 97 55. 99 340. 16 4865. 10 4929. 35 3914. 83 7013. 59 55. 96 339. 95 4919. 16 4983. 41 3994. 59 7109. 04 55. 85 339. 98 4972. 67 5036. 92 4073. 33 7204. 60 56. 13 340. 11 5026. 12 5090. 37 4152. 24 7300. 13 55. 13 342. 26 5080. 05 5144. 30 4230. 61 7396. 28 54. 98 341. 89 5135. 12 5199. 37 4308. 82 7492. 00 54. 69 342. 49 5190. 25 5254. 50 4386. 44 7588. 00 54. 88 342. 28 5245. 61 5309. 86 4464. 22 7683. 71 54. 68 342. 44 5300. 81 5365. 06 4541. 75 7778. 67 54. 87 342. 01 5355. 58 5419. 83 4618. 70 7874. 27 56. 76 341. 68 5409. 29 5473. 54 4697. 21 7969. 63 57. 27 341. 59 5461. 21 5525. 46 4776. 65 8064. 67 56. 94 341. 15 5512. 83 5577. 08 4855. 95 8160. 40 57. 13 342. 34 5564. 92 5629. 17 4935. 71 8256. 27 56. 63 341. 90 5617. 30 5681. 55 5015. 37 8351. 81 56. 38 341. 80 5670. 02 5734. 27 5094. 47 8447. 56 57. 52 343. 20 5722. 24 5786. 49 5174. 02 8542. 87 57. 27 343. 33 5773. 60 5837. 85 5253. 47 8637. 10 56. 95 343. 74 5824. 77 5889. 02 5331. 71 8732. 43 56. 65 343. 09 5876. 97 594 i . 22 5410. 61 8828. 78 56. 35 342. 99 5930. 15 5994. 40 5490. 15 8925. 20 55. 53 342. 89 5984. 15 6048. 40 5569. 26 9020. 82 57. 12 343. 57 6037. 17 6101. 42 5648. 00 9116. 04 56. 79 343. 95 6089. 09 6153. 34 5726. 87 1/14.ykf 15/5.1"1 14"L:i.y/ -tf(iy.15 2794,75 2654.48 2501.40 -888.40 2876.14 2735.48 2580.44 -907.87 2957.22 2816.18 2659.19 -927.14 3038.27 2896.83 2738.03 -945.97 3118.33 2976.46 2816.03 -964.01 3198.28 3055.98 2893.97 -981.83 3278.80 3136.21 2972.14 -1001.09 3360.50 3217.84 3050.60 -1023.88 3441.62 3298.93 3128.06 -1047.94 3522.89 3380.16 3205.89 -1071.31 3602.16 3459.37 3282.00 -1093.50 3684.61 3541.77 3361.10 -1116.75 3765.56 3622.71 3438.27 -1141.20 3847.30 3704.44 3515.56 -1167.81 3925.10 3782.21 3588.68 -1194.35 4004.29 3861.37 3663.00 -1221.73 4083.70 3940.75 3737.64 -1248.83 4163.78 4020.80 3812.91 -1276.15 4242.82 4099.82 3887.17 -1303.23 4322.03 4179.00 3961.63 -1330.26 4400.88 4257.85 4036.25 -1355.70 4479.70 4336.66 4111.24 -1379.95 4557.95 4414.90 4185.74 -1403.89 4636.38 4493.32 4260.50 -1427.62 4714.57 4571.50 4335.01 -1451.32 4792.14 4649.07 4408.88 -1475.00 4871.22 4728.14 4484.02 -1499.64 4951.21 4808.13 4559.93 -1524.84 5031.01 4887.93 4635.55 -1550.34 5111.33 4968.25 4711.83 -1575.49 5191.62 5048.54 4788.24 -1600.14 5271.29 5128.21 4863.95 -1624.96 5351.55 5208.45 4940.49 -1649.09 5431.84 5288.71 5017.38 -1672.21 5510.96 5367.79 5093.26 -1694.64 5590.73 5447.51 5169.71 -1717.40 5671.08 5527.84 5246.56 -1740.84 5750.96 5607.69 5322.93 -1764.27 5830.53 5687.24 5399.12 -1787.23 5910.35 5767.00 5475.75 -1809.55 1.(iES SytS;iUU4.5ti (i1tfUCL.:i/ IV /U 11 44.11 W 14y1L2S.:i5t1 1.91 5983081.67 61$001.98 N 70 21 44.892 W 149 2 28.919 0.31 5983160.38 617981.27 N 70 21 45.670 W 149 2 29.488 0.15 5983238.81 617960.75 N 70 21 46.444 W 149 2 30.052 0.79 5983317.33 617940.67 N 70 21 47.220 W 149 2 30.603 0.32 5983395.03 617921.39 N 70 21 47.987 W 149 2 31.131 0.65 5983472.67 617902.35 N 70 21 48.753 W 149 2 31.652 2.09 5983550.52 617881.85 N 70 21 49.522 W 149 2 32.216 2.22 5983628.60 617857.82 N 70 21 50.294 W 149 2 32.882 0.49 5983705.66 617832.53 N 70 21 51.055 W 149 2 33.586 0.63 5983783.10 617807.93 N 70 21 51.821 W 149 270 0.54 5983858.84 617784.54 N 70 21 52.569 W 149 2 34.919 0.86 5983937.56 617760.03 N 70 21 53.347 W 149 2 35.600 1.78 5984014.32 617734.37 N 70 21 54.106 W 149 2 36.315 2.11 5984091.17 617706.54 N 70 21 54.866 W 149 2 37.093 1.37 5984163.86 617678.85 N 70 21 55.585 W 149 2 37.870 1.18 5984237.72 617650.29 N 70 21 56.316 W 149 2 38.671 0.46 5984311.92 617622.01 N 70 21 57.050 W 149 2 39.464 0.18 5984386.74 617593.50 N 70 21 57.790 W 149 2 40.263 0.12 5984460.56 617565.25 N 70 21 58.521 W 149 2 41.056 0.31 5984534.57 617537.04 N 70 21 59.253 W 149 2 41.847 2.13 5984608.78 617510.42 N 70 21 59.987 W 149 2 42.591 0.35 5984683.36 617484.98 N 70 22 0.724 W 149 2 43.301 0.60 5984757.47 617459.87 N 70 22 1.457 W 149 2 44.002 0.27 5984831.83 617434.95 N 70 22 2.192 W 149 2 44.696 0.25 5984905.95 617410.08 N 70 22 2.925 W 149 2 45.390 0.42 5984979.43 617385.23 N 70 22 3.651 W 149 2 46.083 2.00 5985054.16 617359.40 N 70 22 4.390 W 149 24 0.54 5985129.66 617333.00 N 70 22 5.137 W 149 2 2 0.52 5985204.86 617306.31 N 70 22 5.880 W .149 2 4 .288 1.06 5985280.72 617279.95 N 70 22 6.631 W 149 2 49.024 0.65 5985356.73 617254.09 N 70 22 7.382 W 149 2 49.745 0.28 5985432.03 617228.08 N 70 22 8.127 W 149 2 50.472 1.71 5985508.17 617202.74 N 70 22 8.879 W 149 2 51.178 0.29 5985584.67 617178.40 N 70 22 9.635 W 149 2 51.855 0.50 5985660.18 617154.78 N 70 22 10.382 W 149 2 52.511 0.65 5985736.25 617130.80 N 70 22 i 1.133 W 149 2 53.178 0.32 5985812.72 617106.15 N 70 22 11.889 W 149 2 53.864 0.85 5985888.69 617081.51 N 70 22 12.640 W 149 2 54.550 1.76 5985964.50 617057.35 N 70 22 13.389 W 149 2 55.222 0.48 5986040.76 617033.82 N 70 22 14.143 W 149 2 55.876 SurveyEditor Ver SP 1.0 Bld( doc40x_56) S-122\S-122\S-122PB1\S-122PB1 Generated 9/1 9/2005 1 1:58 AM Page 3 of 4 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Fasting Latitude Longitude Depth Section Departure ft de de (t ft ft it ft ft ft de 100 ft ftUS ftUS 9212.77 9306.96 9400.78 9498.81 9594.62 9690.03 9784.92 9881.09 9976.47 10072.32 10167.70 10263.24 10359.01 10453.96 10549.72 56.08 56.07 55.22 54.64 57.28 58.58 59.26 58.68 59.86 61.12 60.66 60.93 61.39 61.35 61.42 343.88 345.15 345.05 344.41 339.74 337.19 337.50 337.49 335.70 335.21 335.04 335.25 335.91 334.78 334.56 6142.57 6195.14 6248.09 6304.41 6358.06 6408.72 6457.71 6507.28 6556.02 6603.23 6649.64 6696.25 6742.45 6787.95 6833.81 6206.82 5806.49 5990.95 5847.54 5553.19 -1831.88 0.74 5986117.84 617010.26 N 70 22 14 .905 W 149 2 56.529 6259.39 5883.56 6069.10 5925.61 5628.51 -1852.75 1.12 5986192.81 616988.20 N 70 22 15 .645 W 149 2 57.140 6312.34 5959.80 6146.55 6002.93 5703.36 -1872.66 0.91 5986267.32 616967.10 N 70 2216 .381 W 149 2 57.724 6368.66 6038.86 6226.79 6083.06 5780.76 -1893.79 0.80 5986344.37 616944.75 N 70 22 17 .143 W 149 2 58.342 6422.31 6117.60 6306.16 6162.41 5856.24 -1918.26 4.89 5986419.45 616919.09 N 70 22 17 .885 W 149 2 59.059 6472.97 6198.29 6387.00 6243.11 .5931.43 -1947.95 2.64 5986494.15 6521.96 6279.49 6468.27 6324.13 6006.43 -1979.25 0.77 5986568.64 6571.53 6361.81 6550.68 6406.31 6082.56 -2010.79 0.60 5986644.25 6620.27 6443.76 6632.66 6487.97 6157.79 -2043.36 2.03 5986718.95 6667.48 6527.17 6716.08 6570.90 6233.67 -2078.02 1.39 5986794.26 6713.89 6610.50 6799.41 6653.72 6309.27 -2113.07 0.51 5986869.29 6760.50 6693.90 6882.80 6736.61 6384.94 -2148.12 0.34 5986944.39 6806.70 6777.78 6966.69 6820.07 6461.33 -2182.80 0.77 5987020.21 6852.20 6861.12 7050.03 6902.96 6537.07 -2217.57 1.05 5987095.38 6898.06 6945.18 7134.10 6986.47 6613.05 -2253.53 0.21 5987170.77 10644.34 61.40 334.60 6879.09 6943.34 7028.26 7217.18 7069.01 6688.09 -2289.20 0.04 5987245.23 Last MWD+IFR+MS 10668.78 61.06 334.17 6890.85 6955.10 7049.69 7238.60 7090.29 6707.41 -2298.46 2.08 5987264.40 TD (Projected) 10731.00 61.06 334.17 6920.96 6985.21 7104.13 7293.05 7144.35 6756.42 -2322.18 0.00 5987313.02 Survey Type: Definitive Survey NOTES: GYD GC SS - (Gyrodata -gyro single shots --Gyrodata gyro orientation surveys. Not to be run above 70 degrees inclination. ) MWD +IFR + MS - (In-field referenced MWD with mull-station analysis and correction applied in post-processing. Assumes a BHA sag correction is applied to enhance inclination accuracy. ) Legal Description: Northing (Y) [ftUS] Fasting (X) [ftUS] Surface : 4391 FSL 4500 FEL S35 T12N R12E UM 5980594.90 618929.91 BHL : 587 FSL 1533 FEL S22 T12N R12E UM 5987313.02 616500.96 W 149 2 59.928 W 149 3 0.844 W 149 3 1.767 W 149 3 2.721 W 149 3 3.735 W 149 ~1 W 149 3 5.788 W 149 3 6.803 W 149 3 7.821 W 149 3 8.874 W 149 3 9.918 W 149 3 10.189 W 149 3 10.884 616888.21 616855.73 616822.98 616789.22 616753.37 616717.13 616680.88 616645.00 616609.04 616571.87 616535.03 616525.46 616500.96 N 70 22 18.624 N 70 22 19.362 N 70 22 20.110 N 70 22 20.850 N 70 22 21.596 N 70 22 22.340 N 70 22 23.084 N 70 22 23.835 N 70 22 24.580 N 70 22 25.327 N 70 22 26.065 N 70 22 26.255 N 70 22 26.737 SurveyEditor Ver SP 1.0 Bld( doc40x_56) S-122\S-122\S-122P61\S-122PB1 Generated 9/19/2005 11:58 AM Page 4 of 4 S-122PB2 Surve y Report Report Date: 15-Aug-05 Survey /DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 334.950° Field: Prudhoe Bay Unit - WOA Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure /Slot: S-PAD / S-122 TVD Reference Datum: Rotary Table Well: S-122 TVD Reference Elevation: 64.25 ft relative to MSL Borehole: S•122PB2 Sea Bed I Ground Level Elevation: 35.70 ft relative to MSL UWIIAPI#: 500292326571 Magnetic Declination: 24.687° Survey Name /Date: S•122P82 /August 15, 2005 Total Field Strength: 57588.860 nT Tort /AHD / DDI / ERD ratio: 224.561 ° / 7470.24 ft / 6.429 / 1.103 Magnetic Dip: 80.882° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: July 29, 2005 Location LaVlong: N 70 21 20.292, W 149 2 2.940 Magnetic Declination Model: BGGM 2005 Location Grid WE Y/X: N 5980594.899 ftUS, E 618929.906 ftUS North Reference: True North Grid Convergence Angle: +0.90964481 ° Totai Corr Mag North -> 7rue North: +24.687° Grid Scale Factor: 0.99991607 Local Coordinates Referenced To: Well Head Measured Vertical Along Hole Comments Inclination Azimuth Sub-Sea TVD TVp Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft d de ft ft fi ft fl ft ft de 100 ft ftUS ftUS H I t U.OU U.UU U.VU -64.Zb U.UU U.UU UAO 0.UU UAU U.OU U.OU 59tiUb94.9U 61 tt9L9.91 N lU 21 ZU.292 W 149 2 2.940 First GYD GC SS 76.00 0.46 357.51 11.75 76.00 0.28 0.31 0.31 0.30 -0.01 0.61 5980595.20 618929.89 N 70 21 20.295 W 149 2 2.940 100.00 0.35 24.42 35.75 100.00 0.42 0.47 0.47 0.47 0.01 0.90 5980595.37 618929.91 N 70 21 20.297 W 149 2 2.940 198.00 0.14 17.76 133.75 198.00 0.70 0.89 0.87 0.85 0.17 0.22 5980595.76 618930.07 N 70 21 20.300 W 149 2 2.935 250.00 0.82 128.20 185.75 250.00 0.42 1.26 0.84 0.68 0.48 1.69 5980595.59 618930.38 N 70 21 20.299 W 149 2 2.926 300.00 1.38 131.84 235.74 299.99 -0.46 2.22 1.22 0.06 1.21 1.13 5980594.98 618931.12 N 70 21 20.293 W 149 2 2.904 349.00 2.46 116.46 284.71 348.96 -1.82 3.85 2.72 -0.80 2.60 2.42 5980594.14 618932.51 N 70 21 20.284 W 149 2 2.864 438.00 4.60 109.24 373.53 437.78 -5.81 9.33 8.18 -2.83 7.68 2.45 5980592.19 618937.63 N 70 21 20.264 W 149 2 2.716 500.00 4.50 121.68 435.34 499.59 -9.58 14.23 13.06 -4.92 12.09 1.60 5980590.17 618942.07 N 70 21 20.244 W 149 2 2.586 550.00 3.76 126.03 485.21 549.46 -12.66 17.83 16.60 -6.92 15.09 1.61 5980588.22 618945.10 N 70 21 20.224 W 149 2 2.499 650.00 2.62 149.64 585.06 649.31 -17.80 23.31 21.77 -10.82 18.90 1.72 5980584.38 618948.97 N 70 21 20.186 W 149 ~8 708.00 2.61 158.31 643.00 707.25 -20.44 25.96 24.00 -13.19 20.05 0.68 5980582.03 618950.16 N 70 21 20.162 W 149 2 4 800.00 2.20 159.68 734.92 799.17 -24.29 29.82 27.23 -16.79 21.44 0.45 5980578.45 618951.61 N 70 21 20.127 W 149 2 2.313 893.00 2.38 160.82 827.84 892.09 -27.99 33.53 30.44 -20.29 22.70 0.20 5980574.97 618952.92 N 70 21 20.092 W 149 2 2.277 925.00 2.29 157.96 859.82 924.07 -29.29 34.84 31.60 -21.51 23.15 0.46 5980573.76 618953.40 N 70 21 20.080 W 149 2 2.263 1000.00 1.65 172.65 934.77 999.02 -31.82 37.40 33.82 -23.97 23.85 1.08 5980571.31 618954.14 N 70 21 20.056 W 149 2 2.243 1079.00 1.59 290.46 1013.76 1078.01 -32.12 38.96 33.74 -24.72 22.97 3.51 5980570.55 618953.27 N 70 21 20.049 W 149 2 2.268 1100.00 1.85 294.16 1034.75 1099.00 -31.65 39.59 33.17 -24.48 22.39 1.35 5980570.78 618952.68 N 70 21 20.051 W 149 2 2.285 1200.00 2.59 300.25 1134.67 1198.92 -28.57 43.46 29.56 -22.68 18.97 0.78 5980572.53 618949.23 N 70 21 20.069 W 149 2 2.386 1250.00 2.69 299.72 1184.62 f 248.87 -26.69 45.77 27,41 -21.53 16.97 0.21 5980573.65 618947.21 N 70 21 20.080 W 149 2 2.444 1300.00 3.79 296.81 1234.54 1298.79 -24.43 48.59 24.85 -20.20 14.48 2.22 5980574.93 618944.70 N 70 21 20.093 W 149 2 2.517 1350.00 5.35 295.83 1284.38 1348.63 -21.32 52.57 21.42 -18.44 10.90 3.12 5980576.64 618941.10 N 70 21 20.111 W 149 2 2.621 1400.00 6.74 295.32 1334.10 1398.35 -17.25 57.84 17.30 -16.17 6.15 2.78 5980578.83 618936.31 N 70 21 20.133 W 149 2 2.760 1450.00 9.86 294.86 1383.57 1447.82 -11.72 65.06 13.12 -13.11 -0.39 6.24 5980581.78 618929.73 N 70 21 20.163 W 149 2 2.951 1500.00 11.78 293.85 1432.68 1496.93 -4.59 74.44 12.86 -9.25 -8.94 3.86 5980585.51 618921.12 N 70 21 20.201 W 149 2 3.201 SurveyEditor Ver SP 1.0 Bld( doc40x_56 ) S-122\S-122\S-122P 62\S-122PB2 Generated 9/19/2005 11:59 AM Page 1 of 4 Comments Measured Inclination Azimuth Sub-Sea TVD ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft h ft de 700 ft ftUS ftUS Last GYD GC SS 1550.00 First MWD+IFR+MS 1591.98 1686.98 1782.38 1877.83 1972.81 2068.14 2164.41 2260.49 2355.35 2451.14 2545.77 2641.35 2737.32 2834.00 12.79 294.19 1481.53 1545.78 13.70 289.72 1522.39 1586.64 17.48 286.46 1613.88 1678.13 19.02 296.93 1704.51 1768.76 22.05 306.79 1793.91 1858.16 23.31 311.47 1881.55 1945.80 26.24 315.83 1968.10 2032.35 28.11 320.93 2053.76 2118.01 31.38 323.87 2137.17 2201.42 31.69 328.13 2218.03 2282.28 34.18 332.79 2298.43 2362.68 36.71 338.59 2375.54 2439.79 37:93 343.54 2451.57 2515.82 40.82 347.09 2525.76 2590.01 44.29 349.11 2596.97 2661.22 3.45 85.08 19.29 -4.92 -18.66 2.03 5980589.69 618911.33 N 70 21 20.244 W 149 2 3.485 10.47 94.69 27.61 -1.33 -27.57 3.26 5980593.13 618902.36 N 70 21 20.279 W 149 2 3.746 27.85 120.21 52.26 6.51 -51.86 4.08 5980600.58 618877.96 N 70 21 20.356 W 149 2 4.456 49.60 150.01 81.39 17.61 -79.47 3.79 5980611.24 618850.18 N 70 21 20.465 W 149 2 5.263 77.67 183.42 113.36 35.39 -107.70 4.81 5980628.58 618821.67 N 70 21 20.640 W 149 2 6.088 110.62 220. 03 148.11 58 .52 -136 .06 2.32 5980651. 25 147.85 259. 95 186 .03 86 .13 -164 .88 3.62 5980678. 40 189.97 303. 90 227 .61 119 .01 -194 .01 3.10 5980710. 81 236.49 351. 55 272 .64 156 .80 -223 .04 3.73 5980748. 13 285.47 401. 15 319 .46 197 .92 -250 .76 2.37 5980788. 79 337.36 453. 20 368 .15 243 .23 -276 .36 3.71 5980833. 69 392.17 508. 05 418 .67 293 .22 -298 .85 4.45 5980883. 32 449.75 565. 97 471 .15 348 .01 -317 .60 3.39 5980937. 79 509.60 626. 83 525 .76 406 .89 -332 .97 3.82 5980996. 41 573.24 692. 20 584 .56 470 .86 -346 .41 3.86 5981060. 16 2929.79 48. 27 348.08 2663.16 2727.41 640.51 761. 42 647 .99 538.70 -360.12 4.23 5981127. 77 3025.62 52. 61 347.16 2724.18 2788.43 712.58 835. 28 717 .28 610.84 -375 .98 4.59 5981199. 64 3121.73 56. 59 347.01 2779.84 2844.09 789.15 913. 61 791 .87 687.19 -393 .48 4.14 5981275. 69 3215.11 56. 21 346.89 2831.51 2895.76 865.23 991. 39 866 .64 762.95 -411 .05 0.42 5981351. 17 3312.60 57. 35 346.96 2884.92 2949.17 945.01 1072. 94 945 .57 842.40 -429 .50 1.17 5981430. 30 3407.74 56. 76 346.62 2936.66 3000.91 1023.15 1152. 78 1023 .28 920.12 -447 .74 0.69 5981507. 72 3503.23 58. 05 346.96 2988.10 3052.35 1101.89 1233. 23 1101 .89 998.44 -466 .12 1.38 5981585. 73 3599.06 56. 73 346.43 3039.75 3104.00 1180,92 1313. 95 1181 .04 1077.00 -484 .70 1.45 5981663. 98 3753.15 56. 73 346.14 3124.28 3188.53 1307.24 1442. 79 1307 .92 1202.16 -515 .24 0.16 5981788. 62 3850.14 58. 63 344.67 3176.13 3240.38 1387,84 1524. 74 1389 .01 1281.47 -535 .90 2.34 5981867. 59 618792.95 618763.69 618734.04 618704.43 618676.06 618649.75 618626.47 618606.85 618590.54 618576.09 618561.31 618544.31 618525.60 618506.84 618487.13 618467.65 618448.03 618428.22 618395.69 618373.77 N 70 21 20.868 N 70 21 21.139 N 70 21 21.462 N 70 21 21.834 N 70 21 22.238 N 70 21 22.684 N 70 21 23.176 N 70 21 23.715 N 70 21 24.294 N 70 21 24.923 N 70 21 25.590 N 70 21 26.299 N 70 21 27.050 N 70 21 27.795 N 70 21 28.577 N 70 21 29.341 N 70 21 30.111 N 70 21 30.884 N 7021 32.115 N 70 21 32.895 W 149 2 6.917 W 149 2 7.760 W 149 2 8.612 W 149 2 9.460 W 149 2 10.270 W 149 2~ 9 W 149 2 11.676 W 149 2 12.225 W 149 2 12.674 W 149 2 13.067 W 149 2 13.468 W 149 2 13.931 W 149 2 14.443 W 149 2 14.957 W 149 2 15.497 W 149 2 16.030 W 149 2 16.568 W 149 2 17.111 W i 49 2 18.004 W 149 2 18.608 3940.07 56.73 343.52 3224.21 3288.46 1462.86 1600.74 1464.50 1354.55 -556.72 2.37 5981940.33 618351.80 N 70 21 33.614 W 149 2 19.217 4041.51 57.32 343.24 3279.42 3343.67 1547.04 1685.84 1549.20 1436.10 -581.06 0.63 5982021.47 618326.17 N 70 21 34.416 W 149 2 19.929 4137.82 55.75 343.57 3332.53 3396.78 1626.51 1766.18 1629.19 1513.09 -604.01 1.66 5982098.08 618302.00 N 70 21 35.173 W 149 20 4239.59 55.12 343.37 3390.27 3454.52 1709.39 1849.98 1712.67 1593.43 -627.85 0.64 5982178.03 618276.89 N 70 21 35.963 W 149 2 7 4336.00 55.34 343.00 3445.25 3509.50 1787.77 1929.18 1791.61 1669.24 -650.76 0.39 5982253.46 618252.78 N 70 21 36.709 W 149 2 2 .967 4431.67 55.86 342.64 3499.30 3563.55 1865.97 2008.12 1870.35 1744.66 -674.08 0.63 5982328.49 618228.27 N 70 21 37.450 W 149 2 22.649 4527.17 55.68 342.74 3553.02 3617.27 1944.20 2087.08 1949.14 1820.04 -697.58 0.21 5982403.48 618203.59 N 70 21 38.192 W 149 2 23.337 4622.73 53.35 344.12 3608.49 3672.74 2021.16 2164.88 2026:73 1894.61 -719.78 2.71 5982477.68 618180.21 N 70 21 38.925 W 149 2 23.986 4718.75 53.53 343.18 3665.69 3729.94 2097.40 2242.01 2103.63 1968.61 -741.49 0.81 5982551.32 618157.32 N 70 21 39.653 W 149 2 24.621 4814.00 55.69 344.25 3720.85 3785.10 2174.13 2319.65 2181.05 2043.15 -763.25 2.45 5982625.50 618134.38 N 70 21 40.386 W 149 2 25.258 4909.67 54.87 344.63 3775.34 3839.59 2251.69 2398.29 2259.41 2118.90 -784.35 0.92 5982700.90 618112.09 N 70 21 41.131 W 149 2 25.875 5005.57 56.47 343.74 3829.42 3893.67 2329.86 2477.48 2338.36 2195.09 -805.93 1.84 .5982776.73 618089.30 N 70 21 41.880 W 149 2 26.506 5100.25 56.74 343.76 3881.53 3945.78 2407.97 2556.53 2417.23 2270.98 -828.05 0.29 5982852.25 618065.98 N 70 21 42.626 W 149 2 27.153 5196.07 55.02 344.88 3935.28 3999.53 2486.24 2635.85 2496.33 2347.35 -849.50 2.04 5982928.26 618043.32 N 70 21 43.377 W 149 2 27.780 5291.98 56.18 346.21 3989.47 4053.72 2564.02 2714.98 2575.12 2423.97 -869.25 1.66 5983004.56 618022.37 N 70 21 44.131 W 149 2 28.358 5387.00 57.99 346.00 4041.10 4105.35 2642.28 2794.75 2654.48 2501.40 -888.40 1.91 5983081.67 618001.98 N 70 21 44.892 W 149 2 28.919 SurveyEditor Ver SP 1.0 Bld( doc40x_56) S-122\S-122\S-122PB2\S-122P62 Generated 9/1 9/2005 1 1:59 AM Page 2 of 4 Comments Measured Inclination Azimuth Sub-Sea 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 5481.93 btf.lU :14(1.3:1 4Uyl.tt/ 5578.41 58.15 346.17 4142.29 5674.01 57.80 346.96 4192.99 5768.78 57.50 346.99 4243.70 5863.88 56.93 347.26 4295.19 5959.54 57.71 345.07 4346.85 6056.21 57.69 342.53 4398.51 6152.03 57.99 342.96 4449.51 6247.99 57.75 343.61 4500.55 6341.49 58.20 343.89 4550.13 6438.88 57.50 343.34 4601.96 6534.49 58.21 341.51 4652.83 6631.65 56.35 340.49 4705.35 6725.69 55.29 339.61 4758.18 6821.40 56.39 339.93 4811.92 6916.97 55.99 340.16 4865.10 7013.59 55.96 339.95 4919.16 7109.04 55.85 339.98 4972.67 7204.60 56.13 340.11 5026.12 7300.13 7396.28 7492.00 7588.00 7683.71 7778.67 7874.27 7969.63 8064.67 8160.40 8256.27 8351.81 8447.56 8542.87 8637.10 8732.43 8828.78 8925.20 9020.82 9116.04 55.13 54.98 54.69 54.88 54.68 54.87 56.76 57.27 56.94 57.13 56.63 56.38 57.52 57.27 56.95 342.26 341.89 342.49 342.28 342.44 342.01 341.68 341.59 341.15 342.34 341.90 341.80 343.20 343.33 343.74 5080.05 5135.12 5190.25 5245.61 5300.81 56.65 343.09 56.35 342.99 55.53 342.89 57.12 343.57 56.79 343.95 4156.11L/L1.11L8/6.14 2/35.48 4206.54 2801.62 2957.22 2816.18 4257.24 2881.02 3038.27 2896.83 4307.95 2959.32 3118.33 2976.46 4359.44 4411.10 4462.76 4513.76 4564.80 4614.38 4666.21 4717.08 4769.60 4822.43 4876.17 4929.35 4983.41 5036.92 5090.37 5144.30 5199.37 5254.50 5309.86 5365.06 3037.47 3116.45 3197.17 3277.54 3357.95 3436.28 3517.80 3598.06 3679.34 3756.82 3835.74 3914.83 3994.59 4073.33 4152.24 4230.61 4308.82 4386.44 4464.22 4541.75 3198.28 3278.80 3360.50 3441.62 3522.89 3602.16 3684.61 3765.56 3847.30 3925.10 4004.29 4083.70 4163.78 4242.82 4322.03 4400.88 4479.70 4557.95 4636.38 4714.57 3055.98 3136.21 3217.84 3298.93 3380.16 3459.37 3541.77 3622.71 3704.44 3782.21 5015. 37 5191. 62 5048. 54 5094. 47 5271. 29 5128. 21 5174. 02 5351. 55 5208. 45 5253. 47 5431. 84 5288. 71 5331. 71 5510. 96 5367. 79 5410. 61 5590. 73 5447. 51 5490. 15 5671. 08 5527. 84 5569. 26 5750. 96 5607. 69 5648. 00 5830. 53 5687. 24 5726. 87 5910. 35 5767. 00 5806. 49 5990. 95 5847. 54 5883. 56 6069. 10 5925. 61 5959. 80 6146. 55 6002. 93 3861.37 3940.75 4020.80 4099.82 4179.00 4257.85 4336.66 4414.90 4493.32 4571.50 U.31 59831(iU.38 0.15 5983238.81 0.79 5983317.33 0.32 5983395.03 0.65 5983472.67 2.09 5983550.52 2.22 5983628.60 0.49 5983705.66 0.63 5983783.10 0.54 5983858.84 0.86 5983937.56 1.78 5984014.32 2.11 5984091.17 1.37 5984163.86 1.18 5984237.72 0.46 5984311.92 0.18 5984386.74 0.12 5984460.56 0.31 5984534.57 2.13 5984608.78 0.35 5984683.36 0.60 5984757.47 0.27 5984831.83 0.25 5984905.95 5355.58 5419.83 4618. 70 4792.14 4649.07 4408.88 -1475.00 0.42 5984979. 43 5409.29 5473.54 4697. 21 4871 .22 4728.14 4484.02 -1499.64 2.00 5985054. 16 5461.21 5525.46 4776. 65 4951 .21 4808.13 4559.93 -1524.84 0.54 5985129. 66 5512.83 5577.08 4855. 95 5031 .01 4887.93 4635.55 -1550.34 0.52 5985204. 86 5564.92 5629.17 4935. 71 5111 .33 4968.25 4711.83 -1575.49 1.06 5985280. 72 5617.30 5670.02 5722.24 5773.60 5824.77 5876.97 5930.15 5984.15 6037.17 6089.09 5681.55 5734.27 5786.49 5837.85 5889.02 5941.22 5994.40 6048.40 6101.42 6153.34 9212.77 56.08 343.88 6142.57 6206.82 9306.96 56.07 345.15 6195.14 6259.39 9400.78 55.22 345.05 6248.09 6312.34 SurveyEditor Ver SP 1.0 Bld( doc4Ox_56 ) 1S8U.44 -9U/.8/ 2659.19 -927.14 2738.03 -945.97 2816.03 -964.01 2893.97 -981.83 2972.14 -1001.09 3050.60 -1023.88 3128.06 -1047.94 3205.89 -1071.31 3282.00 -1093.50 3361.10 -1116.75 3438.27 -1141.20 3515.56 -1167.81 3588.68 -1194.35 3663.00 -1221.73 3737.64 -1248.83 3812.91 -1276.15 3887.17 -1303.23 3961.63 -1330.26 4036.25 -1355.70 4111.24 -1379.95 4185.74 -1403.89 4260.50 -1427.62 4335.01 -1451.32 4788.24 -1600.14 4863.95 -1624.96 4940.49 -1649.09 5017.38 -1672.21 5093.26 -1694.64 5169.71 -1717.40 5246.56 -1740.84 5322.93 -1764.27 5399.12 -1787.23 5475.75 -1809.55 5553.19 -1831.88 5628.51 -1852.75 5703.36 -1872.66 S-122\S-122\ S-122 P B2\S-122 P 62 0.65 5985356.73 0.28 5985432.03 1.71 5985508.17 0.29 5985584.67 0.50 5985660.18 0.65 5985736.25 0.32 5985812.72 0.85 5985888.69 1.76 5985964.50 0.48 5986040.76 0.74 5986117.84 1.12 5986192.81 0.91 5986267.32 61 /981.'1/ N /U 11 4b.6/U W 1491'19.488 617960.75 N 70 21 46.444 W 149 2 30.052 617940.67 N 70 21 47.220 W 149 2 30.603 617921.39 N 70 21 47.987 W 149 2 31.131 617902.35 N 70 21 48.753 W 149 2 31.652 617881.85 N 70 21 49.522 W 149 2 32.216 617857.82 N 70 21 50.294 W 149 2 32.882 617832.53 N 70 21 51.055 W 149 2 33.586 617807.93 N 70 21 51.821 W 149 2 34.270 617784.54 N 70 21 52.569 W 149 2 34.919 617760.03 N 70 21 53.347 W 149 200 617734.37 N 70 21 54.106 W 149 22 5 617706.54 N 70 21 54.866 W 149 2 37.093 617678.85 N 70 21 55.585 W 149 2 37.870 617650.29 N 70 21 56.316 W 149 2 38.671 617622.01 N 70 21 57.050 W 149 2 39.464 617593.50 N 70 21 57.790 W 149 2 40.263 617565.25 N 70 21 58.521 W 149 2 41.056 617537.04 N 70 21 59.253 W 149 2 41.847 617510.42 N 70 21 59.987 W 149 2 42.591 617484.98 N 70 22 0.724 W 149 2 43.301 617459.87 N 70 22 1.457 W 149 2 44.002 617434.95 N 70 22 2.192 W 149 2 44.696 617410.08 N 70 22 2.925 W 149 2 45.390 617385.23 617359.40 617333.00 617306.31 617279.95 617254.09 617228.08 617202.74 617178.40 617154.78 N 70 22 3.651 N 70 22 4.390 N 70 22 5.137 N 70 22 5.880 N 70 22 6.631 N 70 22 7.382 N 70 22 8.127 N 70 22 8.879 N 70 22 9.635 N 70 22 10.382 W 149 2 46.083 W 149 2 46.804 W 149 2 47.542 W 149 2 48.288 W 149 2 4 W 149 2 4745 W 149 2 50.472 W 149 2 51.178 W 149 2 51.855 W 149 2 52.511 617130.80 N 70 22 11.133 W 149 2 53.178 617106.15 N 70 22 11.889 W 149 2 53.864 617081.51 N 70 22 12.640 W 149 2 54.550 617057.35 N 70 22 13.389 W 149 2 55.222 617033.81 N 70 22 14.143 W 149 2 55.876 617010.26 N 70 2214.905 W 149 2 56.529 616988.20 N 70 22 15.645 W 149 2 57.140 616967.10 N 70 22 16.381 W 149 2 57.724 Generated 9/1 9/2005 1 1:59 AM Page 3 of 4 Measured Vertical Along Hole Comments Inclination Azimuth Sub-Sea ND ND 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 y4yti.t31 b4.ti4 ;144.41 ti~U4.41 (i:i(it1.(i(i (iU:itl.it(i ti"L'L(i./5 fiUti:i.Ufi 5/tiU./li -ltSy:1./y U.tiU bykS(i:144. :i/ (il(iy44./5 N /U LL 1 /.14:1 W 14yL btt.:142 9594.62 57.28 339.74 6358.06 6422.31 6117.60 6306.16 6162.41 5856.24 -1918.26 4.89 5986419. 45 616919.09 N 70 22 17.885 W 149 2 59.059 9690.03 58.58 337.19 6408.72 6472.97 6198.29 6387.00 6243.11 5931.43 -1947.95 2.64 5986494. 15 616888.21 N 70 2218.624 W 149 2 59.928 9784.92 59.26 337.50 6457.71 6521.96 6279.49 6468.27 6324.13 6006.43 -1979.25 0.77 5986568. 64 616855.73 N 70 22 19.362 W 149 3 0.844 9881.09 58.68 337.49 6507.28 6571.53 6361.81 6550.68 6406.31 6082.56 -2010.79 0.60 5986644. 25 616822.98 N 70 22 20.110 W 149 3 1.767 9976.47 59.86 335.70 6556.02 6620.27 6443.76 6632.66 6487.97 6157.79 -2043.36 2.03 5986718. 95 616789.22 N 70 22 20.850 W 149 3 2.721 10072.32 61.12 335.21 6603.23 6667.48 6527.17 6716.08 6570.90 6233.67 -2078.02 1.39 5986794. 26 616753.37 N 70 22 21.596 W 149 3 3.735 Tie-In Survey 10167.70 60.66 335.04 6649.64 6713.89 6610.50 6799.41 6653.72 6309.27 -2113.07 0.51 5986869. 29 616717.13 N 70 22 22.340 W 149 3 4.762 Top Window (Inc only) 10217.00 60.80 335.15 6673.74 6737.99 6653.51 6842.41 6696.46 6348.28 -2131.18 0.34 5986908. 00 616698.40 N 70 22 22.723 W 149 3 5.292 Base Window (Inc only) 10229.00 62.60 334.40 6679.43 6743.68 6664.07 6852.98 6706.95 6357.83 -2135.68 15.98 5986917. 48 616693.75 N 70 22 22.817 W 149 3 5.424 End Mill (Inc Only) 10243.00 62.60 334.40 6685.87 6750.12 6676.50 6865.41 6719.29 6369.04 -2141.05 0.00 5986928. 60 616688.20 N 70 22 22.928 W 149 j~81 Blind (Inc Only) 10268.64 69.85 334.40 6696.20 6760.45 6699.95 6888.86 6742.56 6390.19 -2151.19 28.28 5986949. 59 616677.74 N 70 22 23.136 W 1497 Blind (Inc Only) 10300.73 77.78 332.84 6705.14 6769.39 6730.73 6919.65 6773.07 6417.77 -2164.87 25.15 5986976. 94 616663.61 N 70 22 23.407 W 149 3 6.278 First MWD+IFR+MS 10332.34 85.77 332.90 6709.66 6773.91 6761.97 6950.91 6803.99 6445.59 -2179.13 25.28 5987004. 53 616648.92 N 70 22 23.680 W 149 3 6.695 10363.34 89.38 330.48 6710.97 6775.22 6792.89 6981.88 6834.52 6472.85 -2193.81 14.02 5987031. 55 616633.80 N 70 22 23.948 W 149 3 7.125 10395.10 91.54 329.81 6710.71 6774.96 6824.53 7013.63 6865.68 6500.39 -2209.62 7.12 5987058. 84 616617.56 N 70 22 24.219 W 149 3 7.588 10426.92 94.42 329.14 6709.06 6773.31 6856.16 7045.41 6896.79 6527.76 -2225.76 9.29 5987085. 95 616600.99 N 70 22 24.488 W 149 3 8.060 10458.49 96.56 328.24 6706.04 6770.29 6887.40 7076.83 6927.47 6554.61 -2242.09 7.35 5987112. 53 616584.24 N 70 22 24.752 W 149 3 8.538 10490.87 97.39 326.81 6702.11 6766.36 6919.27 7108.97 6958.72 6581.73 -2259.35 5.08 5987139. 36 616566.56 N 70 22 25.019 W 149 3 9.044 10521.85 96.42 321.63 6698.38 6762.63 6949.47 7139.72 6988.15 6606.67 -2277.32 16.89 5987164. 01 616548.19 N 70 22 25.264 W 149 3 9.570 10554.31 96.14 318.59 6694.83 6759.08 6980.66 7171.99 7018.30 6631.42 -2298.01 9.35 5987188. 43 616527.11 N 70 22 25.508 W 149 3 10.175 10586.26 96.01 316.01 6691.45 6755.70 7010.93 7203.76 7047.43 6654.77 -2319.56 8.04 5987211. 43 616505.20 N 70 22 25.737 W 149 3 10.806 10617.72 94.70 314.37 6688.51 6752.76 7040.41 7235.08 7075.69 6676.99 -2341.63 6.65 5987233. 30 616482.78 N 70 22 25.956 W 149 3 11.452 10649.67 93.19 314.45 6686.31 6750.56 7070.25 7266.96 7104.29 6699.29 -2364.40 4.73 5987255. 24 616459.66 N 70 22 26.175 W 149 3 12.118 10682.45 91.23 317.39 6685.05 6749.30 7101.22 7299.71 7134.07 6722.82 -2387.18 10.77 5987278. 40 616436.51 N 70 22 26.406 W 149 3 12.785 10714.16 90.00 316.30 6684.71 6748.96 7131.35 7331.42 7163.13 6745.95 -2408.87 5.18 5987301. 18 616414.46 N 70 22 26.634 W 149 3 13.420 10746.75 89.96 315.81 6684.72 6748.97 7162.19 7364.01 7192.85 6769.41 -2431.49 1.51 5987324. 28 616391.48 N 70 22 26.864 W 149 3 14.082 Last MWD+IFR+MS 10777.91 91.02 313.23 6684.45 6748.70 7191.38 7395.17 7220.93 6791.26 -2453.70 8.95 5987345. 77 616368.92 N 70 22 27.079 W 149 3 32 TD (Projected) 10853.00 87.60 310.00 6685.36 6749.61 7260.31 7470.24 7286.97 6841.11 -2509.82 6.26 5987394. 72 616312.02 N 70 22 27.569 W 149 3~4 Survey Type: Definitive Survey NOTES: GYD GC SS - (Gyrodata -gyro single shots --Gyrodata gyro orientation surveys. Not to be run above 70 degrees incl ination. ) MWD +IFR + MS - (In-field referenced MWD w ith mult-stat ion analysis and correction applied in post-processing. Assu mes a BHA sag correction is applied to enhance inclination accuracy. ) Legal Description: Northing (Y) [ftUS] Eastin g (X) [ftUS] Surface : 4391 FSL 4500 FEL S35 T 12N R12E UM 5980594.90 618929.91 BHL : 587 FSL 1533 FEL S22 T1 2N R12E UM 5987313.02 616500.96 SurveyEditor Ver SP 1.0 Bld( doc40x_56) S-122\S-122\S-122P62\S-122P62 Generated 911 912005 1 1:59 AM Page 4 of 4 S-122P63 Survey Report 3chiumberger Client: BP Exploration Alaska Field: Prudhoe Bay Unit - WOA Structure I Slot: S-PAD / S-122 Well: S-122 Borehole: S-122P63 UWUAPI#: 500292326572 Survey Name /Date: S-122P83 /August 16, 2005 Tort IAND / DDI I ERD ratio: 250.608° 18076.69 ft / 6.533 / 1.187 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location LaUlong: N 70 21 20.292, W 149 2 2.940 Location Grid WE Y/X: N 5980594.899 ftUS, E 618929.906 ftUS Grid Convergence Angle: +0.90964481 ° Survey / DLS Computation Method: Minimum Curvature / Lubinski Vertical Section Azimuth: 334.950° Vertical Section Origin: N 0.000 ft, E 0.000 ft TVD Reference Datum: Rotary Table TVD Reference Elevation: 64.25 ft relative to MSL Sea Bed /Ground Level Elevation: 35.70 ft relative to MSL Magnetic Declination: 24.687° Total Field Strength: 57588.860 nT Magnetic Dip: 80.882° Decfination Date: July 29, 2005 Magnetic Declination Model: BGGM 2005 North Reference: True North Total Corr Mag North -> True North: +24.687° 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 ft ft it n ft ft ft de 100 ft ftUS ftUS Filt V.VV V.VV U.VU -04.Zb V.VV V.VU V.VV V.VV U.UU U.UV U.VU byiSUby4.yV tiliSyZy.yl N /V "Ll GU.Y`JY First GYD GC SS 76.00 0.46 357. 51 11.75 76.00 0.28 0.31 0.31 0.30 -0.01 0.61 5980595.20 618929.89 N 70 21 20.295 100.00 0.35 24. 42 35.75 100.00 0.42 0.47 0.47 0.47 0.01 0.90 5980595.37 618929.91 N 70 21 20.297 198,00 0.14 17. 76 133.75 198.00 0.70 0.89 0.87 0.85 0.17 0.22 5980595.76 618930.07 N 70 21 20.300 250.00 0.82 128. 20 185.75 250.00 0.42 1.26 0.84 0.68 0.48 1.69 5980595.59 618930.38 N 70 21 20.299 300.00 1.38 131. 84 235.74 299.99 -0.46 2.22 1.22 0.06 1.21 1.13 5980594.98 618931.12 N 70 21 20.293 349.00 2.46 116. 46 284.71 348.96 -1.82 3.85 2.72 -0.80 2.60 2.42 5980594.14 618932.51 N 70 21 20.284 438.00 4.60 109. 24 373.53 437.78 -5.81 9.33 8.18 -2.83 7.68 2.45 5980592.19 618937.63 N 70 21 20.264 500.00 4.50 121. 68 435.34 499.59 -9.58 14.23 13.06 -4.92 12.09 1.60 5980590.17 618942.07 N 70 21 20.244 550.00 3.76 126. 03 485.21 549.46 -12.66 17.83 16.60 -6.92 15.09 1.61 5980588.22 618945.10 N 70 21 20.224 650.00 2.62 149.64 585.06 649.31 708.00 2.61 158.31 643.00 707.25 800.00 2.20 159.68 734.92 799.17 893.00 2.38 160.82 827.84 892.09 925:00 2.29 157.96 859.82 924.07 1000.00 1.65 172.65 934.77 999.02 1079.00 1.59 290.46 1013.76 1078.01 1100.00 1.85 294.16 1034.75 1099.00 1200.00 2.59 300.25 1134.67 1198.92 1250.00 2.69 299.72 1184.62 1248.87 1300.00 3.79 296.81 1234.54 1298.79 1350.00 5.35 295.83 1284.38 1348.63 1400.00 6.74 295.32 1334.10 1398.35 -17.80 -20.44 -24.29 -27.99 -29.29 -31.82 -32.12 -31.65 -28.57 -26.69 -24.43 -21.32 -17.25 23.31 25.96 29.82 33.53 34.84 37.40 38.96 39.59 43.46 45.77 48.59 52.57 57.84 21.77 24.00 27.23 30.44 31.60 33.82 33.74 33.17 29.56 27.41 24.85 21.42 17.30 -10.82 18.90 1.72 59$0584. 38 618948.97 N 70 21 20.186 -13.19 20.05 0.68 5980582. 03 618950.16 N 70 21 20.162 -16.79 21.44 0.45 5980578. 45 618951.61 N 70 21 20.127 -20.29 22.70 0.20 5980574. 97 618952.92 N 70 21 20.092 -21.51 23.15 0.46 5980573. 76 618953.40 N 70 21 20.080 VV 14y Z "L.y4U W 149 2 2.940 W 149 2 2.940 W 149 2 2.935 W 149 2 2.926 W 149 2 2.904 W 149 2 2.864 W 149 2 2.716 W 149 2 2.586 W 149 2 2.499 W 149 ~8 W 149 54 W 149 2 2.313 W 149 2 2.277 W 149 2 2.263 -23.97 23,85 1.08 5980571.31 618954.14 N 70 21 20.056 W 149 2 2.243 -24.72 22,97 3.51 5980570.55 618953.27 N 70 21 20.049 W 149 2 2.268 -24.48 22.39 1.35 5980570.78 618952.68 N 70 21 20.051 W 149 2 2.285 -22.68 18.97 0.78 5980572.53 618949.23 N 70 21 20.069 W 149 2 2.386 -21.53 16.97 0.21 5980573.65 618947.21 N 70 21 20.080 W 149 2 2.444 -20.20 14.48 2.22 5980574.93 618944.70 N 70 21 20.093 W 149 2 2.517 -18.44 10.90 3.12 5980576.64 618941.10 N 70 21 20.111 W 149 2 2.621 -16.17 6.15 2.78 5980578.83 618936.31 N 70 21 20.133 W 149 2 2.760 SurveyEditor Ver SP 1.0 Bld( doc40x_56) S-122\S-122\S-122P63\S-122P63 Generated 9/1 9/2005 1 1:59 AM Page 1 of 5 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitutle Depth Section Departure ft de de ft ft ft ft ft ft ft de 100 (t ftUS ftUS 145U.UU y.tfFi ~y4.tlti 1;itS:i.S/ 144/.ti1 -11./G bS.Uti 1;1.11 -1:1.17 -U.:iy (i.'L4 SyttU5ti1./tf ti12Sy'Ly./~ N /U "Ll 2U.lEi3 W 14y'L Z.y51 1500.00 11.78 293.85 1432.68 1496.93 -4.59 74.44 12.86 -9.25 -8.94 3.86 5980585.51 618921.12 N 70 21 20.201 W 149 2 3.201 Last GYD GC SS 1550.00 12.79 294.19 1481.53 1545.78 3.45 85.08 19.29 -4.92 -18.66 2.03 5980589.69 618911.33 N 70 21 20.244 W 149 2 3.485 First MWD+IFR+MS 1591.98 13.70 289.72 1522.39 1586.64 10.47 94.69 27.61 -1.33 -27.57 3.26 5980593.13 618902.36 N 70 21 20.279 W 149 2 3.746 1686.98 17.48 286.46 1613.88 1678.13 27.85 120.21 52.26 6.51 -51.86 4.08 5980600.58 618877.96 N 70 21 20.356 W 149 2 4.456 1782.38 19.02 296.93 1704.51 1768.76 49.60 150.01 81.39 17.61 -79.47 3.79 5980611.24 618850.18 N 70 21 20.465 W 149 2 5.263 1877.83 22.05 306.79 1793.91 1858.16 77.66 183.42 113.36 35.39 -107.70 4.81 5980628.58 618821.67 N 70 21 20.640 W 149 2 6.088 1972.81 23.31 311.47 1881,55 1945.80 110.62 220.03 148.11 58.52 -136.06 2.32 5980651.25 618792.95 N 70 21 20.868 W 149 2 6.917 2068.14 26.24 315.83 1968,10 2032.35 147.85 259.95 186.03 86.13 -164.88 3.62 5980678.40 618763.69 N 70 21 21.139 W 149 2 7.760 2164.41 28.11 320.93 2053.76 2118.01 189.97 303.90 227.61 119.01 -194.01 3.10 5980710.81 618734.04 N 70 21 21.462 W 149 2 8.612 2260.49 31.38 323.87 2137.17 2201.42 236.49 351.55 272.64 156.80 -223.04 3.73 5980748.13 618704.43 N 70 21 21.834 W 149 0 2355.35 31.69 328.13 2218.03 2282.28 285.47 401.15 319.46 197.92 -250.76 2.37 5980788.79 618676.06 N 70 21 22.238 W 149 2~0 2451.14 34.18 332.79 2298.43 2362.68 337.36 453.20 368.15 243.23 -276.36 3.71 5980833.69 618649.75 N 70 21 22.684 W 149 2 11.019 2545.77 36.71 338.59 2375.54 2439.79 392.17 508.05 418.67 293.22 -298.85 4.45 5980883.32. 618626.47 N 70 21 23.176 W 149 2 11.676 2641.35 37.93 343.54 2451.57 2515.82 449.75 565.97 471.15 348.01 -317.60 3.39 5980937.79 618606.85 N 70 21 23.715 W 149 2 12.225 2737.32 40.82 347.09 2525.76 2590.01 509.60 626.83 525.76 406.89 -332.97 3.82 5980996.41 618590.54 N 70 21 24,294 W 149 2 12.674 2834.00 44.29 349.11 2596.97 2661.22 573.24 692.20 584.56 470.86 -346.41 3.86 5981060.16 618576.09 N 70 21 24.923 W 149 2 13.067 2929.79 48.27 348.08 2663.16 2727.41 640.51 761.42 647.99 538.70 -360.12 4.23 5981127.77 618561.31 N 70 21 25.590 W 149 2 13.468 3025.62 52.61 347.16 2724.18 2788.43 712.58 835.28 717.28 610.84 -375.98 4.59 5981199.64 618544.31 N 70 21 26.299 W 149 2 13.931 3121.73 56.59 347.01 2779.84 2844.09 789.15 913.61 791.87 687.19 -393.48 4.14 5981275.69 618525.60 N 70 21 27,050 W 149 2 14.443 3215.11 56.21 346.89 2831.51 2895.76 865.23 991.39 866.64 762.95 -411.05 0.42 5981351.17 618506.84 N 70 21 27.795 W 149 2 14.957 3312.60 57.35 346.96 2884.92 2949.17 945.01 1072.94 945.57 842.40 -429.50 1.17 5981430.30 618487.13 N 70 21 28.577 W 149 2 15.497 3407.74 56.76 346.62 2936.66 3000.91 1023.15 1152.78 1023.28 920.12 -447.74 0.69 5981507.72 618467.65 N 70 21 29.341 W 149 2 16.030 3503.23 58.05 346.96 2988.10 3052.35 1101.89 1233.23 1101.89 998.44 -466.12 1.38 5981585.73 618448.03 N 70 21 30.111 W 149 216.568 3599.06 56.73 346.43 3039.75 3104.00 1180.92 1313.95 1181.04 1077.00 -484.70 1.45 5981663.98 618428.22 N 70 21 30.884 W 149 2 17.111 3753.15 56.73 346.14 3124.28 3188.53 1307.24 1442.79 1307.92 1202.16 -515.24 0.16 5981788.62 618395.69 N 70 21 32.115 W 149 2 18.004 3850.14 58.63 344.67 3176.13 3240.38 1387.84 1524.74 1389.01 1281.47 -535.90 2.34 59$1867.59 618373.77 N 70 21 32.895 W 149 2 18.608 3940.07 56.73 343.52 3224.21 3288.46 1462.86 1600.74 1464.50 1354.55 -556.72 2.37 5981940.33 618351.80 N 70 21 33.614 W 149 27 4041.51 57.32 343.24 3279.42 3343.67 1547.04 1685.84 1549.20 1436.10 -581.06 0.63 5982021.47 618326.17 N 70 21 34.416 W 149 2 9 4137.82 55.75 343.57 3332.53 3396.78 1626.51 1766.18 1629.19 1513.09 -604.01 1.66 5982098.08 618302.00 N 70 21 35.173 W 149 2 00 4239.59 55.12 343.37 3390.27 3454.52 1709.39 1849.98 1712.67 1593.43 -627.85 0.64 5982178.03 618276.89 N 70 21 35.963 W 149 2 21.297 4336.00 55.34 343.00 3445.25 3509.50 1787.77 1929. i 8 1791.61 1669.24 -650.76 0.39 5982253.46 618252.78 N 70 21 36.709 W 149 2 21.967 4431.67 55.86 342.64 3499.30 3563.55 1865.97 2008.12 1870.35 1744.66 -674.08 0.63 5982328.49 618228.27 N 70 21 37.450 W 149 2 22.649 4527.17 55.68 342.74 3553.02 3617.27 1944.20 2087.08 1949.14 1820.04 -697.58 0.21 5982403.48 618203.59 N 70 21 38.192 W 149 2 23.337 4622.73 53.35 344.12 3608.49 3672.74 2021. i 6 2164.88 2026.73 1894.61 -719.78 2.71 5982477.68 618180.21 N 70 21 38.925 W 149 2 23.986 4718.75 53.53 343.18 3665.69 3729.94 2097.40 2242.01 2103.63 1968.61 -741.49 0.81 5982551.32 618157.32 N 70 21 39.653 W 149 2 24.621 4814.00 55.69 344.25 3720.85 3785.10 2174.13 2319.65 2181.05 2043.15 -76325 2.45 5982625.50 618134.38 N 70 21 40.386 W 149 2 25.258 4909,67 54.87 344.63 3775.34 3839.59 2251.69 239829 2259.41 2118.90 -784.35 0.92 5982700.90 618112.09 N 70 21 41.131 W 149 2 25.875 5005,57 56.47 343.74 3829.42 3893.67 2329.86 2477.48 2338.36 2195.09 -805.93 1,84 5982776.73 618089.30 N 70 21 41.880 W 149 2 26.506 5100.25 56.74 343.76 3881.53 3945.78 2407.97 2556.53 2417.23 2270.98 -828.05 0.29 5982852.25 618065.98 N 70 21 42.626 W 149 2 27.153 5196.07 55.02 344.88 3935.28 3999.53 2486.24 2635.85 2496.33 2347.35 -849.50 2.04 5982928.26 618043.32 N 70 21 43.377 W 149 2 27.780 SurveyEditor Ver SP 1.0 Bld( doc40x_56) S-122\S-122\S-122P63\S-122PB3 Generated 9/19/2005 11:59 AM Page 2 of 5 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure h de de ft ft h ft ft ft ft de 100 ft ftUS ftUS 5Gy1.yt5 bb.1 tS 34b.G1 JytSy.4/ 4Vb3./'L G5b4.VG L/74.y25 Gb/b.IG G4G:S.y/ -tlby.Gb I.bb byt5JVV4.5b bI25VGG .3/ IV /V GI 44.1:57 VV 14`JGGiS..SbtS 5387.00 57.99 346.00 4041.10 4105.35 2642.28 2794.75 2654.48 2501.40 -888.40 1.91 5983081.67 618001 .98 N 70 21 44.892 W 149 2 28.919 5482.93 58.10 346.33 4091.87 4156.12 2722.11 2876.14 2735.48 2580.44 -907.87 0.31 5983160.38 617981 .27 N 70 21 45.670 W 149 2 29.488 5578.41 58.15 346.17 4142.29 4206.54 2801.62 2957.22 2816.18 2659.19 -927.14 0.15 5983238.81 617960 .75 N 70 21 46.444 W 149 2 30.052 5674.01 57.80 346.96 4192.99 4257.24 2881.02 3038.27 2896.83 2738.03 -945.97 0.79 5983317.33 617940 .67 N 70 21 47.220 W 149 2 30.603 5768.78 57.50 346.99 4243.70 4307.95 2959.32 3118.33 2976.46 2816.03 -964.01 0.32 5983395.03 617921 .39 N 70 21 47.987 W 149 2 31.131 5863.88 56.93 347.26 4295.19 4359.44 3037.47 3198.28 3055.98 2893.97 -981.83 0.65 5983472.67 617902 .35 N 70 21 48.753 W 149 2 31.652 5959.54 57.71 345.07 4346.85 4411.10 3116.45 3278.80 3136.21 2972.14 -1001.09 2.09 5983550.52 617881 .85 N 70 21 49.522 W 149 2 32.216 6056.21 57.69 342.53 4398.51 4462.76 3197.17 3360.50 3217.84 3050.60 -1023.88 2.22 5983628.60 617857 .82 N 70 21 50.294 W 149 2 32.882 6152.03 57.99 342.96 4449.51 4513.76 3277.54 3441.62 329$.93 3128.06 -1047.94 0.49 5983705.66 617832 .53 N 70 21 51.055 W 149 2 33.586 6247.99 57.75 343.61 4500.55 4564.80 3357.95 3522.89 3380.16 3205.89 -1071.31 0.63 5983783.10 617807 .93 N 70 21 51.821 W 149 2~0 6341.49 58.20 343.89 4550.13 4614.38 3436.28 3602.16 3459.37 3282.00 -1093.50 0.54 5983858.84 617784 .54 N 70 21 52.569 W 149 2 34.919 6438.88 57.50 343.34 4601.96 4666.21 3517.80 3684.61 3541.77 3361.10 -1116.75 0.86 5983937.56 617760 .03 N 70 21 53.347 W 149 2 35.600 6534.49 58.21 341.51 4652.83 4717.08 3598.06 3765.56 3622.71 3438.27 -1141.20 1.78 5984014.32 617734 .37 N 70 21 54.106 W 149 2 36.315 6631.65 56.35 340.49 4705.35 4769.60 3679.34 3847.30 3704.44 3515.56 -1167.81 2.11 5984091.17 617706 .54 N 70 21 54.866 W 149 2 37.093 6725.69 55.29 339.61 4758.18 4822.43 3756.82 3925.10 3782.21 3588.68 -1194.35 1.37 5984163.86 617678 .85 N 70 21 55.585 W 149 2 37.870 6821.40 56.39 339.93 4811.92 4876.17 3835.74 4004.29 3861.37 3663.00 -1221.73 1.18 5984237.72 617650 .29 N 70 21 56.316 W 149 2 38.671 6916.97 55.99 340.16 4865.10 4929.35 3914.83 4083.70 3940.75 3737.64 -1248.83 0.46 5984311.92 617622 .01 N 70 21 57.050 W 149 2 39.464 7013.59 55.96 339.95 4919.16 4983.41 3994.59 4163.78 4020.80 3812.91 -1276.15 0.18 5984386.74 617593 .50 N 70 21 57.790 W 149 2 40.263 7109.04 55.85 339.98 4972.67 5036.92 4073.34 4242.82 4099.82 3887.17 -1303.23 0.12 5984460.56 617565 .25 N 70 21 58.521 W 149 2 41.056 7204.60 56.13 340.11 5026.12 5090.37 4152.24 4322.03 4179.00 3961.63 -1330.26 0.31 5984534.57 617537 .04 N 70 21 59.253 W 149 2 41.847 7300.13 55.13 342.26 5080.05 5144.30 4230.61 4400.88 4257.85 4036.25 -1355.70 2.13 5984608.78 617510.42 N 70 21 59.987 W 149 2 42.591 7396.28 54.98 341.89 5135.12 5199.37 4308.82 4479.70 4336.66 4111.24 -1379.95 0.35 5984683.36 617484.98 N 70 22 0.724 W 149 2 43.301 7492.00 54.69 342.49 5190.25 5254.50 4386.44 4557.95 4414.90 4185.74 -1403.89 0.60 5984757.47 617459.87 N 70 22 1.457 W 149 2 44.002 7588.00 54.88 342.28 5245.61 5309.86 4464.22 4636.38 4493.32 4260.50 -1427.62 0.27 5984831.83 617434.95 N 70 22 2.192 W 149 2 44.696 7683.71 54.68 342.44 5300.81 5365.06 4541.75 4714.57 4571.50 4335.01 -1451.32 0.25 5984905.95 617410.08 N 70 22 2.925 W 149 2 45.390 7778.67 54.87 342.01 5355.58 5419.83 4618.70 4792.14 4649.07 4408.88 -1475.00 0.42 5984979.43 617385.23 N 70 22 3.651 W 149 2 46.083 7874.27 56.76 341.68 5409.29 5473.54 4697.21 4871.22 4728.14 4484.02 -1499.64 2.00 5985054.16 617359.40 N 70 22 4.390 W 149 2 4 7969.63 57.27 341.59 5461.21 5525.46 4776.65 4951.21 4808.13 4559.93 -1524.84 0.54 5985129.66 617333.00 N 70 22 5.137 W 149 2 2 8064.67 56.94 341.15 5512.83 5577.08 4855.95 5031.01 4887.93 4635.55 -1550.34 0.52 5985204.86 617306.31 N 70 22 5.880 W 149 2 4.88 8160.40 57.13 342.34 5564.92 5629.17 4935.71 5111.33 4968.25 4711.83 -1575.49 1.06 5985280.72 617279.95 N 70 22 6.631 W 149 2 49.024 8256.27 56.63 341.90 5617.30 5681.55 5015.37 5191.62 5048.54 4788.24 -1600.14 0.65 5985356.73 617254.09 N 70 22 7.382 W 149 2 49.745 8351.81 56.38 341.80 5670.02 5734.27 5094.47 5271.29 5128.21 4863.95 -1624.96 0.28 5985432.03 617228.08 N 70 22 8.127 W 149 2 50.472 8447.56 57.52 343.20 5722.24 5786.49 5174.02 5351.55 5208.45 4940.49 -1649.09 1.71 5985508.17 617202.74 N 70 22 8.879 W 149 2 51.178 8542.87 57.27 343.33 5773.60 5837.85 5253.47 5431.84 5288.71 5017.38 -1672.21 0.29 5985584.67 617178.40 N 70 22 9.635 W 149 2 51.855 8637.10 56.95 343.74 5824.77 5889.02 5331.71 5510.96 5367.79 5093.26 -1694.64 0.50 5985660.18 617154.78 N 70 22 10.382 W 149 2 52.511 8732.43 56.65 343.09 5876.97 5941.22 5410.61 5590.73 5447.51 5169.71 -1717.40 0.65 5985736.25 617130.80 N 70 22 11.133 W 149 2 53.178 8828.78 56.35 342.99 5930.15 5994.40 5490.15 5671.08 5527.84 5246.56 -1740.84 0.32 5985812.72 617106.15 N 70 22 11.889 W 149 2 53.864 8925.20 55.53 342.89 5984.15 6048.40 5569.26 5750.96 5607.69 5322.93 -1764.27 0.85 5985888.69 617081.51 N 70 2212.640 W 149 2 54.550 9020.82 57.12 343.57 6037.17 6101.42 5648.00 5830.53 5687.24 5399.12 -1787.23 1.76 5985964.50 617057.35 N 70 22 13.389 W 149 2 55.222 9116.04 56.79 343.95 6089.09 6153.34 5726.87 5910.35 5767.00 5475.75 -1809.55 0.48 5986040.76 617033.81 N 70 22 14.143 W 149 2 55.876 SurveyEditor Ver SP 1.0 Bld( doc40x_56) S-122\S-122\S-1 22P63\S-122PB3 Generated 9/1 9/2005 1 1:59 AM Page 3 of 5 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft h ft ft ft de 100 ft ftUS ftUS 9212.77 56.08 343.88 6142.57 6206.82 5806.49 5990.95 5847.54 5553.19 -1831.88 0.74 5986117.84 617010.26 N 70 22 14.905 W 149 2 56.529 9306.96 56.07 345.15 6195.14 6259.39 5883.56 6069.10 5925.61 5628.51 -1852.75 1.12 5986192.81 616988.20 N 70 22 15.645 W 149 2 57.140 9400.78 55.22 345.05 6248.09 6312.34 5959.80 6146.55 6002.93 5703.36 -1872.66 0.91 5986267.32 616967.10 N 70 22 16.381 W 149 2 57.724 9498.81 54.64 344.41 6304.41 6368.66 6038.86 6226.79 6083.06 5780.76 -1893.79 0.80 5986344.37 616944.75 N 70 22 17.143 W 149 2 58.342 9594.62 57.28 339.74 6358.06 6422.31 6117.61 6306.16 6162.41 5856.24 -1918.26 4.89 5986419.45 616919.09 N 70 22 17.885 W 149 2 59.059 9690.03 58.58 337.19 6408.72 6472.97 6198.29 6387.00 6243.11 5931.43 -1947.95 2.64 5986494.15 616888.21 N 70 22 18.624 W 149 2 59.928 9784.92 59.26 337.50 6457.71 6521.96 6279.49 6468.27 6324.13 6006.43 -1979.25 0.77 5986568.64 616855.73 N 70 22 19.362 W 149 3 0.844 9881.09 58.68 337.49 6507.28 6571.53 6361.81 6550.68 6406.31 6082.56 -2010.79 0.60 5986644.25 616822.98 N 70 22 20.110 W 149 3 1.767 9976.47 59.86 335.70 6556.02 6620.27 6443.76 6632.66 6487.97 6157.79 -2043.36 2.03 5986718.95 616789.22 N 70 22 20.850 W 149 3 2.721 10072.32 61.12 335.21 6603.23 6667.48 6527.17 6716.08 6570.90 6233.67 -2078.02 1.39 5986794.26 616753.37 N 70 22 21.596 W 149 3 3.735 Tie-In Survey 10167.70 60.66 335.04 6649.64 6713.89 6610.50 6799.41 6653.72 6309.27 -2113.07 0.51 5986869.29 616717.13 N 70 22 22.340 W 149 ~i2 Top Window (Inc only) 10217.00 60.80 335.15 6673.74 6737.99 6653.51 6842.41 6696.46 6348.28 -2131.18 0.34 5986908.00 616698.40 N 70 22 22.723 W 149 3 5.292 Base Window (Inc only) 10229.00 62.60 334.40 6679.43 6743.68 6664.07 6852.98 6706.95 6357.83 -2135.68 15.98 5986917.48 616693.75 N 70 22 22.817 W 149 3 5.424 End Mill (Inc Only) 10243.00 62.60 334.40 6685.87 6750.12 6676.50 6865.41 6719.29 6369.04 -2141.05 0.00 5986928.60 616688.20 N 70 22 22.928 W 149 3 5.581 Blind (Inc Only) 10268.64 69.85 334.40 6696.20 6760.45 6699.95 6888.86 6742.56 6390.19 -2151.18 28.28 5986949.58 616677.74 N 70 22 23.136 W 149 3 5.877 Blind (Inc Only) 10300.73 77.78 332.84 6705.14 6769.39 6730.73 6919.65 6773.07 6417.77 -2164.87 25.15 5986976.94 616663.61 N 70 22 23.407 W 149 3 6.278 First MWD+IFR+MS 10332.34 85.77 332.90 6709.66 6773.91 6761.97 6950.91 6803.99 6445.59 -2179.13 25.28 5987004.53 616648.92 N 70 22 23.680 W 149 3 6.695 10363.34 89.38 330.48 6710.97 6775.22 6792.89 6981.88 6834.52 6472.85 -2193.81 14.02 5987031.55 616633.80 N 70 22 23.948 W 149 3 7.125 Tie-In Survey 10395.10 91.54 329.81 6710.71 6774.96 6824.53 7013.63 6865.68 6500.39 -2209.62 7.12 5987058.84 616617.56 N 70 22 24.219 W 149 3 7.588 MWD+IFR+MS 10427.83 94.58 328.24 6708.97 6773.22 6857.04 7046.31 6897.62 6528.41 -2226.44 10.45 5987086.59 616600.30 N 70 22 24.495 W 149 3 8.080 10459.37 95.24 329.82 6706.27 6770.52 6888.29 7077.74 6928.35 6555.36 -2242.61 5.41 5987113.27 616583.71 N 70 22 24.760 W 149 3 8.554 10490.74 92.25 327.46 6704.22 6768.47 6919.40 7109.04 6958.91 6582.08 -2258.90 12.13 5987139.73 616567.00 N 70 22 25.023 W 149 3 9.030 10521.95 90.22 326.50 6703.55 6767.80 6950.30 7140.24 6989.18 6608.24 -2275.90 7.19 5987165.61 616549.59 N 70 22 25.280 W 149 3 9.528 10554.13 89.54 322.83 6703.61 6767.86 6981.96 7172.42 7020.06 6634.49 -2294.51 11.60 5987191.56 616530.56 N 70 22 25.538 W 149 3 10.073 10586.55 89.74 319.42 6703.82 6768.07 7013.43 7204.84 7050.57 6659.72 -2314.85 10.54 5987216.47 616509.82 N 70 22 25.786 W 149 3 10.668 10617.59 90.12 316.76 6703.85 6768.10 7043.14 7235.88 7079.20 6682.82 -2335.59 8.66 5987239.23 616488.73 N 70 22 26.013 W 149 3 11.275 10649.77 90.43 313.28 6703.70 6767.95 7073.38 7268.06 7108.20 6705.58 -2358.33 10.86 5987261.62 616465.63 N 70 22 26.237 W 149 3 11.941 10682.32 90.39 309.79 6703.47 6767.72 7103.25 7300.61 7136.66 6727.16 -2382.69 10.72 5987282.81 616440.93 N 70 22 26.449 W 149 3 4 10713.13 90.09 305.81 6703.34 6767.59 7130.66 7331.41 7162.60 6746.04 -2407.03 12.95 5987301.30 616416.30 N 70 22 26.635 W 149 3~6 10745.55 89.61 303.84 6703.42 6767.67 7158.70 7363.83 7189.01 6764.55 -2433.64 6.25 5987319.39 616389.40 N 70 22 26.817 W 149 3 14.145 10778.00 90.26 302.02 6703.46 6767.71 7186.21 7396.28 7214.85 6782.19 -2460.88 5.96 5987336.59 616361.89 N 70 22 26.990 W 149 3 14.942 10809.52 90.60 300.29 6703.22 6767.47 7212.40 7427.80 7239.40 6798.50 -2487.85 5.59 5987352.46 616334.66 N 70 22 27.150 W 149 3 15.731 10841.83 90.70 300.75 6702.86 6767.11 7239.05 7460.11 7264.41. 6814.91 -2515.68 1.46 5987368.43 616306.58 N 70 22 27.312 W 149 3 16.546 10873.42 90.22 298.93 6702.60 6766.85 7264.89 7491.70 7288.67 6830.62 -2543.08 5.96 5987383.71 616278.93 N 70 22 27.466 W 149 3 17.347 10904.95 89.64 297.84 6702.64 6766.89 7290.21 7523.23 7312.42 6845.61 -2570.82 3.92 5987398.25 616250.96 N 70 22 27.613 W 149 3 18.159 10936.92 88.89 298.25 6703.05 6767.30 7315.77 7555.20 7336.44 6860.64 -2599.03 2.67 5987412.83 616222.52 N 70 22 27.761 UV 149 3 18.985 10968.65 85.93 298.28 6704.49 6768.74 7341.19 7586.89 7360.40 6875.65 -2626.95 9.33 5987427.39 616194.37 N 70 22 27.909 W 149 3 19.802 11000.25 83.52 297.54 6707.39 6771.64 7366.31 7618.36 7384.11 6890.38 -2654.75 7.98 5987441.68 616166.34 N 70 22 28.053 W 149 3 20.615 11032.94 83.69 297.78 6711.03 6775.28 7392.15 7650.84 7408.55 6905.46 -2683.52 0.90 5987456.30 616137.33 N 70 22 28.202 W 149 3 21.457 11063.67 83.80 297.28 6714.38 6778.63 7416.41 7681.39 7431.55 6919.58 -2710.61 1.66 5987469.98 616110.02 N 70 22 28.340 W 149 3 22.250 SurveyEditor Ver SP 1.0 Bld( doc4Ox_56) S-122\S-122\S-122P63\S-122P63 Generated 9/19/2005 11:59 AM Page 4 of 5 Comments Measured Inclination Azimuth Sub-Sea 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 11096.73 83.yU 19(1.59 Ei71/.y2 6/8L.1/ 7441,31 /714.2(1 /4tiFi.14 6y34.4/ -1/3y.yZ 2.1U 5y8/484.4U 11128.61 83.94 297.92 6721.30 6785.55 7467.39 7745.96 7480.02 6948.99 -2768.10 4.15 5987498.47 11159.93 84.70 296.38 6724.40 6788.65 7492.02 7777.13 7503.53 6963.21 -2795.83 5.46 5987512.25 11191.54 86.07 296.79 6726.94 6791.19 7516.72 7808.63 7527.14 6977.31 -2824.00 4.52 5987525.90 11224.09 86.04 296.56 6729.18 6793.43 7542,21 7841.10 7551.57 6991.88 -2853.02 0.71 5987540.01 11255.84 86.11 296.50 6731.35 6795.60 7567.03 7872.78 7575.40 7006.03 -2881.36 0.29 5987553.71 11287.58 85.83 295.99 6733.59 6797.84 7591.74 7904.44 7599.18 7020.03 -2909.76 1.83 5987567.25 11320.05 85.28 295.40 6736.10 6800.35 7616.80 7936.81 7623.35 7034.07 -2938.93 2.48 5987580.82 11351.92 87.89 293.74 6738.00 6802.25 7641.04 7968.62 7646.74 7047.30 -2967.86 9.70 5987593.59 11383.47 89.61 293.75 6738.69 6802.94 7664.77 8000.17 7669.68 7060.00 -2996.73 5.45 5987605.83 Last MWD+IFR+MS 11404.13 89.54 294.20 6738.84 6803.09 7680.36 8020.83 7684.79 7068.39 -3015.61 2.20 5987613.92 TD (Projected) 11460.00 89.54 294.20 6739.29 6803.54 7722.69 8076.69 7725.95 7091.29 -3066.57 0.00 5987636.01 Survey Type: Definitive Survey NOTES: GYD GC SS - (Gyrodata -gyro single shots -- Gyrodata gyro orientation surveys. Not to be run above 70 degrees inclination. ) MWD +IFR + MS - (In-field referenced MWp with mull-station analysis and correction applied in post-processing. Assumes a BHA sag correction is applied to enh ance inclination accuracy. ) Legal Description: Northing (Y) [ftUS] Easting (X) [ftUS] Surface : 4391 FSL 4500 FEL S35 T 12N R12E UM 5980594.90 618929.91 BHL : 921 FSL 2277 FEL S22 T1 2N R12E UM 5987636.01 615751.42 (il(iU8U.49 N /U LL 1tf.48/ W 149313.1Uti 616052.09 N 70 22 28.629 W 149 3 23.932 616024.13 N 70 22 28.769 W 149 3 24.744 615995.74 N 70 22 28.908 W 149 3 25.569 615966.50 N 70 22 29.051 W 149 3 26.418 615937,94 N 70 22 29.190 W 149 3 27.247 615909.33 N 70 22 29.328 W 149 3 28.078 615879.94 N 70 22 29.465 W 149 3 28.932 615850.81 N 70 22 29.595 W 149 3 29.778 615821,74 N 70 22 29.720 W 149 3 30.623 615802.73 N 70 22 29.803 W 149 3~6 615751,42 N 70 22 30.028 W 149 3 7 i SurveyEditor Ver SP i.0 Bld( doc40x_56) S-122\S-122\S-122PB3\S-122P63 Generated 9/19/2005 11:59 AM Page 5 of 5 S-122 Survev Report ~chlumherger Report Date: 17-Aug-05 Survey / DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 334.950° Field: Prudhoe Bay Unit - WOA Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure /Slot: S-PAD / S-122 TVD Reference Datum: RKB Well: S-122 TVD Reference Elevation: 64.25 ft relative to MSL Borehole: S-122 Sea Bed /Ground Level Elevation: 35.70 it relative to MSL UWUAPIfi: 500292326500 Magnetic Declination: 24.687° Survey Name I Date: S-122 /August 17, 2005 Total Field Strength: 57588.860 nT Tort /AHD / DDI / ERD ratio: 263.900° / 8789.68 ft / 6.619 / 1.296 Magnetic Dip: 80.882° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: July 29, 2005 Location LaUtong: N 70 2120.292, W 149 2 2.940 Magnetic Declination Model: BGGM 2005 Location Grid WE YIX: N 5980594.899 ftUS, E 618929.906 ftUS North Reference: True North Grid Convergence Angle: +0.90964481 ° Total Corr Mag North -> True North: +24.687° Grid Scale Factor: 0.99991607 Local Coordinates Referenced To: Well Head r 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 ft ft ft ft ft ft ft de 100 ft ftUS ftUS n i c v.vV V.vv V.VV -04.LD V.VV V.UV V.VV V.VV V.VV V.VV V.VV - byt3V5y4.yV bltSyZy.yl N /U Zl ZV."LyL W 14y 1 "G.y4U First GYD GC SS 76.00 0.46 357.51 11.75 76.00 0.28 0.31 0.31 0.30 -0.01 0.61 5980595.20 618929.89 N 70 21 20.295 W 149 2 2.940 100.00 0.35 24.42 35.75 100.00 0.42 0.47 0.47 0.47 0.01 0.90 5980595.37 618929.91 N 70 21 20.297 W 149 2 2.940 198.00 0.14 17.76 133.75 198.00 0.70 0.89 0.87 0.85 0.17 0.22 5980595.76 618930.07 N 70 21 20.300 W 149 2 2.935 250.00 0.82 128.20 185.75 250.00 0.42 1.26 0.84 0.68 0.48 1.69 5980595.59 618930.38 N 70 21 20.299 W 149 2 2.926 300.00 1.38 131.84 235.74 299.99 -0.46 2.22 1.22 0.06 1.21 1.13 5980594.98 618931.12 N 70 21 20.293 W 149 2 2.904 349.00 2.46 116.46 284.71 348.96 -1.82 3.85 2.72 -0.80 2.60 2.42 5980594.14 618932.51 N 70 21 20.284 W 149 2 2.864 438.00 4.60 109.24 373.53 437.78 -5.81 9.33 8.18 -2.83 7.68 2.45 5980592.19 618937.63 N 70 21 20.264 W 149 2 2.716 500.00 4.50 121.68 435.34 499.59 -9.58 14.23 13.06 -4.92 12.09 1.60 5980590.17 618942.07 N 70 21 20.244 W 149 2 2.586 550.00 3.76 126.03 485.21 549.46 -12.66 17.83 16.60 -6.92 15.09 1.61 5980588.22 618945.10 N 70 21 20.224 W 149 2 2.499 650.00 2.62 149.64 585.06 649.31 -17.80 23.31 21.77 -10.82 18.90 1.72 5980584.38 618948.97 N 70 21 20.186 W 149 ~8 708.00 2.61 158.31 643.00 707.25 -20.44 25.96 24.00 -13.19 20.05 0.68 5980582.03 618950.16 N 70 21 20.162 W 149 2TS''4 800.00 2.20 159.68 734.92 799.17 -24.29 29.82 27.23 -16.79 21.44 0.45 5980578.45 618951.61 N 70 21 20.127 W 149 2 2.313 893.00 2.38 160.82 827.84 892.09 -27.99 33.53 30.44 -20.29 22.70 0.20 5980574.97 618952.92 N 70 21 20.092 W i 49 2 2.277 925.00 2.29 157.96 859.82 924.07 -29.29 34.84 31.60 -21.51 23.15 0.46 5980573.76 618953.40 N 70 21 20.080 W 149 2 2.263 1000.00 1.65 172.65 934.77 999.02 -31.82 37.40 33.82 -23.97 23.85 1.08 5980571.31 618954.14 N 70 21 20.056 W 149 2 2.243 1079.00 1.59 290.46 1013.76 1078.01 -32.12 38.96 33.74 -24.72 22.97 3.51 5980570.55 618953.27 N 70 21 20.049 W 149 2 2.268 1 i 00.00 1.85 294.16 1034.75 1099.00 -31.65 39.59 33.17 -24.48 22.39 1.35 5980570.78 618952.68 N 70 21 20.051 W 149 2 2.285 1200.00 2.59 300.25 1134.67 1198.92 -28.57 43.46 29.56 -22.68 18.97 0.78 5980572.53 618949.23 N 70 21 20.069 W 149 2 2.386 1250.00 2.69 299.72 1184.62 1248.87 -26.69 45.77 27.41 -21.53 16.97 0.21 5980573.65 618947.21 N 70 21 20.080 W 149 2 2.444 1300.00 3.79 296.81 1234.54 1298.79 -24.43 48.59 24.85 -20.20 14.48 2.22 5980574.93 618944.70 N 70 21 20.093 W 149 2 2.517 1350.00 5.35 295.83 1284.3$ 1348.63 -21.32 52.57 21.42 -18.44 10.90 3.12 5980576.64 618941.10 N 70 21 20.111 W 149 2 2.621 1400.00 6.74 295.32 1334.10 1398.35 -17.25 57.84 17.30 -16.17 6.15 2.78 5980578.83 618936.31 N 70 21 20.133 W 149 2 2.760 1450.00 9.86 294.86 1383.57 1447.82 -11.72 65.06 13.12 -13.11 -0.39 6.24 5980581.78 618929.73 N 70 21 20.163 W 149 2 2.951 SurveyEditor Ver SP 1.0 Bld( doc40x_56) S-i22\S-122iS-122iS-122 Generated 9/19/2005 12:00 PM Page 1 of 5 Comments Measured Inclination Azimuth Sub-Sea 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 15UU.UU 11./8 293.85 143L.68 1496.93 -4.59 /4.44 12.86 -9.Z5 -8.94 3.86 5980585.51 618921.12 N 70 21 20.201 W 149 2 3.201 Last GYD GC SS 1550.00 12.79 294.19 1481.53 1545.78 3.45 85.08 19.29 -4.92 -18.66 2.03 5980589.69 618911.33 N 70 21 20.244 W 149 2 3.485 First MWD+IFR+MS 1591.98 13.70 289.72 1522.39 1586.64 10.47 94.69 27.61 -1.33 -27.57 3.26 5980593.13 618902.36 N 70 21 20.279 W 149 2 3.746 1686.98 17.48 286.46 1613.88 1678.13 27.85 120.21 52.26 6.51 -51.86 4.08 5980600.58 618877.96 N 70 21 20.356 W 149 2 4.456 1782.38 19.02 296.93 1704.51 1768.76 49.60 150.01 81.39 17.61 -79.47 3.79 5980611.24 618850.18 N 70 21 20.465 W 149 2 5.263 1877.83 22.05 306.79 1793.91 1858.16 77.66 183.42 113.36 35.39 -107.70 4.81 5980628.58 618821.67 N 70 21 20.640 W 149 2 6.088 1972.81 23.31 311.47 1881.55 1945.80 110.62 220.03 148.11 58.52 -136.06 2.32 5980651.25 618792.95 N 70 21 20.868 W 149 2 6.917 2068.14 26.24 315.83 1968.10 2032.35 147.85 259.95 186.03 86.13 -164.88 3.62 5980678.40 618763.69 N 70 21 21.139 W 149 2 7.760 2164.41 28.11 320.93 2053.76 2118.01 189.97 303.90 227.61 119.01 -194.01 3.10 5980710.81 618734.04 N 70 21 21.462 W 149 2 8.612 2260.49 31.38 323.87 2137.17 2201.42 236.49 351.55 272.64 156.80 -223.04 3.73 5980748.13 618704.43 N 70 21 21.834 W 149 2 9.460 2355.35 31.69 328.13 2218.03 2282.28 285.47 401.15 319.46 197.92 -250.76 2.37 5980788.79 618676.06 N 70 21 22.238 W 149 2 ~0 2451.14 34.18 332.79 2298.43 2362.68 337.36 453.20 368.15 243.23 -276.36 3.71 5980833.69 618649.75 N 70 21 22.684 W 149 2 11.019 2545.77 36.71 338.59 2375.54 2439.79 392.17 508.05 418.67 293.22 -298.85 4.45 5980883.32 618626.47 N 70 21 23.176 W 149 2 11.676 2641.35 37.93 343.54 2451.57 2515.82 449.75 565.97 471.15 348.01 -317.60 3.39 5980937.79 618606.85 N 70 21 23.715 W 149 2 12.225 2737.32 40.82 347.09 2525.76 2590.01 509.60 626.83 525.76 406.89 -332.97 3.82 5980996.41 618590.54 N 70 21 24.294 W 149 2 12.674 2834.00 44.29 349.11 2596.97 2661.22 573.24 692.20 584.56 470.86 -346.41 3.86 5981060.16 618576.09 N 70 21 24.923 W 149 2 13.067 2929.79 48.27 348.08 2663.16 2727.41 640.51 761.42 647.99 538,70 -360.12 4.23 5981127.77 618561.31 N 70 21 25.590 W 149 2 13.468 3025.62 52.61 347.16 2724.18 2788.43 712.58 835.28 717.28 610.84 -375.98 4.59 5981199.64 618544.31 N 70 21 26.299 W 149 2 13.931 3121.73 56.59 347.01 2779.84 2844.09 789.15 913.61 791.87 687.19 -393.48 4.14 5981275.69 618525.60 N 70 21 27.050 W 149 2 14.443 3215.11 56.21 346.89 2831.51 2895.76 865.23 991.39 866.64 762.95 -411.05 0.42 5981351.17 618506.84 N 70 21 27.795 W 149 2 14.957 3312.60 57.35 346.96 2884.92 2949.17 945.01 1072.94 945.57 842.40 -429.50 1.17 5981430.30 618487.13 N 70 21 28.577 W 149 2 15.497 3407.74 56.76 346.62 2936.66 3000.91 1023.15 1152.78 1023.28 920.12 -447.74 0.69 5981507.72 618467.65 N 70 21 29.341 W 149 2 16.030 3503.23 58.05 346.96 2988.10 3052.35 1101.89 1233.23 1101.89 998.44 -466.12 1.38 5981585.73 618448.03 N 70 21 30.111 W 149 2 16.568 3599.06 56.73 346.43 3039.75 3104.00 1180.92 1313.95 1181.04 1077.00 -484.70 1.45 5981663.98 618428.22 N 70 21 30.884 W 149 2 17.111 3753.15 56.73 346.14 3124.28 3188.53 1307.24 1442.79 1307.92 1202.16 -515.24 0.16 5981788.62 618395.69 N 70 21 32.115 W 149 2 18.004 3850.14 58.63 344.67 3176.13 3240.38 1387.84 1524.74 1389.01 1281.47 -535.90 2.34 5981867.59 618373.77 N 70 21 32.895 W 149 2 18.608 3940.07 56.73 343.52 3224.21 3288.46 1462.86 1600.74 1464.50 1354.55 -556.72 2.37 5981940.33 618351.80 N 70 21 33.614 W 149 2 19.217 4041.51 57.32 343.24 3279.42 3343.67 1547.04 1685.84 1549.20 1436.10 -581.06 0.63 5982021.47 618326.17 N 70 21 34.416 W 149 2 9 4137.82 55.75 343.57 3332.53 3396.78 1626.51 1766.18 1629.19 1513.09 -604.01 1.66 5982098.08 618302.00 N 70 21 35.173 W 149 2 0 4239.59 55.12 343.37 3390.27 3454.52 1709.39 1849.98 1712.67 1593.43 -627.85 0.64 5982178.03 618276.89 N 70 21 35.963 W 149 2 2.97 4336.00 55.34 343.00 3445.25 3509.50 1787.77 1929.18 1791.61 1669.24 -650.76 0.39 5982253.46 618252.78 N 70 21 36.709 W 149 2 21.967 4431.67 55.86 342.64 3499.30 3563.55 1865.97 2008.12 1870.35 1744.66 -674.08 0.63 5982328.49 618228.27 N 70 21 37.450 W 149 2 22.649 4527.17 55.68 342.74 3553.02 3617.27 1944.20 2087.08 1949.14 1820.04 -697.58 0.21 5982403.48 618203.59 N 70 21 38.192 W 149 2 23.337 4622.73 53.35 344.12 3608.49 3672.74 2021.16 2164.88 2026.73 1894.61 -719.78 2.71 5982477.68 618180.21 N 70 21 38.925 W 149 2 23.986 4718.75 53.53 343.18 3665.69 3729.94 2097.40 2242.01 2103.63 1968.61 -741.49 0.81 5982551.32 618157.32 N 70 21 39.653 W 149 2 24.621 4814.00 55.69 344.25 3720.85 3785.10 2174.13 2319.65 2181.05 2043.15 -763.25 2.45 5982625.50 618134.38 N 70 21 40.386 W 149 2 25.258 4909.67 54.87 344.63 3775.34 3839.59 2251.69 2398.29 2259.41 2118.90 -784.35 0.92 5982700.90 618112.09 N 70 21 41.131 W 149 2 25.875 5005.57 56.47 343.74 3829.42 3893.67 2329.86 2477.48 2338.36 2195.09 -805.93 1.84 5982776.73 618089.30 N 70 21 41.880 W 149 2 26.506 5100.25 56.74 343.76 3881.53 3945.78 2407.97 2556.53 2417.23 2270.98 -828.05 0.29 5982852.25 618065.98 N 70 21 42.626 W 149 2 27.153 5196.07 55.02 344.88 3935.28 3999.53 2486.24 2635.85 2496.33 2347.35 -849.50 2.04 5982928.26 618043.32 N 70 21 43.377 W 149 2 27.780 5291.98 56.18 346.21 3989.47 4053.72 2564.02 2714.98 2575.12 2423.97 -869.25 1.66 5983004.56 618022.37 N 70 21 44.131 W 149 2 28.358 SurveyEditor Ver SP 1.0 Bld( doc40x_56) S-122\S-122\S-122\S-122 Generated 9/19/2005 12:00 PM Page 2 of 5 Comments Measured Inclination Azimuth Sub-Sea 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 5~t5/.UU S/.yy 34ti.UU 4U41.1U 41Ub.J5 'Lb4L."Lt1 L1~J4./5 Lb54.4t5 L5U1.4V -i5tSt5.4V l.yl by2S;3V211.b/ 5482.93 58.10 346.33 4091.87 4156.12 2722.11 2876.14 2735.48 2580.44 -907.87 0.31 5983160.38 5578.41 58.15 346.17 4142.29 4206.54 2801.62 2957.22 2816.18 2659.19 -927.14 0.15 5983238.81 5674.01 57.80 346.96 4192.99 4257.24 2881.02 3038.27 2896.83 2738.03 -945.97 0.79 5983317.33 5768.78 57.50 346.99 4243:70 4307.95 2959.32 3118.33 2976.46 2816.03 -964.01 0.32 5983395.03 5863.88 56.93 347.26 4295.19 4359.44 3037.47 3198.28 3055.98 2893.97 -981.83 0.65 5983472.67 5959.54 57.71 345.07 4346.85 4411.10 3116.45 3278.80 3136.21 2972.14 -1001.09 2.09 5983550.52 6056.21 57.69 342.53 4398.51 4462.76 3197.17 3360.50 3217.84 3050,60 -1023.88 2.22 5983628.60 6152.03 57.99 342.96 4449.51 4513.76 3277.54 3441.62 3298.93 3128.06 -1047.94 0.49 5983705.66 6247.99 57.75 343.61 4500.55 4564.80 3357.95 3522.89 3380.16 3205.89 -1071.31 0.63 5983783.10 6341.49 58.20 343.89 4550.13 4614.38 3436.28 3602.16 3459.37 3282.00 -1093.50 0.54 5983858.84 6438.88 57.50 343.34 4601.96 4666.21 3517.80 3684.61 3541.77 3361.10 -1116.75 0.86 5983937.56 6534.49 58.21 341.51 4652.83 4717.08 3598.06 3765.56 3622.71 3438.27 -1141.20 1.78 5984014.32 6631.65 56.35 340.49 4705.35 4769.60 3679.34 3847.30 3704.44 3515.56 -1167.81 2.11 5984091.17 6725.69 55.29 339.61 4758.18 4822.43 3756.82 3925.10 3782.21 3588.68 -1194.35 1.37 5984163.86 6821.40 56.39 339.93 4811.92 4876.17 3835.74 4004.29 3861.37 3663.00 -1221.73 1.18 5984237.72 6916.97 55.99 340.16 4865.10 4929.35 3914.83 4083.70 3940.75 3737.64 -1248.83 0.46 5984311.92 7013.59 55.96 339.95 4919.16 4983.41 3994.59 4163.78 4020.50 3812.91 -1276.15 0.18 5984386.74 7109.04 55.85 339.98 4972.67 5036.92 4073.34 4242.82 4099.82 3887.17 -1303.23 0.12 5984460.56 7204.60 56.13 340.11 5026.12 5090.37 4152.24 4322.03 4179.00 3961.63 -1330.26 0.31 5984534.57 7300.13 55.13 342.26 5080.05 5144.30 4230.61 4400.88 4257.85 4036.25 -1355.70 2.13 5984608.78 7396.28 54.98 341.89 5135.12 5199.37 4308.82 4479.70 4336.66 4111.24 -1379.95 0.35 5984683.36 7492.00 54.69 342.49 5190.25 5254.50 4386.44 4557.95 4414.90 4185.74 -1403.89 0.60 5984757.47 7588.00 54.88 342.28 5245.61 5309.86 4464.22 4636.38 4493.32 4260.50 -1427.62 0.27 5984831.83 7683.71 54.68 342,44 5300.81 5365.06 4541.75 4714.57 4571.50 4335.01 -1451,32 0.25 5984905.95 7778.67 54.87 342.01 5355.58 5419.83 4618.70 4792.14 4649.07 4408.88 -1475.00 0.42 5984979.43 7874.27 56.76 341.68 5409.29 5473.54 4697.21 4871.22 4728.14 4484.02 -1499.64 2.00 5985054.16 7969.63 57.27 341.59 5461.21 5525.46 4776.65 4951.21 4808.13 4559.93 -1524.84 0.54 5985129.66 8064.67 56.94 341.15 5512.83 5577.08 4855.95 5031.01 4887.93 4635.55 -1550.34 0.52 5985204,86 8160.40 57.13 342.34 5564.92 5629.17 4935.71 5111.33 4968.25 4711.83 -1575.49 1.06 5985280.72 8256. 27 56. 63 341. 90 5617.30 5681. 55 5015. 37 5191. 62 5048.54 4788.24 -1600.14 0.65 5985356. 73 8351. 81 56. 38 341. 80 5670.02 5734. 27 5094. 47 5271. 29 5128.21 4863.95 -1624.96 0.28 5985432. 03 8447. 56 57. 52 343. 20 5722.24 5786. 49 5174. 02 5351. 55 5208.45 4940.49 -1649.09 1.71 5985508. 17 8542. 87 57. 27 343. 33 5773.60 5837. 85 5253. 47 5431. 84 5288.71 5017.38 -1672.21 0.29 5985584. 67 8637. 10 56. 95 343. 74 5824.77 5889. 02 5331. 71 5510. 96 5367.79 5093.26 -1694,64 0.50 5985660. 18 8732. 43 56. 65 343. 09 5876.97 5941. 22 5410. 61 5590. 73 5447.51 5169.71 -1717.40 0.65 5985736. 25 8828. 78 56. 35 342. 99 5930.15 5994. 40 5490. 15 5671. 08 5527.84 5246.56 -1740.84 0.32 5985812. 72 8925. 20 55. 53 342. 89 5984.15 6048. 40 5569. 26 5750. 96 5607.69 5322.93 -1764.27 0.85 5985888. 69 9020. 82 57. 12 343. 57 6037.17 6101. 42 5648. 00 5830. 53 5687.24 5399.12 -1787.23 1.76 5985964. 50 9116. 04 56. 79 343. 95 6089.09 6153. 34 5726. 87 5910. 35 5767.00 5475.75 -1809.55 0.48 5986040. 76 9212. 77 56. 08 343. 88 6142.57 6206. 82 5806. 49 5990. 95 5847.54 5553.19 -1831.88 0.74 5986117. 84 9306. 96 56. 07 345. 15 6195.14 6259. 39 5883. 56 6069. 10 5925.61 5628.51 -1852.75 1.12 5986192. 81 bl25VU1.y23 N /V Ll 44.23yL VV 14`J L Lt3.yly 617981.27 N 70 21 45.670 W 149 2 29.488 617960.75 N 70 21 46.444 W 149 2 30.052 617940.67 N 70 21 47.220 W 149 2 30.603 617921.39 N 70 21 47.987 W 149 2 31.131 617902.35 N 70 21 48.753 W 149 2 31.652 617881.85 N 70 21 49.522 W 149 2 32.216 617857.82 N 70 21 50.294 W 149 2 32.882 617832.53 N 70 21 51.055 W 149 2 33.586 617807.93 N 70 21 51.821 W 149 2 34.270 617784.54 N 70 21 52.569 W 149 219 617760.03 N 70 21 53.347 W617760.03 N 70 21 53.347 149 0 617734.37 N 70 21 54.106 W 149 2 36.315 617706.54 N 70 21 54.866 W 149 2 37.093 617678.85 N 70 21 55.585 W 149 2 37.870 617650.29 N 70 21 56.316 W 149 2 38.671 617622.01 N 70 21 57.050 W 149 2 39.464 617593.50 N 70 21 57.790 W 149 2 40.263 617565.25 N 70 21 58.521 W 149 2 41.056 617537.04 N 70 21 59.253 W 149 2 41.847 617510.42 N 70 21 59.987 W 149 2 42.591 617484.98 N 70 22 0.724 W 149 2 43.301 617459.87 N 70 22 1.457 W 149 2 44.002 617434.95 N 70 22 2.192 W 149 2 44.696 617410.08 N 70 22 2.925 W 149 2 45.390 617385.23 N 70 22 3.651 W 149 2 46.083 617359.40 N 70 22 4.390 W i 49 2 46.804 617333.00 N 70 22 5.137 W 149 2 47.542 617306.31 N 70 22 5.880 W 149 2 8 617279.95 N 70 22 6.631 W 149 2~4 617254.09 N 70 22 7.382 W 149 2 49.745 617228.08 N 70 22 8.127 W 149 2 50.472 617202.74 N 70 22 8.879 W 149 2 51.178 617178.40 N 70 22 9.635 W 149 2 51.855 617154.78 N 70 22 10.382 W 149 2 52.511 617130.80 617106.15 617081.51 617057.35 617033.81 617010.26 616988.20 N 70 22 11.133 N 70 22 11.889 N 70 22 12.640 N 70 22 13.389 N 70 22 14.143 N 70 22 14.905 N 70 22 15.645 W 149 2 53.178 W 149 2 53.864 W 149 2 54.550 W 149 2 55.222 W 149 2 55.876 W 149 2 56.529 W 149 2 57.140 SurveyEditor Ver SP 1.0 Bld( doc40x_56) S-122\S-122\S-122\S-122 Generated 9/19/2005 12:00 PM Page 3 of 5 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft it ft ft ft ft de 100 ft ftUS ftUS `J4UV. /ii bb. LL J4b. Ub ti"G4tS .Uy b:ilL. ;i4 5yby.tSU bl4b. bb bVVL. y3 b/U:i. ;Sb -lt3/L.bb V.yl bytSbLb/. 3L 9498. 81 54. 64 344. 41 6304 .41 6368 .66 6038. 86 6226. 79 6083. 06 5780. 76 -1893.79 0.80 5986344. 37 9594. 62 57. 28 339. 74 6358 .06 6422. 31 6117. 61 6306. 16 6162. 41 5856. 24 -1918.26 4.89 5986419. 45 9690. 03 58. 58 337. 19 6408. 72 6472. 97 6198. 29 6387. 00 6243. 11 5931. 43 -1947.95 2.64 5986494. 15 9784. 92 59. 26 337. 50 6457. 71 6521. 96 6279. 49 6468. 27 6324. 13 6006. 43 -1979.25 0.77 5986568. 64 9881. 09 58. 68 337. 49 6507. 28 6571. 53 6361. 81 6550. 68 6406. 31 6082. 56 -2010.79 0.60 5986644. 25 9976. 47 59. 86 335. 70 6556. 02 6620. 27 6443. 76 6632. 66 6487. 97 6157. 79 -2043.36 2.03 5986718. 95 10072. 32 61. 12 335. 21 6603. 23 6667. 48 6527. 17 6716. 08 6570. 90 6233. 67 -2078.02 1.39 5986794. 26 Tie-In Survey 10167. 70 60. 66 335. 04 6649. 64 6713. 89 6610. 50 6799. 41 6653. 72 6309. 27 -2113.07 0.51 5986869. 29 Top Window (Inc only) 10217. 00 60. 80 335. 15 6673. 74 6737. 99 6653. 51 6842. 41 6696. 46 6348. 28 -2131.18 0.34 5986908. 00 Base Window (Inc only) 10229. 00 62, 60 334. 40 6679. 43 6743. 68 6664. 07 6852. 98 6706. 95 6357. 83 -2135.68 15.98 5986917. 48 End Mill (Inc Only) 10243. 00 62. 60 334. 40 6685. 87 6750. 12 6676. 50 6865. 41 6719. 29 6369. 04 -2141.05 0.00 5986928. 60 Blind (Inc Only) 10268. 64 69. 85 334. 40 6696. 20 6760. 45 6699. 95 6888. 86 6742. 56 6390. 19 -2151.18 28.28 5986949. 58 Blind (Inc Only) 10300. 73 77. 78 332. 84 6705. 14 6769. 39 6730. 73 6919. 65 6773. 07 6417. 77 -2164.87 25.15 5986976. 94 Tie-In Survey 10332. 34 85. 77 332. 90 6709. 66 6773. 91 6761. 97 6950. 91 6803. 99 6445. 59 -2179.13 25.28 5987004. 53 MWD+IFR+MS 10363. 74 89. 25 331. 52 6711. 02 6775. 27 6793. 30 6982. 27 6834. 96 6473. 34 -2193.75 11.92 5987032. 04 10396. 52 89. 01 332. 47 6711. 52 6775. 77 6826. 03 7015. 05 6867. 31 6502. 28 -2209.14 2.99 5987060. 73 10428. 15 87. 64 330. 34 6712. 44 6776. 69 6857. 59 7046. 67 6898. 46 6530. 03 -2224.27 8.00 5987088. 24 10459. 24 87. 40 327. 41 6713. 79 6778. 04 6888. 47 7077. 73 6928. 81 6556. 62 -2240.33 9.45 5987114. 57 10489. 52 87. 43 324. 06 6715. 16 6779. 41 6918. 33 7107. 98 6957. 97 6581. 62 -2257.36 11.05 5987139. 29 10520. 73 87. 81 321. 77 6716. 45 6780. 70 6948. 82 7139. 16 6987. 60 6606. 49 -2276.16 7.43 5987163. 86 10553. 24 87. 81 320. 52 6717. 69 6781. 94 6980. 37 7171. 65 7018. 17 6631. 79 -2296.54 3.84 5987188. 83 10585. 62 89. 21 318. 38 6718. 54 6782. 79 7011. 56 7204. 01 7048. 30 6656. 38 -2317.58 7.90 5987213. 08 10617. 49 90. 72 314. 46 6718. 56 6782. 81 7041. 77 7235. 88 7077. 34 6679. 46 -2339.54 13.18 5987235. 81 10649. 95 90. 93 313. 21 6718. 09 6782. 34 7072. 05 7268. 34 7106. 31 6701. 94 -2362.96 3.90 5987257. 91 10681. 58 90. 86 314. 76 6717. 59 6781. 84 7101. 58 7299. 97 7134. 60 6723. 90 -2385.71 4.90 5987279. 51 10713. 59 91. 03 311. 11 6717. 07 6781. 32 7131. 24 7331. 97 7162. 99 6745. 70 -2409.14 11.41 5987300. 93 10746. 05 90. 62 310. 68 6716. 60 6780. 85 7160. 88 7364. 43 7191. 27 6766. 95 -2433.67 1.83 5987321. 78 10777, 14 91. 20 308. 15 6716. 10 6780. 35 7188. 93 7395. 51 7217. 99 6786. 69 -2457.69 8.35 5987341. 13 10808. 55 90. 34 308. 04 6715. 68 6779. 93 7216. 95 7426. 92 7244. 64 6806. 06 -2482.40 2.76 5987360. 11 10840. 92 89. 59 306. 53 6715. 70 6779. 95 7245. 62 7459. 29 7271. 91 6825. 67 -2508.16 5.21 5987379. 31 10872. 81 89. 56 304. 69 6715. 94 6780. 19 7273. 41 7491. 18 7298. 30 6844. 24 -2534.08 5.77 5987397. 46 10905. 04 89. 66 303. 98 6716. 16 6780. 41 7301. 15 7523. 41 7324. 61 6862. 42 -2560.70 2.22 5987415. 21 10937. 38 89. 59 301. 78 6716. 37 6780. 62 7328. 55 7555. 75 7350. 58 6879. 97 -2587.85 6.81 5987432. 33 10966. 77 90. 17 299. 42 6716. 43 6780. 68 7352. 82 7585. 14 7373. 51 6894. 93 -2613.15 8.27 5987446. 89 11000. 39 90. 62 297. 26 6716. 20 6780. 45 7379. 80 7618. 76 7398. 95 6910. 89 -2642.74 6.56 5987462. 37 11032. 86 90. 38 295. 73 6715 .92 6780. 17 7405. 23 7651. 23 7422. 89 6925. 37 -2671.79 4.77 5987476. 39 11062. 39 90. 41 297. 23 6715. 71 6779. 96 7428. 35 7680. 76 7444. 71 6938. 54 -2698.23 5.08 5987489. 14 11093. 62 90. 24 295. 63 6715. 54 6779. 79 7452. 78 7711. 98 7467. 83 6952. 44 -2726.19 5.15 5987502. 59 11126. 34 90. 24 295. 78 6715. 40 6779. 65 7478. 12 7744. 70 7491. 84 6966. 63 -2755.67 0.46 5987516. 31 11156. 57 90. 10 295. 91 6715. 31 6779. 56 7501. 58 7774. 93 7514. 13 6979. 81 -2782.88 0.63 5987529. 05 11187. 68 89. 21 296. 20 6715. 50 6779. 75 7525. 79 7806. 04 7537. 20 6993. 48 -2810.82 3.01 5987542. 27 blbyb/.1V IV /V ZZ Ib.J231 VY 14yLb/./Z4 616944.75 N 70 22 17.143 W 149 2 58.342 616919.09 N 70 22 17.885 W 149 2 59.059 616888.21 N 70 22 18.624 W 149 2 59.928 616855.73 N 70 22 19.362 W 149 3 0.844 616822.98 N 70 22 20.110 W 149 3 1.767 616789.22 N 70 22 20.850 W 149 3 2.721 616753.37 N 70 22 21.596 W 149 3 3.735 616717.13 616698.40 616693.75 616688.20 616677.74 616663.61 616648.92 616633.86 616618.01 616602.44 616585.97 616568.55 616549.36 616528.58 616507.15 616484.83 616461.06 616437.96 616414.19 616389.33 N 70 22 22.340 N 70 22 22.723 N 70 22 22.817 N 70 22 22.928 N 70 22 23.136 N 70 22 23.407 N 70 22 23.680 N 70 22 23.953 N 70 22 24.238 N 70 22 24.511 N 70 22 24.772 N 70 22 25.018 N 70 22 25.263 N 70 22 25.511 N 70 22 25.753 N 70 22 25.980 N 70 22 26.201 N 70 22 26.417 N 70 22 26.631 N 70 22 26.840 W 149 3 4.762 W 149 3 5.292 W 149 4 W 149 1 W 149 3 5.877 W 149 3 6.278 W 149 3 6.695 W 149 3 7.123 W 149 3 7.574 W 149 3 8.017 W 149 3 8.487 W 149 3 8.985 W 149 3 9.536 W 149 3 10.132 W 149 3 10.748 W 149311.391 W 149 3 12.076 W 149 3 12.742 W 149 3 13.428 W 149 3 14.146 616365.Oi 616339.99 616313.93 616287.71 616260.82 616233.39 616207.86 616178.02 616148.74 616122.11 616093.93 616064.23 616036.82 616008.66 N 70 22 27.034 N 70 22 27.225 N 70 22 27.417 N 70 22 27.600 N 70 22 27.779 N 70 22 27.951 N 70 22 28.098 N 70 22 28.255 N 70 22 28.397 N 70 22 28.527 N 70 22 28.663 N 70 22 28.803 N 70 22 28.932 N 70 22 29.067 W 149 3~8 W 14931 72 W 149316.326 W 149 3 17.084 W 149 317.863 W 149 3 18.658 W 149 3 19.398 W 149 3 20.264 W 149321.114 W 149 3 21.888 W 149 3 22.706 W 149 3 23.569 W 149 3 24.365 W 149 3 25.1 B3 SurveyEditor Ver SP 1.0 Bld( doc40x_56) S-122\S-122\S-122\S-122 Generated 9/19/2005 12:00 PM Page 4 of 5 ~. Comments Measured Inclination Azimuth SutrSea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de tt ft ft ft ft ft ft de 100 ft ftUS ftUS 11 LL1. "G23 i5y.L7 "Lyb. 525 b/lb.yb b/25V. L7 /b51.2525 /L33y.b4 /5bL.1L 11251. 49 89.04 296. 44 6716.42 6780. 67 7575.37 7869.85 7584.62 f 1284. 22 88.60 295. 75 6717.10 6781. 35 7600.85 7902.57 7609.09 11316. 94 89.25 295. 01 6717.71 6781. 96 7626.07 7935.28 7633.34 11347. 80 91.48 293. 98 6717.51 6781. 76 7649.55 7966.14 7655.96 11380. 58 92.09 294. 28 6716.49 6780. 74 7674.34 7998.91 7679.89 11411 .97 92.30 292.41 6715.29 6779.54 7697.80 8030.27 7702.56 11444 .26 93.02 291.92 6713.79 6778.04 7721.47 8062.53 7725.48 11476 .39 93.64 293.42 6711.92 6776.17 7745.20 8094.60 7748.54 11508 .80 93.40 294.08 6709.93 6774.18 7769.54 8126.95 7772.27 11541 .44 92.44 292.56 6708.27 6772.52 7793.90 8159.55 7796.09 /VV23.lb -L2f41.V5 7021.39 -2868.20 7035.78 -2897.58 7049.81 -2927.14 7062.60 -2955.22 7075.99 -2985.12 7088.42 -3013.92 7100.59 -3043.79 7112.95 -3073.39 7125.98 -3103.00 7138.89 -3132.93 1.255 b`J23/bbb.4b 2.90 5987569.27 2.50 5987583.20 3.01 5987596.75 7.96 5987609.09 2.07 5987622.01 5.99 5987633.98 2.70 5987645.67 5.04 5987657.56 2.16 5987670.11 5.50 5987682.54 blby/25.21 IV /V ZZ L`J.ZI1 VV 14`J 3 Zb.Vb25 615950.86 N 70 22 29.341 W 149 3 26.862 615921.25 N 70 22 29.482 W 149 3 27.722 615891.48 N 70 22 29.620 W 149 3 28.587 615863.20 N 70 22 29.746 W 149 3 29.409 615833.09 N 70 22 29.878 W 149 3 30.284 615804.10 N 70 22 30.000 W 149 3 31.127 615774.04 N 70 22 30.119 W 149 3 32.001 615744.26 N 70 22 30.241 W 149 3 32.867 615714.45 N 70 22 30.369 W 149 3 33.733 615684.32 N 70 22 30.496 W 149 3~9 615654.61 N 70 22 30.613 W 149 3 35.473 615624.55 N 70 22 30.731 W 149 3 36.348 615594.64 N 70 22 30.856 W 149 3 37.217 615566.01 N 70 22 30.977 W 149 3 38.050 615535.99 N 70 22 31.106 W 149 3 38.922 615506.32 N 70 22 31.232 W 149 3 39.785 615477.07 N 70 22 31.356 W 149 3 40.635 615447.89 N 70 22 31.484 W 149 3 41.483 615418.21 N 70 22 31.615 W 149 3 42.346 615389.16 N 70 22 31.739 W 149 3 43.191 615359.34 N 70 22 31.861 W 149 3 44.058 615330.10 N 70 22 31.980 W 149 3 44.908 615300.53 N 70 22 32.097 W 149 3 45.768 615270.52 N 70 22 32.215 W 149 3 46.641 615241.31 N 70 22 32.330 W 149 3 47.490 615210.15 N 70 22 32.453 W 149 3 48.397 615179.96 N 70 22 32.575 W 149 3~5 615150.81 N 70 22 32.695 W 149 3 2 6i 5100.1 9 - N 70 22 32.906 W 149 3 5 .594 11573.31 91.65 291.50 6707.13 6771.38 7817.23 8191.40 7818.92 7150.83 -3162.45 4.15 5987694.01 11605.54 92.40 292.45 6706.00 6770.25 7840.79 8223.61 7842.06 7162.89 -3192.32 3.75 5987705.59 11637.8$ 93.02 293.66 6704.47 6768.72 7864.84 8255.91 7865.74 7175.54 -3222.05 4.20 5987717.77 11668.93 92.30 293.42 6703.02 6767.27 7888.10 8286.93 7888.72 7187.92 -3250.48 2.44 5987729.70 11701.53 92.61 294.04 6701.63 6765.88 7912.60 8319.50 7912.98 7201.03 -3280.30 2.12 5987742.33 11733.72 93.19 293,00 6700.00 6764.25 7936.70 8351.65 7936.90 7213.86 -3309.77 3.70 5987754.69 11765.45 94.12 293.87 6697.98 6762.23 7960.41 8383.31 7960.49 7226.45 -3338.83 4.01 5987766.82 11797.29 93.84 294.48 6695.77 6760.02 7984.47 8415.07 7984.48 7239.46 -3367.80 2.10 5987779.36 11829.73 93.71 294.34 6693.63 6757.88 8009.07 8447.44 8009.07 7252.84 -3397.28 0.59 5987792.27 11861.30 93.54 292.94 6691.64 6755.89 8032.73 8478.95 8032.78 7265.47 -3426.14 4.46 5987804.44 11893.48 93.57 292.51 6689.64 6753.89 8056.51 8511.07 8056.67 7277.88 -3455.77 1.34 5987816.38 11925.00 93.36 292.64 6687.73 6751.98 8079.76 8542.53 8080.06 7289.96 -3484.82 0.78 5987827.99 11956.79 93.16 291.71 6685.93 6750.18 8103.05 8574.27 8103.58 7301.94 -3514.21 2.99 5987839.50 11989.01 94.22 292.14 6683.85 6748.10 8126.56 8606.42 8127.36 7313.94 -3544.04 3.55 5987851.03 12020.40 94.60 291.80 6681.44 6745.69 8149.46 8637.72 8150.58 7325.65 -3573.06 1.62 5987862.28 12053.91 94.74 292.17 6678.71 6742.96 8173.90 8671.12 8175.42 7338.15 -3604.03 1.18 5987874.29 12086.47 94.91 292.59 6675.97 6740.22 8197.79 8703.56 8199.76 7350.51 -3634.03 1.39 5987886.16 Last MWD+IFR+MS 12118.03 95.43 293.13 6673.13 6737.38 8221.12 8734.99 8223.57 7362.72 -3662.99 2.37 5987897.91 TD (Projected) - 12173.00 96.24 293.13 6667.54 6731.79 - 8261.87 8789.68 8265.28 7384.20 -3713.28 1.47 - 5987918.59 Survey Type: Definitive Survey NOTES: GYD GC SS - (Gyrodata -gyro single shots --Gyrodata gy ro orientatio n surveys. Not to be run above 70 degrees incli nation. ) MWD +IFR + MS - (In-field referenced MWD with mull-station analysis and correction applied in post-processing. Assumes a BHA sag correction is applied to enhance inclination accuracy. ) Legal Description: Northing (Y) [ftUS] Easting (X) [ftUS] Surface : 4391 FSL 4500 FEL S35 T12N R12E UM 5980594.90 6i 8929.91 BHL : 1214 FSL 2923 FEL S22 T12N R12E UM 5987918.59 615100.19 SurveyEditor Ver SP 1.0 Bld( doc40x_56) S-122\S-122\S-122\S-122 Generated 9/19/2005 12:00 PM Page 5 of 5 .~-122 Actual completion • 13-3/8", 68.0#, L- 532 80, BTC, 2 9 5/8", 40.0#, L-80, BTC, btm 4 jts 40# 3, 658 K-55 BTC 4 1/2", 12.6#, L-80, IBT-M tubing 4,806 Baker 7" X 3 1 /2" 9, 920 Premier Packer 3 1/2" 9.2#, L 80, 9,815 IBT tbg Baker HMC liner hngr, ZXP pkr, w / 9, 973 TBS Baker Whip stock, (Top of w indow) 10,217 HES 7" Ezsv 10,233 7", 26.0#, L-80, 10,701 BTC-M = 3.81 TREE= 4 1/16" CM! WELLHEAD= FMC ACTUATOR= LEO KB. ELEV = 64.20' AMSL CB. ELEV = 35.70' AMSL KOP = 300' Max Angle = 99° @ 11,200' Datum MD = 12,257 Datum TVD = 6,814' Mit~im~m ID = 2.813" @9858,9882,9948,9969 ND GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 9797 6530 59 MMG Dum RK 2 8093 5600 56 MMG Dum RK 3 7077 5000 55 MMG Dum RK 4 4880 3800 54 MMG DCR RK AN~..EATTCP~ 60.8 degree I~bte: lamer to Roduction CB for historical perF data SQE SFF IMl3~/AL Opn/Sgz l]4ZE 6 1022010250 open 08/105 6 10300-10440 open 08<19~05 6 1050010550 open OEY19>•06 6 10600-10650 open 0~19r05 6 10700-10750 open 08/19/05 6 10890-11070 open 08/19'05 6 1112011270 open 019`05 6 11350-11400 open 019/05 6 1145011550 open 08/19'05 6 1160011750 open 08/19105 6 1180012030 open 08/19/05 9,856 Baker CMD Sliding Sleeve; I.D. = 2.813" 9,880 HES 3 1/2"'X' nipple; I.D. = 2.813" 9,900 HES 3 1/2" BHG w/ I Wire to Surface ~gl:~ I$31/2"X rim I.Q =2813' 9,967 HES 3 1l2" 'X' nipple; I.D. = 2.813" 10,839 Pup W/'RA' Tag 11,419 Pup W/'RA' Tag 0 0 PBTD 12,039 4 1i2", 11.6 #, L-80 LT&C liner 12,082 DATE REV BY COMMENTS DATE REV BY COMMENTS 08/21/05 LV Actual Completion PRUDNOE BAY UNIT WELL: S-122 PERMff No: 205-081 AF1 No: 50-029-23265 BP Exploration (Alaska) sJ C? SCHLUMBERGER Survey report Client .................... BP Exploration (Alaska) Inc. Field ..................... Aurora Well ...................... 5-122PB1 API number ...............: 50-029-23265-70 Engineer .................. S. Moy RIG :...................... NABORS 7ES 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 Ta11y 35.70 ft N/A Top Drive ft 64.25 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: 334.95 degrees [{c)2005 IDEAL ID9_1C_02] 9-Aug-2005 16:29:22 Page 1 of 6 Spud date ................. 30-Jul-05 Last survey date.........: 09-Aug-05 Total accepted surveys...: 123 MD of first survey.......: 0.00 ft MD of last survey........: 10731.00 ft ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2004 Magnetic date ............. 29-Jul-2005 Magnetic field strength..: 1152.68 HCNT Magnetic dec (+E/W-).....: 24.52 degrees Magnetic dip .............. 80.85 degrees ----- MWD survey Reference Reference G ............... Reference H ............... Reference Dip ............. Tolerance of G............ Tolerance of H............ Tolerance of Dip.......... Criteria --------- 1002.68 meal 1152.68 HCNT 80.85 degrees (+/-) 2.50 meal (+/-) 6.00 HCNT (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 24.52 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 24.52 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 • SCHLUMBERGER Survey Report 9-Aug-2005 16:29:22 Page 2 of 6 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # .depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP None 2 76.00 0.46 357.51 76.00 76.00 0.28 0.30 -0.01 0.31 357.51 0.61 GYR None 3 100.00 0.35 24.42 24.00 100.00 0.42 0.47 0.01 0.47 1.58 0.90 GYR None 4 198.00 0.14 17.76 98.00 198.00 0.70 0.85 0.17 0.87 11.46 0.22 GYR None 5 250.00 0.82 128.20 52.00 250.00 0.42 0.68 0.48 0.84 35.31 1.69 GYR None 6 300.00 1.38 131.84 50.00 299.99 -0.46 0.06 1.21 1.22 87.08 1.13 GYR None 7 349.00 2.46 116.46 49.00 348.96 -1.82 -0.80 2.60 2.72 107.14 2.42 GYR None 8 438.00 4.60 109.24 89.00 437.78 -5.81 -2.83 7.68 8.18 110.22 2.45 GYR None 9 500.00 4.50 121.68 62.00 499.59 -9.58 -4.92 12.09 13.06 112.16 1.60 GYR None 10 550.00 3.76 126.03 50.00 549.46 -12.66 -6.92 15.09 16.60 114.63 1.61 GYR None 11 650.00 2.62 149.64 100.00 649.3.1 -17.80 -10.82 18.90 21.77 119.80 1.72 GYR None 12 708.00 2.61 158.31 58.00 707.25 -20.44 -13.19 20.05 24.00 123.34 0.68 GYR None 13 800.00 2.20 159.68 92.00 799.17 -24.29 -16.79 21.44 27.23 128.07 0.45 GYR None 14 893.00 2.38 160.82 93.00 892.09 -27.99 -20.29 22.70 30.44 131.80 0.20 GYR None 15 925.00 2.29 157.96 32.00 924.07 -29.29 -21.51 23.15 31.60 132.89 0.46 GYR None 16 1000.00 1.65 172.65 75.00 999.02 -31.82 -23.97 23.85 33.82 135.14 1.08 GYR None 17 1079.00 1.59 290.46 79.00 1078.01 -32.12 -24.72 22.97 33.74 137.09 3.51 GYR None 18 1100.00 1.85 294.16 21.00 1099.00 -31.65 -24.48 22.39 33.17 137.55 1.35 GYR None 19 1200.00 2.59 300.25 100.00 1198.92 -28.57 -22.68 18.97 29.56 140.09 0.78 GYR None 20 1250.00 2.69 299.72 50.00 1248.87 -26.69 -21.53 16.97 27.41 141.75 0.21 GYR None 21 1300.00 3.79 296.81 50.00 1298.79 -24.43 -20.20 14.48 24.85 144.37 2.22 GYR None 22 1350.00 5.35 295.83 50.00 1348.63 -21.32 -18.44 10.90 21.42 149.40 3.12 GYR None 23 1400.00 6.74 295.32 50.00 1398.35 -17.25 -16.17 6.15 17.30 159.16 2.78 GYR None 24 1450.00 9.86 294.86 50.00 1447.82 -11.72 -13.11 -0.39 13.12 181.68 6.24 GYR None 25 1500.00 11.78 293.85 50.00 1496.93 -4.59 -9.25 -8.94 12.86 224.03 3.86 GYR None 26 1550.00 12.79 294.19 50.00 1545.78 3.45 -4.92 -18.66 19.29 255.24 2.03 GYR None 27 1591.98 13.70 289.72 41.98 1586.64 10.47 -1.33 -27.57 27.61 267.23 3.26 MWD IFR MS 28 1686.98 17.48 286.46 95.00 1678.13 27.85 6.51 -51.86 52.26 277.15 4.08 MWD IFR MS 29 1782.38 19.02 296.93 95.40 1768.76 49.60 17.61 -79.47 81.39 282.50 3.79 MWD IFR MS 30 1877.83 22.05 306.79 95.45 1858.16 77.67 35.39 -107.70 113.36 288.19 4.81 MWD IFR MS [(c)2005 IDEAL ID9_1C_02] SCHLUMBERGER Survey Report 9-Aug-2005 16:29:22 Page 3 of 6 --- --- 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 -- -- - 1972.81 --- -- 23.31 ------- 311.47 ------ 94.98 -------- 1945.80 -------- 110.62 ------- 58.52 --------- -136.06 ------- 148.11 -------- 293.27 ----- 2.32 ----- MWD -- IFR ---- MS 32 2068.14 26.24 315.83 95.33 2032.35 147.85 86.13 -164.88 186.03 297.58 3.62 MWD IFR MS 33 2164.41 28.11 320.93 96.27 2118.01 189.97 119.01 -194.01 227.61 301.53 3.10 MWD ~ IFR _MS 34 2260.49 31.38 323.87 96.08 2201.42 236.49 156.80 -223.04 272.64 305.11 3.73 MWD ~ IFR MS 35 2355.35 31.69 328.13 94.86 2282.28 285.47 197.92 -250.76 319.46 308.28 2.37 MWD IFR MS 36 2451.14 34.18 332.79 95.79 2362.68 337.36 243.23 -276.36 368.15 311.35 3.71 MWD_ IFR _MS 37 2545.77 36.71 338.59 94.63 2439.79 392.18 293.22 -298.85 418.67 314.46 4.45 MWD_ IFR _MS 38 2641.35 37.93 343.54 95.58 2515.82 449.75 348.01 -317.60 471.15 317.62 3.39 MWD IFR MS 39 2737.32 40.82 347.09 95.97 2590.01 509.60 406.89 -332.97 525.76 320.71 3.82 MWD IFR MS ~ 40 2834.00 44.29 349.11 96.68 2661.22 573.24 470.86 -346.41 584.56 323.66 3.86 MWD IFR MS 41 2929.79 48.27 348.08 95.79 2727.41 640.51 538.70 -360.12 647.99 326.24 4.23 MWD IFR MS 42 3025.62 52.61 347.16 95.83 2788.43 712.58 610.84 -375.98 717.28 328.39 4.59 MWD IFR MS 43 3121.73 56.59 347.01 96.11 2844.09 789.15 687.19 -393.48 791.87 330.20 4.14 MWD IFR MS 44 3215.11 56.21 346.89 93.38 2895.76 865.23 762.95 -411.05 866.64 331.69 0.42 MWD IFR MS 45 3312.60 57.35 346.96 97.49 2949.17 945.01 842.40 -429.50 945.57 332.99 1.17 MWD IFR MS 46 3407.74 56.76 346.62 95.14 3000.91 1023.15 920.12 -447.74 1023.28 334.05 0.69 MWD IFR MS 47 3503.23 58.05 346.96 95.49 3052.35 1101.89 998.44 -466.12 1101.89 334.97 1.38 MWD IFR MS 48 3599.06 56.73 346.43 95.83 3104.00 1180.92 1077.00 -484.70 1181.04 335.77 1.45 MWD IFR MS 49 3753.15. 56.73 346.14 154.09 3188.53 1307.24 1202.16 -515.24 1307.92 336.80 0.16 MWD IFR MS 50 3850.14 58.63 344.67 96.99 3240.38 1387.84 1281.47 -535.90 1389.01 337.31 2.34 MWD IFR MS 51 3940.07 56.73 343.52 89.93 3288.46 1462.86 1354.55 -556.72 1464.50 337.66 2.37 MWD_ IFR_ MS 52 4041.51 57.32 343.24 101.44 3343.67 1547.04 1436.10 -581.06 1549.20 337.97 0.63 MWD IFR MS 53 4137.82 55.75 343.57 96.31 3396.78 1626.51 1513.09 -604.01 1629.19 338.24 1.66 MWD IFR MS 54 4239.59 55.12 343.37 101.77 3454.52 1709.39 1593.43 -627.85 1712.67 338.49 0.64 MWD IFR MS 55 4336.00 55.34 343.00 96.41 3509.50 1787.77 1669.24 -650.76 1791.61 338.70 0.39 MWD IFR MS 56 4431.67 55.86 342.64 95.67 3563.55 1865.96 1744.66 -674.08 1870.35 338.88 0.63 MWD IFR MS 57 4527.17 55.68 342.74 95.50 3617.27 1944.20 1820.04 -697.58 1949.14 339.03 0.21 MWD IFR MS 58 4622.73 53.35 344.12 95.56 3672.74 2021.16 1894.61 -719.78 2026.73 339.20 2.71 MWD IFR l MS 59 4718.75 53.53 343.18 96.02 3729.94 2097.40 1968.61 -741.49 2103.63 339.36 0.81 MWD IFR MS 60 4814.00 55.69 344.25 95.25 3785.10 2174.13 2043.15 -763.25 2181.05 339.52 2.45 MWD IFR MS [(c)2005 IDEAL ID9_1C_02] SCHLUMBERGER Survey Report 9-Aug-2005 16:29:22 Page 4 of 6 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +El~- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type {deg) 61 4909.67 54.87 344.63 95.67 3839.59 2251.69 2118.90 -784.35 2259.41 339.69 0.92 MWD IFR MS 62 5005.57 56.47 343.74 95.90 3893.67 2329.86 2195.09 -805.93 2338.36 339.84 1.84 MWD IFR MS 63 5100.25 56.74 343.76 94.68 3945.78 2407.97 2270.98 -828.05 2417.23 339.97 0.29 MWD ` IFR _MS 64 5196.07 55.02 344.88 95.82 3999.53 2486.24 2347.35 -849.50 2496.33 340.10 2.04 MWD IFR MS 65 5291.98 56.18 346.21 95.91 4053.72 2564.02 2423.97 -869.25 2575.12 340.27 1.66 MWD IFR MS 66 5387.00 57.99 346.00 95.02 4105.35 2642.28 2501.40 -888.40 2654.48 340.45 1.91 MWD_ IFR _MS 67 5482.93 58.10 346.33 95.93 4156.12 2722.11 2580.44 -907.87 2735.48 340.62 0.31 MWD_ IFR _MS 68 5578.41 58.15 346.17 95.48 4206.54 2801.62 2659.19 -927.14 2816.18 340.78 0.15 MWD IFR MS 69 5674.01 57.80 346.96 95.60 4257.23 2881.02 2738.03 -945.97 2896.83 340.94 0.79 MWD IFR MS 70 5768.78 57.50 346.99 94.77 4307.95 2959.32 2816.03 -964.01 2976.46 341.10 0.32 MWD IFR MS 71 5863.88 56.93 347.26 95.10 4359.44 3037.47 2893.97 -981.83 3055.98 341.26 0.65 MWD IFR MS 72 5959.54 57.71 345.07 95.6.6 4411.10 3116.44 2972.14 -1001.09 313.6.21 341.39 2.09 MWD IFR MS 73 6056.21 57.69 342.53 96.67 4462.76 3197.17 3050.60 -1023.88 3217.84 341.45 2.22 MWD IFR MS 74 6152.03 57.99 342.96 95.82 4513.76 3277.54 3128.06 -1047.94 3298.93 341.48 0.49 MWD IFR MS 75 6247.99 57.75 343.61 95.96 4564.80 3357.95 3205.89 -1071.31 3380.16 341.52 0.63 MWD IFR MS 76 6341.49 58.20 343.89 93.50 4614.38 3436.28 3282.00 -1093.50 3459.37 341.57 0.54 MWD IFR MS 77 6438.88 57.50 343.34 97.39 4666.20 3517.80 3361.10 -1116.75 3541.77 341.62 0.86 MWD IFR MS 78 6534.49 58.21 341.51 95.61 4717.08 3598.06 3438.27 -1141.20 3622.71 341.64 1.78 MWD IFR MS 79 6631.65 56.35 340.49 97.16 4769.59 3679.34 3515.56 -1167.81 3704.44 341.62 2.11 MWD ~ IFR_ MS 80 6725.69 55.29 339.61 94.04 4822.43 3756.82 3588.68 -1194.35 3782.21 341.59 1.37 MWD IFR MS 81 6821.40 56.39 339.93 95.71 4876.17 3835.74 3662.99 -1221.73 3861.37 341.55 1.18 MWD_ IFR_ MS 82 6916.97 55.99 340.16 95.57 4929.35 3914.83 3737.64 -1248.83 3940.75 341.52 0.46 MWD IFR MS 83 7013.59 55.96 339.95 96.62 4983.41 3994.59 3812.91 -1276.15 4020.80 341.50 0.18 MWD IFR MS 84 7109.04 55.85 339.98 95.45 5036.92 4073.33 3887.17 -1303.23 4099.81 341.47 0.12 MWD IFR MS 85 7204.60 56.13 340.11 95.56 5090.37 4152.23 3961.63 -1330.26 4179.00 341.44 0.31 MWD IFR MS 86 7300.13 55.13 342.26 95.53 5144.30 4230.61 4036.25 -1355.70 4257.85 341.43 2.13 MWD IFR MS 87 7396.28 54.98 341.89 96.15 5199.37 4308.82 4111.24 -1379.95 4336.66 341.45 0.35 MWD IFR MS 88 7492.00 54.69 342.49 95.72 5254.50 4386.44 4185.74 -1403.89 4414.90 341.46 0.60 MWD IFR MS 89 7588.00 54.88 342.28 96.00 5309.86 4464.22 4260.50 -1427.62 4493.32 341.47 0.27 MWD IFR MS 90 7683.71 54.68 342.44 95.71 5365.06 4541.75 4335.01 -1451.32 4571.50 341.49 0.25 MWD IFR MS [(c)2005 IDEAL ID9_1C_02] SCHLUMBERGER Survey Report 9-Aug-2005 16:29:22 Page 5 of 6 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type .(deg) 91 7778.67 54.87 342.01 94.96 5419.83 4618.70 4408.88 -1475.00 4649.07 341.50 0.42 MWD IFR MS 92 7874.27 56.76 341.68 95.60 5473.54 4697.21 4484.02 -1499.64 4728.14 341.51 2.00 MWD IFR MS 93 7969.63 57.27 341.59 95.36 5525.46 4776.65 4559.93 -1524.84 4808.13 341.51 0.54 MWD IFR MS 94 8064.67 56.94 341.15 95.04 5577.07 4855.95 4635.55 -1550.34 4887.93 341.51 0.52 MWD IFR MS 95 8160.40 57.13 342.34 95.73 5629.17 4935.70 4711.83 -1575.49 4968.25 341.51 1.06 MWD IFR MS 96 8256.27 56.63 341.90 95.87 5681.55 5015.37 4788.24 -1600.14 5048.54 341.52 0.65 MWD_ IFR _MS 97 8351.81 56.38 341.80 95.54 5734.27 5094.47 4863.95 -1624.96 5128.21 341.53 0.28 MWD_ IFR _MS 98 8447.56 57.52 343.20 95.75 5786.49 5174.02 4940.49 -1649.09 5208.45 341.54 1.71 MWD IFR MS 99 8542.87 57.27 343.33 95.31 5837.85 5253.47 5017.38 -1672.21 5288.71 341.57 0.29 MWD IFR MS 100 8637.10 56.95 343.74 94.23 5889.02 5331.71 5093.26 -1694.64 5367.79 341.60 0.50 MWD IFR MS 101 8732.43 56.65 343.09 95.33 5941.22 5410.61 5169.71 -1717.40 5447.51 341.62 0.65 MWD IFR MS 102 8828.78 56.35 342.99 96.35 5994.40 5490.15 5246.56 -1740.84 5527.83 341.64 0.32 MWD IFR ~ MS 103 8925.20 55.53 342.89 96.42 6048.40 5569.25 5322.93 -1764.27 5607.69 341.66 0.85 MWD IFR MS 104 9020.82 57.12- 343.57 95.62 6101.42 5648.00 5399.12 -1787.23 5687.23 341.68 1.76 MWD IFR MS 105 9116.04 56.79 343.95 95.22 6153.34 5726.87 5475.75 -1809.55 5767.00 341.71 0.48 MWD IFR MS 106 9212.77 56.08 343.88 96.73 6206.82 5806.49 5553.19 -1831.88 5847.54 341.74 0.74 MWD IFR MS 107 9306.96 56.07 345.15 94.19 6259.39 5883.55 5628.51 -1852.75 5925.61 341.78 1.12 MWD IFR MS 108 9400.78 55.22 345.05 93.82 6312.33 5959.80 5703.36 -1872.66 6002.93 341.82 0.91 MWD IFR MS 109 9498.81 54.64 344.41 98.03 6368.66 6038.86 5780.76 -1893.79 6083.06 341.86 0.80 MWD IFR MS 110 9594.62 57.28 339.74 95.81 6422.31 6117.60 5856.24 -1918.26 6162.41 341.86 4.89 MWD IFR MS 111 9690.03 58.58 337.19 95.41 6472.97 6198.29 5931.43 -1947.95 6243.11 341.82 2.64 MWD_ IFR_ MS 112 9784.92 59.26 337.50 94.89 6521.96 6279.49 6006.43 -1979.25 6324.13 341.76 0.77 MWD IFR MS 113 9881.09 58.68 337.49 96.17 6571.53 6361.81 6082.56 -2010.79 6406.31 341.71 0.60 MWD IFR MS 114 9976.47 59.86 335.70 95.38 6620.27 6443.76 6157.79 -2043.36 6487.97 341.64 2.03 MWD IFR MS 115 10072.32 61.12 335.21 95.85 6667.48 6527.17 6233.67 -2078.02 6570.90 341.56 1.39 MWD IFR MS 116 10167.70 60.66 335.04 95.38 6713.88 6610.50 6309.27 -2113.07 6653.72 341.48 0.51 MWD IFR MS 117 10263.24 60.93 335.25 95.54 6760.50 6693.90 6384.94 -2148.12 6736.61 341.41 0.34 MWD IFR MS 118 10359.01 61.39 335.91 95.77 6806.70 6777.78 6461.32 -2182.80 6820.07 341.33 0.77 MWD IFR MS 119 10453.96 61.35 334.78 94.95 6852.19 6861.12 6537.07 -2217.57 6902.96 341.26 1.05 MWD IFR MS 120 10549.72 61.42 334.56 95.76 6898.06 6945.18 6613.05 -2253.53 6986.47 341.18 0.21 MWD IFR MS [(c)2005 IDEAL ID9_1C_02] i SCHLUMBERGER Survey Report 9-Aug-2005 16:29:22 Page 6 of 6 --- --- 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) ----- ------ --- 121 -------- 10644.34 ------ 61.40 ------- 334.60 ------ 94.62 -------- 6943.33 -------- 7028.26 ------- 6688.09 --------- -2289.20 -------- 7069.01 ------- 341.11 ----- 0.04 ----- ------ MWD IFR MS 122 10668.78 61.06 334.17 24.44 6955.10 7049.68 6707.40 -2298.46 7090.29 341.08 2.08 MWD IFR MS 123 10731.00 61.06 334.17 62.22 6985.21 7104.13 6756.41 -2322.18 7144.35 341.03 0.00 Projected to TD [(c)2005 IDEAL ID9_1C_02] SCHLUMBERGER Survey report Client .................... BP Exploration (Alaska) Inc. Field ..................... Aurora Well ...................... 5-122PB2 API number ................ 50-029-23265-71 Engineer .................. J. Davies Rig :...................... Nabors 7ES 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 35.70 ft N/A Top Drive 64.25 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: 334.95 degrees 15-Aug-2005 08:47:34 Page 1 of 6 Spud date ................. 30-Jul-2005 Last survey date.........: 15-Aug-05 Total accepted surveys...: 137 MD of first survey.......: 0.00 ft MD of last survey........: 10853.00 ft ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2004 Magnetic date ............: 29-Jul-2005 Magnetic field strength..: 1152.68 HCNT Magnetic dec (+E/W-).....: 24.52 degrees Magnetic dip .............: 80.85 degrees ----- MWD survey Reference Reference G ............... Reference H ............... Reference Dip ............. Tolerance of G............ Tolerance of H............ Tolerance of Dip.......... Criteria --------- 1002.68 meal 1152.68 HCNT 80.85 degrees (+/-) 2.50 meal (+/-) 6.00 HCNT (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 24.52 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 24.52 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 ., • [(c)2005 IDEAL ID9_1C_01.4] SCHLUMBERGER Survey Report 15- Aug-2005 08:47:34 Page 2 of 6 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) {deg} (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 ----- TIP ------ 2 76.00 0.46 357.51 76.00 76.00 0.28 0.30 -0.01 0.31 357.51 0.61 GYR 3 100.00 0.35 24.42 24.00 100.00 0.42 0.47 0.01 0.47 1.58 0.90 GYR 4 198.00 0.14 17.76 98.00 198.00 0.70 0.85 0.17 0.87 11.46 0.22 GYR 5 250.00 0.82 128.20 52.00 250.00 0.42 0.68 0.48 0.84 35.31 1.69 GYR 6 300.00 1.38 131.84 50.00 299.99 -0.46 0.06 1.21 1.22 87.08 1.13 GYR 7 349.00 2.46 116.46 49.00 348.96 -1.82 -0.80 2.60 2.72 107.14 2.42 GYR 8 438.00 4.60 109.24 89.00 437.78 -5.81 -2.83 7.68 8.18 110.22 2.45 GYR 9 500.00 4.50 121.68 62.00 499.59 -9.58 -4.92 12.09 13.06 112.16 1.60 GYR 10 550.00 3.76 126.03 50.00 549.46 -12.66 -6.92 15.09 16.60 114.63 1.61 GYR 11 650.00 2.62 149.64 100.00 649.31 -17.80 -10.82 18.90 21.77 119.80 1.72 GYR 12 708.00 2.61 158.31 58.00 707.25 -20.44 -13.19 20.05 24.00 123.34 0.68 GYR 13 800.00 2.20 159.68 92.00 799.17 -24.29 -16.79 21.44 27.23 128.07 0.45 GYR 14 893.00 2.38 160.82 93.00 892.09 -27.99 -20.29 22.70 30.44 131.80 0.20 GYR 15 925.00 2.29 157.96 32.00 924.07 -29.29 -21.51 23.15 31.60 132.89 0.46 GYR 16 1000.00 1.65 172.65 75.00 999.02 -31.82 -23.97 23.85 33.82 135.14 1.08 GYR 17 1079.00 1.59 290.46 79.00 1078.01 -32.12 -24.72 22.97 33.74 137.09 3.51 GYR 18 1100.00 1.85 294.16 21.00 1099.00 -31.65 -24.48 22.39 33.17 137.55 1.35 GYR 19 1200.00 2.59 300.25 100.00 1198.92 -28.57 -22.68 18.97 29.56 140.09 0.78 GYR 20 1250.00 2.69 299.72 50.00 1248.87 -26.69 -21.53 16.97 27.41 141.75 0.21 GYR 21 1300.00 3.79 296.81 50.00 1298.79 -24.43 -20.20 14.48 24.85 144.37 2.22 GYR 22 1350.00 5.35 295.83 50.00 1348.63 -21.32 -18.44 10.90 21:42 149.40 3.12 GYR 23 1400.00 6.74 295.32 50.00 1398.35 -17.25 -16.17 6.15 17.30 159.16 2.78 GYR 24 1450.00 9.86 294.86 50.00 1447.82 -11.72 -13.11 -0.39 13.12 181.68 6.24 GYR 25 1500.00 11.78 293.85 50.00 1496.93 -4.59 -9.25 -8.94 12.86 224.03 3.86 GYR 26 1550.00 12.79 294.19 50.00 1545.78 3.45 -4.92 -18.66 19.29 255.24 2.03 GYR 27 1591.98 13.70 289.72 41.98 1586.64 10.47 -1.33 -27.57 27.61 267.23 3.26 MWD IFR MS 28 1686.98 17.48 286.46 95.00 1678.13 27.85 6.51 -51.86 52.26 277.15 4.08 MWD IFR MS 29 1782.38 19.02 296.93 95.40 1768.76 49.60 17.61 -79.47 81.39 282.50 3.79 MWD IFR MS 30 1877.83 22.05 306.79 95.45 1858.16 77.67 35.39 -107.70 113.36 288.19 4.81 MWD IFR MS [(c)2005 IDEAL ID9_1C_01.4] SCHLUMBERGER Survey Report 15-Aug-2005 08:47:34 Page 3 of 6 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 1972.81 23.31 311.47 94.98 1945.80 110.62 58.52 -136.06 148.11 293.27 2.32 MWD IFR MS ' 32 2068.14 26.24 315.83 95.33 2032.35 147.85 86.13 -164.88 186.03 297.58 3.62 MWD IFR MS 33 2164.41 28.11 320.93 96.27 2118.01 189.97 119.01 -194.01 227.61 301.53 3.10 MWD IFR MS 34 2260.49 31.38 323.87 96.08 2201.42 236.49 156.80 -223.04 272.64 305.11 3.73 MWD IFR MS 35 2355.35 31.69 328.13 94.86 2282.28 285.47 197.92 -250.76 319.46 308.28 2.37 MWD IFR MS 36 2451.14 34.18 332.79 95.79 2362.68 337.36 243.23 -276.36 368.15 311.35 3.71 MWD_ IFR _MS 37 2545.77 36.71 338.59 94.63 2439.79 392.18 293.22 -298.85 418.67 314.46 4.45 MWD_ IFR _MS 38 2641.35 37.93 343.54 95.58 2515.82 449.75 348.01 -317.60 471.15 317.62 3.39 MWD IFR MS 39 2737.32 40.82 347.09 95.97 2590.01 509.60 406.89 -332.97 525.76 320.71 3.82 MWD IFR MS 40 2834.00 44.29 349.11 96.68 2661.22 573.24 470.86 -346.41 584.56 323.66 3.86 MWD IFR MS 41 2929.79 48.27 348.08 95.79 2727.41 640.51 538.70 -360.12 647.99 326.24 4.23 MWD IFR MS 42 3025.62 52.61 347.16 95.83 2788.43 712.58 610.84 -375.98 717.28 328.39 4.59 MWD IFR MS 43 3121.73 56.59 347.01 96.11 2844.09 789.15 687.19 -393.48 791.87 330.20 4.14 MWD IFR MS ` 44 3215.11 56.21 346.89 93.38 2895.76 865.23 762.95 -411.05 866.64 331.69 0.42 MWD IFR MS 45 3312.60 57.35 346.96 97.49 2949.17 945.01 842.40 -429.50 945.57 332.99 1.17 MWD IFR MS 46 3407.74 56.76 346.62 95.14 3000.91 1023.15 920.12 -447.74 1023.28 334.05 0.69 MWD IFR MS 47 3503.23 58.05 346.96 95.49 3052.35 1101.89 998.44 -466.12 1101.89 334.97 1.38 MWD IFR MS 48 3599.06 56.73 346.43 95.83 3104.00 1180.92 1077.00 -484.70 1181.04 335.77 1.45 MWD IFR MS ` 49 3753.15 56.73 346.14 154.09 3188.53 1307.24 1202.16 -515.24 1307.92 336.80 0.16 MWD IFR MS 50 3850.14 58.63 344.67 96.99 3240.38 1387.84 1281.47 -535.90 1389.01 337.31 2.34 MWD IFR MS 51 3940.07 56.73 343.52 89.93 3288.46 1462.86 1354.55 -556.72 1464.50 337.66 2.37 MWD_ IFR _MS 52 4041.51 57.32 343.24 101.44 3343.67 1547.04 1436.10 -581.06 1549.20 337.97 0.63 MWD IFR MS 53 4137.82 55.75 343.57 96.31 3396.78 1626.51 1513.09 -604.01 1629.19 338.24 1.66 MWD IFR MS 54 4239.59 55.12 343.37 101.77 3454.52 1709.39 1593.43 -627.85 1712.67 338.49 0.64 MWD IFR MS 55 4336.00 55.34 343.00 96.41 3509.50 1787.77 1669.24 -650.76 1791.61 338.70 0.39 MWD IFR MS 56 4431.67 55.86 342.64 95.67 3563.55 1865.96 1744.66 -674.08 1870.35 338.88 0.63 MWD IFR MS 57 4527.17 55.68 342.74 95.50 3617.27 1944.20 1820.04 -697.58 1949.14 339.03 0.21 MWD IFR MS 58 4622.73 53.35 344.12 95.56 3672.74 2021.16 1894.61 -719.78 2026.73 339.20 2.71 MWD IFR MS 59 4718.75 53.53 343.18 96.02 3729.94 2097.40 1968.61 -741.49 2103.63 339.36 0.81 MWD IFR MS 60 4814.00 55.69 344.25 95.25 3785.10 2174.13 2043.15 -763.25 2181.05 339.52 2.45 MWD IFR MS [(c)2005 IDEAL ID9_1C_01.4] SCHLUMBERGER Survey Report 15-Aug-2005 08:47:34 Page 4 of 6 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 4909.67 54.87 344.63 95.67 3839.59 2251.69 2118.90 -784.35 - 2259.41 - ------ 339.69 ----- 0.92 -- MWD --- IFR ------ MS 62 5005.57 56.47 343.74 95.90 3893.67 2329.86 2195.09 -805.93 2338.36 339.84 1.84 MWD IFR MS 63 5100.25 56.74 343.76 94.68 3945.78 2407.97 2270.98 -828.05 2417.23 339.97 0.29 MWD IFR MS 64 5196.07 55.02 344.88 95.82 3999.53 2486.24 2347.35 -849.50 2496.33 340.10 2.04 MWD IFR MS 65 5291.98 56.18 346.21 95.91 4053.72 2564.02 2423.97 -869.25 2575.12 340.27 1.66 MWD IFR MS 66 5387.00 57.99 346.00 95.02 4105.35 2642.28 2501.40 -888.40 2654.48 340.45 1.91 MWD _IFR _MS 67 5482.93 58.10 346.33 95.93 4156.12 2722.11 2580.44 -907.87 2735.48 340.62 0.31 MWD _IFR _MS 68 5578.41 58.15 346.17 95.48 4206.54 2801.62 2659.19 -927.14 2816.18 340.78 0.15 MWD IFR MS 69 5674.01 57.80 346.96 95.60 4257.23 2881.02 2738.03 -945.97 2896.83 340.94 0.79 MWD IFR MS 70 5768.78 57.50 346.99 94.77 4307.95 2959.32 2816.03 -964.01 2976.46 341.10 0.32 MWD IFR MS 71 5863.88 56.93 347.26 95.10 4359.44 3037.47 2893.97 -981.83 3055.98 341.26 0.65 MWD IFR MS 72 5959.54 57.71 345.07 95.66 4411.10 3116.44 2972.14 -1001.09 3136.21 341.39 2.09 MWD IFR MS 73 6056.21 57.69 342.53 96.67 4462.76 3197.17 3050.60 -1023.88 3217.84 341.45 2.22 MWD IFR MS 74 6152.03 57.99 342.96 95.82 4513.76 3277.54 3128.06 -1047.94 3298.93 341.4$ 0.49 MWD IFR MS 75 6247.99 57.75 343.61 95.96 4564.80 3357.95 3205.89 -1071.31 3380.16 341.52 0.63 MWD IFR MS 76 6341.49 58.20 343.89 93.50 4614.38 3436.28 3282.00 -1093.50 3459.37 341.57 0.54 MWD IFR MS 77 6438.88 57.50 343.34 97.39 4666.20 3517.80 3361.10 -1116.75 3541.77 341.62 0.86 MWD IFR MS 78 6534.49 58.21 341.51 95.61 4717.08 3598.06 3438.27 -1141.20 3622.71 341.64 1.78 MWD IFR MS 79 6631.65 56.35 340.49 97.16 4769.59 3679.34 3515.56 -1167.81 3704.44 341.62 2.11 MWD IFR MS 80 6725.69 55.29 339.61 94.04 4822.43 3756.82 3588.68 -1194.35 3782.21 341.59 1.37 MWD IFR MS 81 6821.40 56.39 339.93 95.71 4876.17 3835.74 3662.99 -1221.73 3$61.37 341.55 1.18 MWD_ IFR _MS 82 6916.97 55.99 340.16 95.57 4929.35 3914.83 3737.64 -1248.83 3940.75 341.52 0.46 MWD IFR MS 83 7013.59 55.96 339.95 96.62 4983.41 3994.59 3812.91 -1276.15 4020.80 341.50 0.18 MWD IFR MS 84 7109.04 55.85 339.98 95.45 5036.92 4073.33 3887.17 -1303.23 4099.81 341.47 0.12 MWD IFR MS 85 7204.60 56.13 340.11 95.56 5090.37 4152.23 3961.63 -1330.26 4179.00 341.44 0.31 MWD IFR MS 86 7300.13 55.13 342.26 95.53 5144.30 4230.61 4036.25 -1355.70 4257.85 341.43 2.13 MWD IFR MS 87 7396.28 54.98 341.89 96.15 5199.37 4308.82 4111.24 -1379.95 4336.66 341.45 0.35 MWD IFR MS 88 7492.00 54.69 342.49 95.72 5254.50 4386.44 4185.74 -1403.89 4414.90 341.46 0.60 MWD IFR MS 89 7588.00 54.88 342.28 96.00 5309.86 4464.22 4260.50 -1427.62 4493.32 341.47 0.27 MWD IFR MS 90 7683.71 54.68 342.44 95.71 5365.06 4541.75 4335.01 -1451.32 4571.50 341.49 0.25 MWD IFR MS [(c)2005 IDEAL ID9_1C_01.4] SCHLUMBERGER Survey Report 15-Aug-2005 08:47:34 Page 5 of 6 Seq Measured Incl Azimuth Course TVD Vertical Disp1 Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +EjW- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 91 7778.67 54.87 342.01 94.96 5419.83 4618.70 4408.88 -1475.00 4649.07 341.50 0.42 MWD IFR MS 92 7874.27 56.76 341.68 95.60 5473.54 4697.21 4484.02 -1499.64 4728.14 341.51 2.00 MWD IFR MS 93 7969.63 57.27 341.59 95.36 5525.46 4776.65 4559.93 -1524.84 4808.13 341.51 0.54 MWD IFR MS 94 8064.67 56.94 341.15 95.04 5577.07 4855.95 4635,55 -1550.34 4887.93 341.51 0.52 MWD IFR MS 95 8160.40 57.13 342.34 95.73 5629.17 4935.70 4711.83 -1575.49 4968.25 341.51 1.06 MWD IFR MS 96 8256.27 56.63 341.90 95.87 5681.55 5015.37 4788.24 -1600.14 5048.54 341.52 0.65 MWD _IFR _MS 97 8351.81 56.38 341.80 95.54 5734.27 5094.47 4863.95 -1624.96 5128.21 341.53 0.28 MWD _IFR _MS • 98 8447.56 57.52 343.20 95.75 5786.49 5174.02 4940.49 -1649.09 5208.45 341.54 1.71 MWD IFR MS 99 8542.87 57.27 343.33 95.31 5837.85 5253.47 5017.38 -1672.21 5288.71 341.57 0.29 MWD IFR MS 100 8637.10 56.95 343.74 94.23 5889.02 5331.71 5093.26 -1694.64 5367.79 341.60 0.50 MWD IFR MS 101 8732.43 56.65 343.09 95.33 5941.22 5410.61 5169.71 -1717.40 5447.51 341.62 0.65 MWD IFR MS 102 8828.78 56.35 342.99 96.35 5994.40 5490.15 5246.56 -1740.84 5527.83 341.64 0.32 MWD IFR MS 103 8925.20 55.53 342.89 96.42 6048.40 5569.25 5322.93 -1764.27 5607.69 341.66 0.85 MWD IFR MS 104 9020.82 57.12 343.57 95.62 6101.42 5648.00 5399.12 -1787.23 5687.23 341.68 1.76 MWD IFR MS 105 9116.04 56.79 343.95 95.22 6153.34 5726.87 5475.75 -1809.55 5767.00 341.71 0.48 MWD IFR MS 106 9212.77 56.08 343.88 96.73 6206.82 5806.49 5553.19 -1831.88 5847.54 341.74 0.74 MWD IFR MS 107 9306.96 56.07 345.15 94.19 6259.39 5883.55 5628.51 -1852.75 5925.61 341.78 1.12 MWD IFR MS 108 9400.78 55.22 345.05 93.82 6312.33 5959.80 5703.36 -1872.66 6002.93 341.82 0.91 MWD IFR MS 109 9498.81 54.64 344.41 98.03 6368.66 6038.86 5780.76 -1893.79 6083.06 341.86 0.80 MWD IFR MS 110 9594.62 57.28 339.74 95.81 6422.31 6117.60 5856.24 -1918.26 6162.41 341.86 4.89 MWD IFR MS 111 9690.03 58.58 337.19 95.41 6472.97 6198.29 5931.43 -1947.95 6243.11 341.82 2.64 MWD_ IFR _MS 112 9784.92 59.26 337.50 94.89 6521.96 6279.49 6006.43 -1979.25 6324.13 341.76 0.77 MWD IFR MS 113 9881.09 58.68 337.49 96.17 6571.53 6361.81 6082.56 -2010.79 6406.31 341.71 0.60 MWD IFR MS 114 9976.47 59.86 335.70 95.38 6620.27 6443.76 6157.79 -2043.36 6487.97 341.64 2.03 MWD IFR MS 115 10072.32 61.12 335.21 95.85 6667.48 6527.17 6233.67 -2078.02 6570.90 341.56 1.39 MWD IFR MS 116 10167.70 60.66 335.04 95.38 6713.88 6610.50 6309.27 -2113.07 6653.72 341.48 0.51 MWD IFR MS 117 10217.00 60.80 335.15 49.30 6737.99 6653.51 6348.27 -2131.18 6696.46 341.44 0.34 Top of Window 118 10229.00 62,60 334.40 12.00 6743.68 6664.07 6357.83 -2135.68 6706.95 341.43 15.98 Bottom of Window 119 10243.00 62.60 334.40 14.00 6750.12 6676.50 6369.04 -2141.05 6719.29 341.42 0.00 End of Mill Run 120 10268.64 69.85 334.40 25.64 6760.45 6699.95 6390.19 -2151.18 6742.56 341.39 28.28 Inclination Only [(c)2005 IDEAL ID9_1C_01.4] SCHLUMBERGER Survey Report 15-Aug-2005 08:47:34 Page 6 of 6 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) 121 10300.73 77.78 332.84 32.09 6769.39 6730.73 6417.77 -2164.87 6773.07 341.36 25.15 Inclina tion Only 122 10332.34 85.77 332.90 31.61 6773.91 6761.97 6445.59 -2179.13 6803.99 341.32 25.28 MWD IFR MS 123 10363.34 89.3$ 330.48 31.00 6775.22 6792.89 6472.85 -2193.81 6834.52 341.28 14.02 MWD IFR MS 124 10395.10 91.54 329.81 31.76 6774.96 6824.53 6500.39 -2209.62 6865.68 341.23 7.12 MWD IFR MS 125 10426.92 94.42 329.14 31.82 6773.31 6856.16 6527.76 -2225.76 6896.79 341.17 9.29 MWD IFR MS 126 10458.49 96.56 328.24 31.57 6770.29 6887.40 6554.61 -2242.09 6927.47 341.12 7.35 MWD IFR MS 127 10490.87 97.39 326.81 32.38 6766.36 6919.27 6581.73 -2259.35 6958.72 341.05 5.08 MWD_ IFR _MS 128 10521.85 96.42 321.63 30.98 6762.63 6949.47 6606.67 -2277.32 6988.15 340.98 16.89 MWD IFR MS 129 10554.31 96.14 318.59 32.46 6759.08 6980.66 6631.42 -2298.01 7018.30 340.89 9.35 MWD ~ IFR _MS 130 10586.26 96.01 316.01 31.95 6755.70 7010.93 6654.77 -2319.56 7047.43 340.78 8.04 MWD IFR MS 131 10617.72 94.70 314.37 31.46 6752.76 7040.41 6676.99 -2341.63 7075.69 340.67 6.65 MWD IFR MS 132 10649.67 93.19 314.45 31.95 6750.56 7070.25 6699.29 -2364.40 7104.29 340.56 4.73 MWD IFR MS 133 10682.45 91.23 317.39 32.78 6749.30 7101.21 6722.82 -2387.18 7134.07 340.45 10.77 MWD IFR MS 134 10714.16 90.00 316.30 31.71 6748.96 7131.35 6745.95 -2408.87 7163.13 340.35 5.18 MWD IFR MS 135 10746.75 89.96 315.81 32.59 6748.97 7162.19 6769.41 -2431.48 7192.85 340.24 1.51 MWD IFR MS 136 10777.91 91.02 313.23 31.16 6748.70 7191.38 6791.26 -2453.70 7220.93 340.14 8.95 MWD IFR MS Proj ection to Total De pth: 137 10853.00 87.60 310.00 75.09 6749.61 7260.30 6841.11 -2509.82 7286.97 339.85 6.26 Project ion to TD [(c)2005 IDEAL ID9_1C_01.4] • SCHLUMBERGER Survey report Client .................... BP Exploration (Alaska) Inc. Field ..................... Aurora Well ...................... 5-122PB3 API number ................ 50-029-23265-72 Engineer .................. J. Davies Rig :...................... Nabors 7ES 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 35.70 ft N/A Top Drive 64.25 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: 334.95 degrees 16-Aug-2005 01:10:00 Page 1 of 7 Spud date ................. 30-Jul-2005 Last survey date.........: 16-Aug-05 Total accepted surveys...: 157 MD of first survey........ 0.00 ft MD of last survey........: 11460.00 ft ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2004 Magnetic date ............: 29-Jul-2005 Magnetic field strength..: 1152.68 HCNT Magnetic dec (+E/W-).....: 24.52 degrees Magnetic dip .............. 80.85 degrees ----- MWD survey Reference Reference G ............... Reference H ............... Reference Dip ............. Tolerance of G............ Tolerance of H............ Tolerance of Dip.......... Criteria --------- 1002.68 meal 1152.68 HCNT 80.85 degrees (+/-) 2.50 meal (+/-) 6.00 HCNT (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 24.52 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 24.52 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 • [(c)2005 IDEAL ID9_1C_01.4] SCHLUMBERGER Survey Report 16- Aug-2005 01:10:00 Page 2 of 7 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP 2 76.00 0.46 357.51 76.00 76.00 0.28 0.30 -0.01 0.31 357.51 0.61 GYR 3 100.00 0.35 24.42 24.00 100.00 0.42 0.47 0.01 0.47 1.58 0.90 GYR 4 198.00 0.14 17.76 98.00 198.00 0.70 0.85 0.17 0.87 11.46 0.22 GYR 5 250.00 0.82 128.20 52.00 250.00 0.42 0.68 0.48 0.84 35.31 1.69 GYR 6 300.00 1.38 131.84 50.00 299.99 -0.46 0.06 1.21 1.22 87.08 1.13 GYR 7 349.00 2.46 116.46 49.00 348.96 -1.82 -0.80 2.60 2.72 107.14 2.42 GYR 8 438.00 4.60 109.24 89.00 437.78 -5.81 -2.83 7.68 8.18 110.22 2.45 GYR 9 500.00 4.50 121.68 62.00 499.59 -9.58 -4.92 12.09 13.06 112.16 1.60 GYR 10 550.00 3.76 126.03 50.00 549.46 -12.66 -6.92 15.09 16.60 114.63 1.61 GYR 11 650.00 2.62 149.64 100.00 649.31 -17.80 -10.82 18.90 21.77 119.80 1.72 GYR 12 708.00 2.61 158.31 58.00 707.25 -20.44 -13.19 20.05 24.00 123.34 0.68 GYR 13 800.00 2.20 159.68 92.00 799.17 -24.29 -16.79 21.44 27.23 128.07 0.45 GYR 14 893.00 2.38 160.82 93.00 892.09 -27.99 -20.29 22.70 30.44 131.80 0.20 GYR 15 925.00 2.29 157.96 32.00 924.07 -29.29 -21.51 23.15 31.60 132.89 0.46 GYR 16 1000.00 1.65 172.65 75.00 999.02 -31.82 -23.97 23.85 33.82 135.14 1.08 GYR 17 1079.00 1.59 290.46 79.00 1078.01 -32.12 -24.72 22.97 33.74 137.09 3.51 GYR 18 1100.00 1.85 294.16 21.00 1099.00 -31.65 -24.48 22.39 33.17 137.55 1.35 GYR 19 1200.00 2.59 300.25 100.00 1198.92 -28.57 -22.68 18.97 29.56 140.09 0.78 GYR 20 1250.00 2.69 299.72 50.00 1248.87 -26.69 -21.53 16.97 27.41 141.75 0.21 GYR 21 1300.00 3.79 296.81 50.00 1298.79 -24.43 -20.20 14.48 24.85 144.37 2.22 GYR • 22 1350.00 5.35 295.83 50.00 1348.63 -21.32 -18.44 10.90 21.42 149.40 3.12 GYR 23 1400.00 6.74 295.32 50.00 1398.35 -17.25 -16.17 6.15 17.30 159.16 2.78 GYR 24 1450.00 9.86 294.86 50.00 1447.82 -11.72 -13.11 -0.39 13.12 181.68 6.24 GYR 25 1500.00 11.78 293.85 50.00 1496.93 -4.59 -9.25 -8.94 12.86 224.03 3.86 GYR 26 1550.00 12.79 294.19 50.00 1545.78 3.45 -4.92 -18.66 19.29 255.24 2.03 GYR 27 1591.98 13.70 289.72 41.98 1586.64 10.47 -1.33 -27.57 27.61 267.23 3.26 MWD IFR MS 28 1686.98 17.48 286.46 95.00 1678.13 27.85 6.51 -51.86 52.26 277.15 4.08 MWD IFR MS 29 1782.38 19.02 296..93 95.4 0 1768.76 49.60 17.61 -79.47 81.39 282.50 3.79 MWD IFR MS 30 1877.83 22.05 306..79 95.45 1858.16 77.67 35.39 -107.70 113.36 288.19 4.81 MWD IFR MS [(c)2005 IDEAL ID9_1C_01.4] s SCHLUMBERGER Survey Report 16-Aug-2005 01:10:00 Page 3 of 7 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 1972.81 23.31 311.47 94.98 1945.80 110.62 58.52 -136.06 148.11 293.27 2.32 MWD IFR MS 32 2068.14 26.24 315.83 95.33 2032.35 147.85 86.13 -164.88 186.03 297.58 3.62 MWD IFR MS 33 2164.41 28.11 320.93 96.27 2118.01 189.97 119.01 -194.01 227.61 301.53 3.10 MWD IFR MS 34 2260.49 31.38 323.87 96.08 2201.42 236.49 156.80 -223.04 272.64 305.11 3.73 MWD IFR MS 35 2355.35 31.69 328.13 94.86 2282.28 285.47 197.92 -250.76 319.46 308.28 2.37 MWD IFR MS 36 2451.14 34.18 332.79 95.79 2362.68 337.36 243.23 -276.36 368.15 311.35 3.71 MWD_ IFR _MS 37 2545.77 36.71 338.59 94.63 2439.79 392.18 293.22 -298.85 418.67 314.46 4.45 MWD_ IFR _MS 38 2641.35 37.93 343.54 95.58 2515.82 449.75 348.01 -317.60 471.15 317.62 3.39 MWD IFR MS 39 2737.32 40.82 347.09 95.97 2590.01 509.60 406.89 -332.97 525.76 320.71 3.82 MWD IFR MS 40 2834.00 44.29 349.11 96.68 2661.22 573.24 470.86 -346.41 584.56 323.66 3.86 MWD IFR MS 41 2929.79 48.27 348.08 95.79 2727.41 640.51 538.70 -360.12 647.99 326.24 4.23 MWD IFR MS 42 3025.62 52.61 347.16 95.83 2788.43 712.58 610.84 -375.98 717.28 328.39 4.59 MWD IFR MS 43 3121.73 56.59 347.01 96.11 2844.09 789.15 687.19 -393.48 791.87 330.20 4.14 MWD IFR MS 44 3215.11 56.21 346.89 93.38 2895.76 865.23 762.95 -411.05 866.64 331.69 0.42 MWD IFR MS 45 3312.60 57.35 346.96 97.49 2949.17 945.01 842.40 -429.50 945.57 332.99 1.17 MWD IFR M5 46 3407.74 56.76 346.62 95.14 3000.91 1023.15 920.12 -447.74 1023.28 334.05 0.69 MWD IFR MS 47 3503.23 58.05 346.96 95.49 3052.35 1101.89 998.44 -466.12 1101.89 334.97 1.38 MWD IFR MS 48 3599.06 56.73 346.43 95.83 3104.00 1180.92 1077.00 -484.70 1181.04 335.77 1.45 MWD IFR MS 49 3753.15 56.73 346.14 154.09 3188.53 1307.24 1202.16 -515.24 1307.92 336.80 0.16 MWD IFR MS 50 3850.14 58.63 344.67 96.99 3240.38 1387.84 1281.47 -535.90 1389.01 337.31 2.34 MWD IFR MS 51 3940.07 56.73 343.52 89.93 .3288.46 1462.86 1354.55 -556.72 1464.50 337.66 2.37 MWD_ IFR _MS 52 4041.51 57.32 343.24 101.44 3343.67 1547.04 1436.10 -581.06 1549.20 337.97 0.63 MWD IFR MS 53 4137.82 55.75 343.57 96.31 3396.78 1626.51 1513.09 -604.01 1629.19 338.24 1.66 MWD IFR MS 54 4239.59 55.12 343.37 101.77 3454.52 1709.39 1593.43 -627.85 1712.67 338.49 0.64 MWD IFR MS 55 4336.00 55.34 343.00 96.41 3509.50 1787.77 1669.24 -650.76 1791.61 338.70 0.39 MWD IFR MS 56 4431.67 55.86 342.64 95.67 3563.55 1865.96 1744.66 -674.08 1870.35 338.88 0.63 MWD IFR MS 57 4527.17 55.68 342.74 95.50 3617.27 1944.20 1820.04 -697.58 1949.14 339.03 0.21 MWD IFR MS 58 4622.73 53.35 344.12 95.56 3672.74 2021.16 1894.61 -719.78 2026.73 339.20 2.71 MWD IFR MS 59 4718.75 53.53 343.18 96.02 3729.94 2097.40 1968.61 -741.49 2103.63 339.36 0.81 MWD IFR MS 60 4814.00 55.69 344.25 95.25 3785.10 2174.13 2043.15 -763.25 2181.05 339.52 2.45 MWD IFR MS [(c)2005 IDEAL ID9_1C_01.4] 2 SCHLUMBERGER Survey Report 16-Aug-2005 01:10:00 Page 4 of 7 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 4909.67 54.87 344.63 95.67 3839.59 2251.69 2118.90 -784.35 2259.41 339.69 0.92 MWD IFR MS 62 5005.57 56.47 343.74 95.90 3893.67 2329.86 2195.09 -805.93 2338.36 339.84 1.84 MWD IFR MS 63 5100.25 56.74 343.76 94.68 3945.78 2407.97 2270.98 -828.05 2417.23 339.97 0.29 MWD IFR MS 64 5196.07 55.02 344.88 95.82 3999.53 2486.24 2347.35 -849.50 2496.33 340.10 2.04 MWD IFR MS 65 5291.98 56.18 346.21 95.91 4053.72 2564.02 2423.97 -869.25 2575.12 340.27 1.66 MWD IFR MS 66 5387.00 57.99 346.00 95.02 4105.35 2642.28 2501.40 -888.40 2654.48 340.45 1.91 MWD_ IFR _MS 67 5482.93 58.10 346.33 95.93 4156.12 2722.11 2580.44 -907.87 2735.48 340.62 0.31 MWD_ IFR _MS 68 5578.41 58.15 346.17 95.48 4206.54 2801.62 2659.19 -927.14 2816.18 340.78 0.15 MWD IFR MS 69 5674.01 57.80 346.96 95.60 4257.23 2881.02 2738.03 -945.97 2896.83 340.94 0.79 MWD IFR MS 70 5768.78 57.50 346.99 94.77 4307.95 2959.32 2816.03 -964.01 2976.46 341.10 0.32 MWD IFR MS 71 5863.88 56.93 347.26 95.10 4359.44 3037.47 2893.97 -981.83 3055.98 341.26 0.65 MWD IFR MS 72 5959.54 57.71 345.07 95.66 4411.10 3116.44 2972.14 -1001.09 3136.21 341.39 2.09 MWD IFR MS 73 6056.21 57.69 342.53 96.67 4462.76 3197.17 3050.60 -1023.88 3217.84 341.45 2.22 MWD IFR MS 74 6152.03 57.99 342.96 95.82 4513.76 3277.54 3128.06 -1047.94 3298.93 341.48 0.49 MWD IFR MS 75 6247.99 57.75 343.61 95.96 4564.80 3357.95 3205.89 -1071.31 3380.16 341.52 0.63 MWD IFR MS 76 6341.49 58.20 343.89 93.50 4614.38 3436.28 3282.00 -1093.50 3459.37 341.57 0.54 MWD IFR MS 77 6438.$8 57.50 343.34 97.39 4666.20 3517.80 3361.10 -1116.75 3541.77 341.62 0.86 MWD IFR MS 78 6534.49 58.21 341.51 95.61 4717.08 3598.06 3438.27 -1141.20 3622.71 341.64 1.78 MWD IFR MS 79 6631.65 56.35 340.49 97.16 4769.59 3679.34 3515.56 -1167.81 3704.44 341.62 2.11 MWD IFR MS 80 6725.69 55.29 339.61 94.04 4$22.43 3756.82 3588.68 -1194.35 3782.21 341.59 1.37 MWD IFR MS 81 6821.40 56.39 339.93 95.71 4876.17 3835.74 3662.99 -1221.73 3861.37 341.55 1.18 MWD_ IFR _MS 82 6916.97 55.99 340.16 95.57 4929.35 3914.83 3737.64 -1248.83 3940.75 341.52 0.46 MWD IFR MS 83 7013.59 55.96 339.95 96.62 4983.41 3994.59 3812.91 -1276.15 4020.80 341.50 0.18 MWD IFR MS 84 7109.04 55.85 339.98 95.45 5036.92 4073.33 3887.17 -1303.23 4099.81 341.47 0.12 MWD IFR MS 85 7204.60 56.13 340.11 95.56.. 5090.37 4152.23 3961.63 -1330.26 4179.00 341.44 0.31 MWD IFR MS 86 7300.13 55.13 342.26 95.53 5144.30 4230.61 4036.25 -1355.70 4257.85 341.43 2.13 MWD IFR MS 87 7396.28 54.98 341.89 96.15 5199.37 4308.82 4111.24 -1379.95 4336.66 341.45 0.35 MWD IFR MS 88 7492.00 54.69 342.49 95.72 5254.50 4386.44 4185.74 -1403.89 4414.90 341.46 0.60 MWD IFR MS ' 89 7588.00 54.88 342.28 96.00 5309.86 4464.22 4260.50 -1427.62 4493.32 341.47 0.27 MWD IFR MS 90 7683.71 54.68 342.44 95.71 5365.06 4541.75 4335.01 -1451.32 4571.50 341.49 0.25 MWD IFR MS [(c)2005 IDEAL ID9_1C_01.4] SCHLUMBERGER Survey Report 16- Aug-2005 01:10:00 Page 5 of 7 Seq Measured Inc1 Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 91 7778.67 54.87. 342.01 94.96 5419.83 4618.70 4408.88 -1475.00 4649.07 341.50 0.42 MWD IFR MS 92 7874.27 56.76 341.68 95.60 5473.54 4697.21 4484.02 -1499.64 4728.14 341.51 2.00 MWD IFR MS 93 7969.63 57.27 341.59 95.36 5525.46 4776.65 4559.93 -1524.84 4808.13 341.51 0.54 MWD _IFR _M5 94 8064.67 56.94 341.15 95.04 5577.07 4855.95 4635.55 -1550.34 4887.93 341.51 0.52 MWD IFR MS 95 8160.40 57.13 342.34 95.73 5629.17 4935.70 4711.83 -1575.49 4968.25 341.51 1.06 MWD IFR M5 96 8256.27 56.63 341.90 95.87 5681.55 5015.37 4788.24 -1600.14 5048.54 341.52 0.65 MWD_ IFR _MS 97 8351.81 56.38 341.80 95.54 5734.27 5094.47 4863.95 -1624.96 5128.21 341.53 0.28 MWD_ IFR _MS • 98 8447.56 57.52 343.20 95.75 5786.49 5174.02 4940.49 -1649.09 5208.45 341.54 1.71 MWD IFR MS 99 8542.8'7 57.27 343.33 95.31 5837.85 5253.47 5017.38 -1672.21 5288.71 341.57 0.29 MWD IFR MS 100 8637.10 56.95 343.74 94.23 5889.02 5331.71 5093.26 -1694.64 5367.79 341.60 0.50 MWD IFR MS 101 8732.43 56.65 343.09 95.33 5941.22 5410.61 5169.71 -1717.40 5447.51 341.62 0.65 MWD IFR MS 102 8828.78 56.35 342.99 96.35 5994.40 5490.15 5246.56 -1740.84 5527.83 341.64 0.32 MWD IFR MS 103 8925.20 55.53 342.89 96.42 6048.40 5569.25 5322.93 -1764.27 5607.69 341.66 0.85 MWD IFR MS 104 9020.82 57.12 343.57 95.62 6101.42 5648.00 5399.12 -1787.23 5687.23 341.68 1.76 MWD IFR MS 105 9116.04 56.79 343.95 95.22 6153.34 5726.87 5475.75 -1809.55 5767.00 341.71 0.48 MWD IFR MS 106 9212.77 56.08 343.88 96.73 6206.82 5806.49 5553.19 -1831.88 5847.54 341.74 0.74 MWD IFR MS 107 9306.96 56.07 345.15 94.19 6259.39 5883.55 5628.51 -1852.75 5925.61 341.78 1.12 MWD IFR MS 108 9400.78 55.22 345.05 93.82 6312.33 5959.80 5703.36 -1872.66 6002.93 341.82 0.91 MWD IFR MS 109 9498.81 54.64 344.41 98.03 6368.66 603$.86 5780.76 -1893.79 6083.06 341.86 0.80 MWD ^ IFR _MS 110 9594.62 57.28 339.74 95.81 6422.31 6117.60 5856.24 -1918.26 6162.41 341.86 4.89 MWD IFR MS 111 9690.03 58.58 337.19 95.41 6472.97 6198.29 5931.43 -1947.95 6243.11 341.82 2.64 MWD_ IFR _MS 112 9784.92 59.26 337.50 94.89 6521.96 6279.49 6006.43 -1979.25 6324.13 341.76 0.77 MWD IFR MS 113 9881.09 58.68 337.49 96.17 6571.53 6361.81 6082.56 -2010.79 6406.31 341.71 0.60 MWD IFR MS 114 9976.47 59.86 335.70 95.38 6620.27 6443.76 6157.79 -2043.36 6487.97 341.64 2.03 MWD IFR MS 115 10072.32 61.12 335.21 95.85 6667.48 6527.17 6233.67 -2078.02 6570.90 341.56 1.39 MWD IFR MS 116 10167.70 60.66 335.04 95.38 6713.88 6610.50 6309.27 -2113.07 6653.72 341.48 0.51 MWD IFR MS 117 10217.00 60.80 335.15 49.30 6737.99 6653.51 6348.27 -2131.18 6696.46 341.44 0.34 TOP OF WINDOW 118 10229.00 62.60 334.40 12.00 6743.68 6664.07 6357.83 -2135.68 6706.95 341.43 15.98 BOTTOM OF WINDOW 119 10243.00 62.60 334.40 14.00 6750.12 6676.50 6369.04 -2141.05 6719.29 341.42 0.00 END OF MILL RUN 120 1026$.64 69.85 334.40 25.64 6760.45 6699.95 6390.19 -2151.18 6742.56 341.39 28.28 INCL INATION ONLY [(c)2005 IDEAL ID9_1C_01.4] SCHLUMBERGER Survey Report 16-Aug-2005 01:10:00 Page 6 of 7 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) 121 10300.73 77.78 332.84 32.09 6769.39 6730.73 6417.77 -2164.87 6773.07 341.36 25.15 INCLINATION ONLY 122 10332.34 85.77 332.90 31.61 6773.91 6761.97 6445.59 -2179.13 6803.99 341.32 25.28 MWD IFR MS 123 10363.34 89.38 330.48 31.00 6775.22 6792.89 6472.85 -2193.81 6834.52 341.28 14.02 MWD IFR MS 124 10395.10 91.54 329.81 31.76 6774.96 6824.53 6500.39 -2209.62 6865.68 341.23 7.12 MWD IFR MS 125 10427.83 94.58 328.24 32.73 6773.22 6857.04 6528.41 -2226.44 6897.62 341.17 10.45 MWD IFR MS 126 10459.37 95.24 329.82 31.54 6770.52 6888.29 6555.36 -2242.61 6928.35 341.11 5.41 MWD IFR MS 127 10490.74 92.25 327.46 31.37 6768.47 6919.40 6582.08 -2258.90 6958.91 341.06 12.13 MWD_ IFR_ MS 128 10521.95 90.22 326.50 31.21 6767.79 6950.30 6608.24 -2275.90 6989.18 341.00 7.19 MWD IFR MS 129 10554.13 89.54 322.83 32.18 6767.86 6981.96 6634.49 -2294.51 7020.06 340.92 11.60 MWD IFR MS 130 105$6.55 89.74 319.42 32.42 6768.07 7013.43 6659.72 -2314.85 7050.57 340.83 10.54 MWD IFR MS 131 10617.59 90.12 316.76 31.04 6768.10 7043.13 6682.82 -2335.59 7079.20 340.74 8.66 MWD IFR MS 132 10649.77 90.43 313.28 32.18 6767.95 7073.38 6705.58 -2358.33 7108.20 340.62 10.86 MWD IFR MS 133 10682.32 90.39 309.79 32.55 6767.72 7103.25 6727.16 -2382.69 7136.66 340.50 10.72 MWD IFR MS 134 10713.13 90.09 305.81 30.81 6767.59 7130.66 6746.04 -2407.03 7162.60 340.36 12.95 MWD IFR MS 135 10745.55 89.61 303.84 32.42 6767.67 7158.70 6764.55 -2433.64 7189.00 340.21 6.25 MWD IFR MS 136 10778.00 90.26 302.02 32.45 6767.71 7186.21 6782.19 -2460.88 7214.85 340.06 5.96 MWD IFR MS 137 10809.52 90.60 300.29 31.52 6767.47 7212.40 6798.50 -2487.85 7239.40 339.90 5.59 MWD IFR MS 138 10841.83 90.70 300.75 32.31 6767.11 7239.05 6814.91 -2515.68 7264.41 339.74 1.46 MWD IFR ' MS 139 10873.42 90.22 298.93 31.59 6766.85 7264.89 6830.62 -2543.08 7288.67 339.58 5.96 MWD IFR MS 140 10904.95 89.64 297.84 31.53 6766.89 7290.21 6845.61 -2570.82 7312.42 339.42 3.92 MWD IFR MS 141 10936.92 88.89 298.25 31.97 6767.30 7315.77 6860.64 -2599.03 7336.44 339.25 2.67 MWD_ IFR_ MS 142 10968.65 85.93 298.28 31.73 6768.74 7341.19 6875.65 -2626.95 7360.40 339.09 9.33 MWD IFR MS 143 11000.25 83.52 297.54 31.60 6771.64 7366.31 6890.38 -2654.75 7384.11 338.93 7.98 MWD IFR MS 144 11032.94 83.69 297.78 32.69 6775.28 7392.15 6905.46 -2683.52 7408.55 338.76 0.90 MWD IFR MS 145 11063.67 83.80 297.28 30.73 6778.63 7416.41 6919.58 -2710.61 7431.55 338.61 1.66 MWD IFR MS 146 11096.73 83.90 296.59 33.06 6782.17 7442.31 6934.47 -2739.92 7456.14 338.44 2.10 MWD IFR MS 147 11128,61 83.94 297.92 31.88 6785.55 7467.39 6948.99 -2768.10 7480.02 338.28 4.15 MWD IFR MS 148 11159.93 84.70 296.38 31.32 6788.65 7492.02 6963.21 -2795.83 7503.53 338.12 5.46 MWD IFR MS 149 11191.54 86.07 296.79 31.61 6791.19 7516.72 6977.31 -2824.00 7527.14 337.96 4.52 MWD IFR MS 150 11224.09 86.04 296.56 32.55 b793.43 7542.21 6991.88 -2853.02 7551.57 337.80 0.71 MWD IFR MS r~ L(c)2005 IDEAL ID9_1C_01.4] SCHLUMBERGER Survey Report --- -------- ------ ------- Seq Measured Intl Azimuth # depth angle angle - (ft) (deg) (deg). --- -------- ------ ------- 151 11255.84 86.11 296.50 152 11287.58 85.83 295.99 153 11320.05 85.28 295.40 154 11351.92 87.89 293.74 155 11383.47 89.61 293.75 156 11404.13 89.54 294.20 Projection to Total Depth: 157 11460.00 89.54 294.20 [(c)2005 IDEAL ID9_1C_01.4] Course length (ft) 31.75 31.74 32.47 31.87 31.55 20.66 55.87 TVD depth (ft) 6795.60 6797.83 6800.35 6802.25 6802.94 6803.09 6803.54 16-Aug-2005 01:10:00 Vertical Displ Displ section +N/S- +E/W- (ft) (ft) (ft) 7567.03 7006.03 -2881.36 7591.74 7020.03 -2909.76 7616.80 7034.07 -2938.93 7641.04 7047.30 -2967.86 7664.77 7060.00 -2996.73 7680.36 7068.39 -3015.61 7722.69 7091.29 -3066.57 Page Total displ (ft) 7575.40 7599.18 7623.35 7646.73 7669.68 7684.79 7725.95 7 of At Azim (deg) 337.64 337.49 337.32 337.16 337.00 336.90 336.61 7 DLS Srvy Tool (degl tool Corr 100f) type (deg) 0.29 MWD_IFR_MS 1.83 MWD_IFR_MS 2.48 MWD_IFR_MS 9.70 MWD_IFR_MS 5.45 MWD_IFR_MS 2.20 MWD_IFR_MS 0.00 PROJECTION TO TD I ~. 4 i ~ SCHLUMBERGER Survey report Client .................... BP Exploration (Alaska) Inc. Field ..................... Aurora Well ...................... 5-122 API number ...............: 50-029-23265-00 Engineer .................. J. Davies RIG :...................... NABORS 7ES 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 35.70 ft N/A Top Drive 64.25 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: 334.95 degrees [(c)2005 IDEAL ID9_1C_02] 17-Aug-2005 17:21:00 Page 1 of 7 Spud date ................. 30-Jul-05 Last survey date.........: 17-Aug-05 Total accepted surveys...: 179 MD of first survey.......: 0.00 ft MD of last survey........: 12173.00 ft ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2004 Magnetic date ............: 29-Jul-2005 Magnetic field strength..: 1152.68 HCNT Magnetic dec (+E/W-).....: 24.52 degrees Magnetic dip .............. 80.85 degrees ----- MWD survey Reference Reference G ............... Reference H ............... Reference Dip.... ........ Tolerance of G............ Tolerance of H............ Tolerance of Dip.......... Criteria --------- 1002.68 meal 1152.68 HCNT 80.85 degrees (+/-) 2.50 meal (+/-) 6.00 HCNT (+/-) 0.45 degrees ----- Corrections ----------------------g---- Magnetic dec (+E/W-).....: 24.52 de rees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 24.52 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 • SCHLUMBERGER Survey Report 17-Aug-2005 17:21:00 Page 2 of 7 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP 2 76.00 0.46 357.51 76.00 76.00 0.28 0.30 -0.01 0.31 357.51 0.61 GYR 3 100.00 0.35 24.42 24.00 100.00 0.42 0.47 0.01 0.47 1.58 0.90 GYR 4 198.00 0.14 17.76 98.00 198.00 0.70 0.85 0.17 0.87 11.46 0.22 GYR 5 250.00 0.82 128.20 52.00 250.00 0.42 0.68 0.48 0.84 35.31 1.69 GYR 6 300.00 1.38 131.84 50.00 299.99 -0.46 0.06 1.21 1.22 87.08 1.13 GYR 7 349.00 2.46 116.46 49.00 348.96 -1.82 -0.80 2.60 2.72 107.14 2.42 GYR 8 438.00 4.60 109.24 89.00 437.78 -5.81 -2.83 7.68 8.18 110.22 2.45 GYR 9 500.00 4.50 121.68 62.00 499.59 -9.58 -4.92 12.09 13.06 112.16 1.60 GYR 10 550.00 3.76 126.03 50.00 549.46 -12.66 -6.92 15.09 16.60 114.63 1.61 GYR 11 650.00 2.62 149.64 100.00 649.31 -17.80 -10.82 18.90 21.77 119.80 1.72 GYR 12 708.00 2.61 158.31 58.00 707.25 -20.44 -13.19 20.05 24.00 123.34 0.68 GYR 13 800.00 2.20 159.68 92.00 799.17 -24.29 -16.79 21.44 27.23 128.07 0.45 GYR 14 893.00 2.38 160.82 93.00 892.09 -27.99 -20.29 22.70 30.44 131.80 0.20 GYR 15 925.00 2.29 157.96 32.00 924.07 -29.29 -21.51 23.15 31.60 132.89 0.46 GYR 16 1000.00 1.65 172.65 75.00 999.02 -31.82 -23.97 23.85 33.82 135.14 1.08 GYR 17 1079.00 1.59 290.46 79.00 1078.01 -32.12 -24.72 22.97 33.74 137.09 3.51 GYR 18 1100.00 1.85 294.16 21.00 1099.00 -31.65 -24.48 22.39 33.17 137.55 1.35 GYR 19 1200.00 2.59 300.25 100.00 1198.92 -28.57 -22.68 18.97 29.56 140.09 0.78 GYR 20 1250.00 2.69 299.72 50.00 1248.87 -26.69 -21.53 16.97 27.41 141.75 0.21 GYR 21 1300.00 3.79 296.81 50.00 1298.79 -24.43 -20.20 14.48 24.85 144.37 2.22 GYR 22 1350.00 5.35 295.83 50.00 1348.63 -21.32 -18.44 10.90 21.42 149.40 3.12 GYR 23 1400.00 6.74 295.32 50.00 1398.35 -17.25 -16.17 6.15 17.30 159.16 2.78 GYR 24 1450.00 9.86 294.86 50.00 1447.82 -11.72 -13.11 -0.39 13.12 181.68 6.24 GYR 25 1500.00 11.78 293.85 50.00 1496.93 -4.59 -9.25 -8.94 12.86 224.03 3.86 GYR 26 1550.00 12.79 294.19 50.00 1545.78 3.45 -4.92 -18.66 19.29 255.24 2.03 GYR 27 1591.98 13.70 289.72 41.98 1586.64 10.47 -1.33 -27.57 27.61 267.23 3.26 MWD IFR MS 28 1686.98 17.48 286.46 95.00 1678.13 27.85 6.51 -51.86 52.26 277.15 4.08 MWD IFR MS 29 1782.38 19.02 296.93 95.40 1768.76 49.60 17.61 -79.47 81.39 282.50 3.79 MWD IFR MS 30 1877.83 22.05 306.79 95.45 1858.16 77.67 35.39 -107.70 113.36 288.19 4.81 MWD IFR MS [(c)2005 IDEAL ID9_1C_02] r SCHLUMBERGER Survey Report 17-Aug-2005 17:21:00 Page 3 of 7 Seq Measured Incl Azimuth Course TVD Vertical Disp1 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 1972.81 23.31 311.47 94.98 1945.80 110.62 58.52 -136.06 148.11 293.27 2.32 MWD IFR MS 32 2068.14 26.24 315.83 95.33 2032.35 147.85 86.13 -164.88 186.03 297.58 3.62 MWD IFR MS 33 2164.41 28.11 320.93 96.27 2118.01 189.97 119.01 -194.01 227.61 301.53 3.10 MWD IFR MS 34 2260.49 31.38 323.87 96.08 2201.42 236.49 156.80 -223.04 272.64 305.11 3.73 MWD IFR MS 35 2355.35 31.69 328.13 94.86 2282.28 285.47 197.92 -250.76 319.46 308.28 2.37 MWD IFR MS 36 2451.14 34.18 332,79 95.79 2362.68 337.36 243.23 -276.36 368.15 311.35 3.71 MWD IFR MS 37 2545.77 36.71 338.59 94.63 2439.79 392.18 293.22 -298.85 418.67 314.46 4.45 MWD_ IFR _MS 38 2641.35 37.93 343.54 95.5$ 2515.82 449.75 348.01 -317.60 471.15 317.62 3.39 MWD IFR MS 39 2737.32 40.82 347.09 95.97 2590.01 509.60 406.89 -332.97 525.76 320.71 3.82 MWD IFR MS 40 2834.00 44.29 349.11 96.68 2661.22 573.24 470.86 -346.41 584.56 323.66 3.86 MWD IFR MS 41 2929.79 48.27 348.08 95.79 2727.41 640.51 538.70 -360.12 647.99 326.24 4.23 MWD IFR MS 42 3025.62 52.61 347.16 95.83 2788.43 712.58 610.84 -375.98 717.28 328.39 4.59 MWD IFR MS 43 3121.73 56.59 347.01 96.11 2844.09 789.15 687.19 -393.48 791.87 330.20 4.14 MWD IFR MS 44 3215.11 56.21 346.89 93.38 2895.76 865.23 762.95 -411.05 866.64 331.69 0.42 MWD IFR MS 45 3312.60 57.35 346.96 97.49 2949.17 945.01 842.40 -429.50 945.57 332.99 1.17 MWD IFR MS 46 3407.74 56.76 346.62 95.14 3000.91 1023.15 920.12 -447.74 1023.28 334.05 0.69 MWD IFR MS 47 3503.23 58.05 346.96 95.49 3052.35 1101.89 998.44 -466.12 1101.89 334.97 1.38 MWD IFR MS 48 3599.06 56.73 346.43 95.83 3104.00 1180.92 1077.00 -484.70 1181.04 335.77 1.45 MWD IFR MS 49 3753.15 56.73 346.14 154.09 3188.53 1307.24 1202.16 -515.24 1307.92 336.80 0.16 MWD IFR MS 50 3850.14 58.63 344.67 96.99 3240.38 1387.84 1281.47 -535.90 1389.01 337.31 2.34 MWD IFR MS 51 3940.07 56.73 343.52 89.93 3288.46 1462.86 1354.55 -556.72 1464.50 337.66 2.37 MWD_ IFR _MS 52 4041.51 57.32 343.24 101.44 3343.67 1547.04 1436.10 -581.06 1549.20 337.97 0.63 MWD IFR MS 53 4137.82 55.75 343.57 96.31 3396.78 1626.51 1513.09 -604.01 1629.19 338.24 1.66 MWD IFR MS 54 4239.59 55.12 343.37 101.77 3454.52 1709.39 1593.43 -627.85 1712.67 338.49 0.64 MWD IFR MS 55 4336.00 55.34 343.00 96.41 3509.50 1787.77 1669.24 -650.76 1791.61 338.70 0.39 MWD IFR MS 56 4431.67 55.86 342.64 95.67 3563.55 1865.96 1744.66 -674.08 1870.35 338.88 0.63 MWD IFR MS 57 4527.17 55.68 342.74 95.50 3617.27 1944.20 1820.04 -697.58 1949.14 339.03 0.21 MWD IFR MS 58 4622.73 53.35 344.12 95.56 3672.74 2021.16 1894.61 -719.78 2026.73 339.20 2.71 MWD IFR MS 59 4718.75 53.53 343.18 96.02 3729.94 2097.40 1968.61 -741.49 2103.63 339.36 0.81 MWD IFR MS 60 4814.00 55.69 344.25 95.25 3785.10 2174.13 2043.15 -763.25 2181.05 339.52 2.45 MWD IFR MS • [(c)2005 IDEAL ID9_1C_02] SCHLUMBERGER Survey Report 17-Aug-2005 17:21:00 Page 4 of 7 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 4909.67 54.87 344.63 95.67 3839.59 2251.69 2118.90 -784.35 2259.41 339.69 0.92 MWD IFR MS 62 5005.57 56.47 343.74 95.90 3893.67 2329.86 2195.09 -805.93 2338.36 339.84 1.84 MWD IFR MS 63 5100.25 56.74 343.76 94.68 3945.78 2407.97 2270.98 -828.05 2417.23 339.97 0.29 MWD IFR MS 64 5196.07 55.02 344.88 95.82 3999.53 2486.24 2347.35 -849.50 2496.33 340.10 2.04 MWD IFR MS 65 5291.98 56.18 346.21 95.91 4053.72 2564.02 2423.97 -869.25 2575.12 340.27 1.66 MWD IFR MS 66 5387.00 57.99 346.00 95.02 4105.35 2642.28 2501.40 -888.40 2654.48 340.45 1.91 MWD_ IFR _MS 67 5482.93 58.10 346.33 95.93 4156.12 2722.11 2580.44 -907.87 2735.48 340.62 0.31 MWD_ IFR _MS 68 5578.41 58.15 346.17 95.48 4206.54 2801.62 2659.19 -927.14 2816.18 340.78 0.15 MWD IFR MS 69 5674.01 57.80 346.96 95.60 4257.23 2881.02 2738.03 -945.97 2896.83 340.94 0.79 MWD IFR MS 70 5768.78 57.50 346.99 94.77 4307.95 2959.32 2816.03 -964.01 2976.46 341.10 0.32 MWD IFR MS 71 5863.88 56.93 347.26 95.10 4359.44 3037.47 2893.97 -981.83 3055.98 341.26 0.65 MWD IFR M5 72 5959.54 57.71 345.07 95.66 4411.10 3116.44 2972.14 -1001.09 3136.21 341.39 2.09 MWD IFR MS 73 6056.21 57.69 342.53 96.67 4462.76 3197.17 3050.60 -1023.88 3217.84 341.45 2.22 MWD IFR MS 74 6152.03 57.99 342.96 95.82 4513.76 3277.54 3128.06 -1047.94 3298.93 341.48 0.49 MWD IFR MS 75 6247.99 57.75 343.61 95.96 4564.80 3357.95 3205.89 -1071.31 3380.16 341.52 0.63 MWD IFR MS 76 6341.49 58.20 343.89 93.50 4614.38 3436.28 3282.00 -1093.50 3459.37 341.57 0.54 MWD IFR MS 77 6438.88 57.50 343.34 97.39 4666.20 3517.80 3361.10 -1116.75 3541.77 341.62 0.86 MWD IFR MS 78 6534.49 58.21 341.51 95.61 4717.08 3598.06 3438.27 -1141.20 3622.71 341.64 1.78 MWD IFR M5 79 6631.65 56.35 340.49 97.16 4769.59 3679.34 3515.56 -1167.81 3704.44 341.62 2.11 MWD IFR MS 80 6725.69 55.29 339.61 94.04 4822.43 3756.82 3588.68 -1194.35 3782.21 341.59 1.37 MWD IFR MS 81 6821.40 56.39 339.93 95.71 4876.17 3835.74 3662.99 -1221.73 3861.37 341.55 1.18 MWD_ IFR _MS 82 6916.97 55.99 340.16 95.57 4929.35 3914.83 3737.64 -1248.83 3940.75 341.52 0.46 MWD IFR MS 83 7013.59 55.96 339.95 96.62 4983.41 3994.59 3812.91 -1276.15 4020.80 341.50 0.18 MWD IFR MS 84 7109.04 55.85 339.98 95.45 5036.92 4073.33 3887.17 -1303.23 4099.81 341.47 0.12 MWD IFR MS 85 7204.60 56.13 340.11 95.56 5090.37 4152.23 3961.63 -1330.26 4179.00 341.44 0.31 MWD IFR MS 86 7300.13 55.13 342.26 95.53 5144.30 4230.61 4036.25 -1355.70 4257.85 341.43 2.13 MWD IFR MS 87 7396.28 54.98 341.89 96.15 5199.37 4308.82 4111.24 -1379.95 4336.66 341.45 0.35 MWD IFR MS 88 7492.00 54.69 342.49 95.72 5254.50 4386.44 4185.74 -1403.89 4414.90 341.46 0.60 MWD IFR MS ^ 89 7588.00 54.$8 342.28 96.00 5309.86 4464.22 4260.50 -1427.62 4493.32 341.47 0.27 MWD IFR MS ^ 90 7683.71 54.68 342.44 95.71 5365.06 4541.75 4335.01 -1451.32 4571.50 341.49 0.25 MWD IFR MS [(c)2005 IDEAL ID9_1C_02] SCHLUMBERGER Survey Report 17 -Aug-2005 17:21:00 Page 5 of 7 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) {deg) (deg} (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 91 777$.67 54.87 342.01 94.96 5419.83 4618.70 4408.88 -1475.00 4649.07 341.50 0.42 MWD IFR MS 92 7874.27 56.76 341.68 95.60 5473.54 4697.21 4484.02 -1499.64 4728.14 341.51 2.00 MWD IFR MS 93 7969.63 57.27 341.59 95.36 5525.46 4776.65 4559.93 -1524.84 4808.13 341.51 0.54 MWD IFR MS 94 8064.67 56.94 341.15 95.04 5577.07 4855.95 4635.55 -1550.34 4887.93 341.51 0.52 MWD IFR MS 95 8160.40 57.13 342.34 95.73 5629.17 4935.70 4711.83 -1575.49 4968.25 341.51 1.06 MWD IFR MS 96 8256.27 56.63 341.90 95.87 5681.55 5015.37 4788.24 -1600.14 5048.54 341.52 0.65 MWD _IFR _MS 97 8351.81 56.38 341.80 95.54 5734.27 5094.47 4863.95 -1624.96 5128.21 341.53 0.28 MWD _IFR _MS • 98 8447.56 57.52 343.20 95.75 5786.49 5174.02 4940.49 -1649.09 5208.45 341.54 1.71 MWD IFR MS 99 8542.87 57.27 343.33 95.31 5837.85 5253.47 5017.38 -1672.21 5288.71 341.57 0.29 MWD IFR MS 100 8637.10 56.95 343.74 94.23 5889.02 5331.71 5093.26 -1694.64 5367.79 341.60 0.50 MWD IFR MS 101 8732.43 56.65 343.09 95.33 5941.22 5410.61 5169.71 -1717.40 5447.51 341.62 0.65 MWD IFR MS 102 8828.78 56.35 342.99 96.35 5994.40 5490.15 5246.56 -1740.84 5527.83 341.64 0.32 MWD IFR MS 103 8925.20 55.53 342.89 96.42 6048.40 5569.25 5322.93 -1764.27 5607.69 341.66 0.85 MWD IFR MS 104 9020.82 57.12 343.57 95.62 6101.42 5648.00 5399.12 -1787.23 5687.23 341.68 1.76 MWD IFR MS 105 9116.04 56.79 343.95 95.22 6153.34 5726.87 5475.75 -1809.55 5767.00 341.71 0.48 MWD IFR MS 106 9212.77 56.08 343.88 96.73 6206.82 5806.49 5553.19 -1831.88 5847.54 341.74 0.74 MWD IFR MS 107 9306.96 56.07 345.15 94.19 6259.39 5883.55 5628.51 -1852.75 5925.61 341.78 1.12 MWD IFR MS ' 108 9400.78 55.22 345.05 93.82 6312.33 5959.80 5703.36 -1872.66 6002.93 341.82 0.91 MWD IFR MS ' 109 9498.81 54.64 344.41 98.03 6368.66 6038.86 5780.76 -1893.79 6083.06 341.86 0.80 MWD IFR MS 110 9594.62 57.28 339.74 95.81 6422.31 6117.60 5856.24 -1918.26 6162.41 341.86 4.89 MWD IFR MS 111 9690.03 58.58 337.19 95.41 6472.97 6198.29 5931.43 -1947.95 6243.11 341.82 2.64 MWD_ IFR _MS 112 9784.92 59.26 337.50 94.89 '6521.96 6279.49 6006.43 -1979.25 6324.13 341.76 0.77 MWD IFR MS 113 9881.09 58.68 337.49 96.17 6571.53 6361.81 6082.56 -2010.79 6406.31 341.71 0.60 MWD IFR MS 114 9976.47 59.86 335.70 95.38 6620.27 6443.76 6157.79 -2043.36 6487.97 341.64 2.03 MWD IFR MS 115 10072.32 61.12 335.21 95.85 6667.48 6527.17 6233.67 -2078.02 6570.90 341.56 1.39 MWD IFR MS 116 10167.70 60.66 335.04 95.38 6713.88 6610.50 6309.2.7 -2113.07 6653.72 341.48 0.51 MWD IFR MS 117 10217.00 60.80 335.15 49.30 6737.99 6653.51 6348.27 -2131.18 6696.46 341.44 0.34 Top of Window 118 10229.00 62.60 334.40 12.00 6743.68 6664.07 6357.83 -2135.68 6706.95 341.43 15.98 Bottom of Window 119 10243.00 62.60 334.40 14.00 6750.12 6676.50 6369.04 -2141.05 6719.29 341.42 0.00 End of Mill Run 120 10268.64 69.85 334.40 25.64 6760.45 6699.95 6390.19 -2151.18 6742.56 341.39 28.28 Incl ination Only [(c)2005 IDEAL ID9_1C_02] SCHLUMBERGER Survey Report 17- Aug-2005 17:21:00 Page 6 of 7 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) 121 10300.73 77.78 332.84 32.09 6769.39 6730.73 6417.77 -2164.87 6773.07 341.36 25.15 Inclina tion Only 122 10332.34 85.77 332.90 31.61 6773.91 6761.97 6445.59 -2179.13 6803.99 341.32 25.28 MWD IFR ' _MS 123 10363.74 89.25 331.52 31.40 6775.27 6793.30 6473.34 -2193.75 6834.96 341.28 11.92 MWD_ IFR _MS 124 10396.52 89.01 332.47 32.78 6775.77 6826.03 6502.28 -2209.14 6867.31 341.23 2.99 MWD IFR ' _MS 125 10428.15 87.64 330.34 31.63 6776.69 6857.59 6530.04 -2224.27 6898.46 341.19 8.00 MWD IFR MS 126 10459.24 87.40 327.41 31.09 6778.04 6888.47 6556.62 -2240.33 6928.81 341.14 9.45 MWD_ IFR _MS 127 10489.52 87.43 324.06 30.28 6779.41 6918.32 6581.62 -2257.35 6957.97 341.07 11.05 MWD_ IFR _MS 128 10520.73 87.81 321.77 31.21 6780.70 6948.82 6606.49 -2276.16 6987.60 340.99 7.43 MWD IFR MS 129 10553.24 87.81 320.52 32.51 6781.94 6980.37 6631.79 -2296.54 7018.17 340.90 3.84 MWD ` IFR _MS 130 10585.62 89.21 318.38 32.38 6782.79 7011.56 6656.38 -2317.58 7048.30 340.80 7.90 MWD IFR MS 131 10617.49 90.72 314.46 31.87 6782.81 7041.77 6679.46 -2339.54 7077.34 340.70 13.18 MWD IFR MS 132 10649.95 90.93 313.21 32.46 6782.34 7072.04 6701.94 -2362.96 7106.31 340.58 3.90 MWD IFR MS 133 10681.58 90.86 314.76 31.63 6781.84 7101.58 6723.91 -2385.71 7134.60 340.46 4.90 MWD ~ IFR _MS 134 10713.59 91.03 311.11 32.01 6781.32 7131.24 6745.70 -2409.14 7162.99 340.35 11.41 MWD IFR MS 135 10746.05 90.62 310.68 32.46 6780.85 7160.88 6766.95 -2433.67 7191.27 340.22 1.83 MWD IFR MS 136 10777.14 91.20 308.15 31.09 6780.35 7188.93 6786.69 -2457.69 7217.99 340.09 8.35 MWD ~ IFR _MS 137 10808.55 90.34 308.04 31.41 6779.93 7216.95 6806.06 -2482.40 7244.64 339.96 2.76 MWD IFR MS 138 10840.92 89.59 306.53 32.37 6779.95 7245.62 6825.67 -2508.16 7271.91 339.82 5.21 MWD IFR MS 139 10872.81 89.56 304.69 31.89 6780.19 7273.41 6844.24 -2534.08 7298.30 339.68 5.77 MWD IFR MS 140 10905.04 89.66 303.98 32.23 6780.41 7301.15 6862.42 -2560.70 7324.61 339.54 2.22 MWD IFR MS 141 10937.38 89.59 301.78 32.34 6780.62 7328.55 6879.97 -2587.85 7350.58 339.39 6.81 MWD_ IFR _MS 142 10966.77 90.17 299.42 29.39 6780.68 7352.81 6894.93 -2613.15 7373.51 339.24 8.27 MWD IFR MS 143 11000.39 90.62 297.26 33.62 6780.45 7379.80 6910.89 -2642.74 7398.95 339.07 6.56 MWD IFR MS 144 11032.86 90.38 295.73 32.47 6780.17 7405.23 6925.38 -2671.79 7422.89 338.90 4.77 MWD IFR MS 145 11062.39 90.41 297.23 29.53 6779.96 7428.34 6938.54 -2698.22 7444.71 338.75 5.08 MWD IFR MS 146 11093.62 90.24 295.63 31.23. 6779.79 7452.78 6952.44 -2726.19 7467.83 338.59 5.15 MWD IFR MS 147 11126.34 90.24 295.78 32.72 6779.65 7478.12 6966.63 -2755.67 7491.84 338.42 0.46 MWD IFR MS 148 11156.57 90.10 295.91 30.23 6779.56 7501.58 6979.81 -2782.88 7514.13 338.26 0.63 MWD IFR MS 149 11187.68 89.21 296.20 31.11 6779.75 7525.79 6993.48 -2810.82 7537.20 338.10 3.01 MWD IFR MS 150 11221.28 89.21 295.58 33.60 6780.21 7551.87 7008.15 -2841.05 7562.12 337.93 1.85 MWD IFR MS [(c)2005 IDEAL ID9_1C_02) R SCHLUMBERGER Survey Report 17-Aug-2005 17:21:00 Page 7 of 7 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) 151 11251.49 89.04 296.44 30.21 6780.67 7575.37 7021.39 -2868.20 7584.62 337.78 2.90 MWD IFR MS ' 152 11284.22 88.60 295.75 32.73 6781.34 7600.85 7035.78 -2897.58 7609.09 337.62 2.50 MWD IFR MS 153 11316.94 89.25 295.01 32.72 6781.96 7626.07 7049.81 -2927.14 7633.34 337.45 3.01 MWD IFR MS 154 11347.80 91.48 293.98 30.86 6781.76 7649.55 7062.60 -2955.22 7655.95 337.29 7.96 MWD IFR MS 155 11380.58 92.09 294.28 32.78 6780.74 7674.34 7075.99 -2985.12 7679.88 337.13 2.07 MWD IFR MS 156 11411.97 92.30 292.41 31.39 6779.54 7697.80 7088.42 -3013.92 7702.56 336.97 5.99 MWD IFR MS 157 11444.26 93.02 291.92 32.29 6778.04 7721.47 7100.59 -3043.79 7725.48 336.80 2.70 MWD IFR MS 158 11476.39 93.64 293.42 32.13 6776.17 7745.20 7112.95 -3073.38 7748.54 336.63 5.04 MWD IFR MS 159 11508.80 93.40 294.08 32.41 6774.18 7769.54 7125.98 -3102.99 7772.27 336.47 2.16 MWD IFR MS 160 11541.44 92.44 292.56 32.64 6772.52 7793.90 7138.89 -3132.93 7796.08 336.31 5.50 MWD IFR MS 161 11573.31 91.65 291.50 31.87 6771.38 7817.23 7150.83 -3162.45 7818.92 336.14 4.15 MWD IFR MS 162 11605.54 92.40 292.45 32.23 6770.25 7840.79 7162.88 -3192.32 7842.06 335.98 3.75 MWD IFR MS 163 11637.88 93.02 293.66 32.34 6768.72 7864.84 7175.54 -3222.04 7865.74 335.82 4.20 MWD IFR MS 164 11668.93 92.30 293.42 31.05 6767.27 7888.10 7187.92 -3250.48 7888.72 335.67 2.44 MWD IFR MS 165 11701.53 92.61 294.04 32.60 6765.88 7912.60 7201.03 -3280.30 7912.98 335.51 2.12 MWD IFR MS 166 11733.72 93.19 293.00 32.19 6764.25 7936.70 7213.86 -3309.77 7936.90 335.35 3.70 MWD IFR MS 167 11765.45 94.12 293.87 31.73 6762.23 7960.41 7226.45 -3338.83 . 7960.49 335.20 4.01 MWD IFR MS 168 11797.29 93.84 294.48 31.84 6760.02 7984.46 7239.46 -3367.80 7984.48 335.05 2.10 MWD IFR MS 169 11829.73 93.71 294.34 32.44 6757.88 8009.06 7252.84 -3397.28 8009.07 334.90 0.59 MWD IFR MS 170 11861.30 93.54 292.94 31.57 6755.89 8032.73 7265.47 -3426.14 8032.78 334.75 4.46 MWD IFR MS 171 11893.48 93.57 292.51 32.18 6753.89 8056.51 7277.88 -3455.77 8056.66 334.60 1.34 MWD IFR MS 172 11925.00 93.36 292.64 31.52 6751.98 8079.76 7289.96 -3484.82 8080.06 334.45 0.78 MWD IFR MS 173 11956.79 93.16 291.71 31.79 6750.18 8103.05 7301.94 -3514.21 8103.57 334.30 2.99 MWD IFR MS 174 11989.01 94.22 292.14 32.22 6748.10 8126.56 7313.94 -3544.03 8127.36 334.15 3.55 MWD IFR MS 175 12020.40 94.60 291.80 31.39 6745.69 8149.46 7325.65 -3573.06 8150.58 334.00 1.62 MWD IFR MS 176 12053.91 177 12086.47 178 12118.03 94.74 292.17 33.51 94.91 292.59 32.56 95.43 293.13 31.56 Projection to Total Depth: 179 12173.00 96.24 293.13 54.97 6742.96 8173.90 7338.15 -3604.03 8175.42 333.84 6740.22 8197.79 7350.51 -3634.03 8199.76 333.69 6737.38 8221.11 7362.72 -3662.99 8223.57 333.55 6731.79 8261.87 7384.20 -3713.28 8265.28 333.30 1.18 MWD_IFR_MS 1.39 MWD_IFR_MS 2.37 MWD_IFR_MS 1.47 Projection to TD [(c)2005 IDEAL ID9_1C_02] • Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: AOGCC -Librarian Well No S-122PB1 Date Dispatched: 1-Sep-05 Installation/Rig Nabors lES Dispatched By: Mauricio Perdomo LWD Log Delivery V1.1,10-02-03 Data No Of Prints No of Floppies Surveys 2 9 Please Sign and return to: James H. Johnson Received By: BP Exploration (Alaska) Inc. Petrotechnical Data Center ILR2-11 900 E. Benson Blvd. Anchorage, Alaska 99508 Fax:907-564-4005 e-mail address: johnsojh~bp.com • • Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: AOGCC -Librarian Well No S-122PB2 Date Dispatched: 1-Sep-05 Installation/Rig Nabors 7ES Dispatched By: Mauricio Perdomo LWD Log Delivery V1.1, 10-02-03 Data No Of Prints No of Floppies Surveys 2 1 ~'~ ~~ f( ` ~• ~ Please sign and return to: JamePH. Johnson 1 y }t Received B : 1 -~~ rG1.Zr BP Ex loration (Alaska- Inc. Petrotechnical Data Center (LR2-1) 900 E. Benson Blvd. Anchorage, Alaska 99508 Fax:907-564-4005 e-mail address: johnsojh~b .com • Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer Well No Installation/Rig BP Exploration (Alaska- Inc. S-122P63 Nabors 7ES Dispatched To: AOGCC -Librarian Date Dispatched: t-Sep-05 Dispatched By: Mauricio Perdomo Data No Of Prints No of Floppies Surveys 2 1 ~ ~ ~ l Received By: - Please sign and return to: Drilling & Measurements LWD Division 2525 Gambell Street, Suite 400 Anchorage, Alaska 99501 nroselC~slb.com Fax: 907-561-8317 LWU Log Uellvery V1.1, lU-U"L-U3 ;~ 1, ~~ '" La ~ ~ J~'i l'~°. Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer BP Exploration (Alaska- Inc. Dispatched To: Well No Installation/Rig S-122 Nabors 7ES A06CC -Librarian Date Dispatched: 1-Sep-05 Dispatched By: Mauricio Perdomo Data No Of Prints No of Floppies Surveys 2 1 /~; ~ r ~ Please sign and return to: James H. Johnson Received By: ~",~ ~%~ BP Exploration (Alaska- Inc. Petrotechnical Data Center (LR2-1) 900 E. Benson Blvd. Anchorage, Alaska 99508 Fax:907-564-4005 e-mail address: johnso'h~b .com LWD Log DeliveryV1.1,10-02-03 ~'~r ~~- l J~ f ~.. gyro data ~ Gyrodata incorporated 1682 W. Sam Houston Pkwy. N Houston, Texas 77043 713/461-3146 Fax: 713/461-0920 August 9, 2005 Ms. Sharmaine Copeland BP Exploration (Alaska) Inc. 900 E. Benson Blvd. Anchorage, Alaska 99508 Re: S-Pad, Well #S-122 Nacth SI®pe, Alaska Enclosed, please find one (1) original, two (2) copies, and two (2) disks of the completed survey for the above referenced well. We would like to take this opportunity to thank you for using Gyrodata, and we look forward to serving you in the future. Sincerely, ~~ Rob Sho"up North American Operations Manager RS :tf Serving the Worldwide Energy Industry with Precision Survey instrumentation ~ ~ gyro data Gyrodata Incorporated 1682 W. Sam Houston Pkwy. N. Houston, Texas 77043 713/461-3146 Fax: 713/461-0920 SURVEY REPORT BP S-PAD #S-122 NABORS #7ES NORTH SLOPE, AK AK0705G_556 AUGUST 2, 2005 kiF.» y # i1 ~J Y `~..~" ;~. ~.' •.hP Serving the Worldwide Energy Industry with Precision Survey Instrumentation A Gyrodata Directional Survey for B.P. EXPLORATION Lease: S-PAD Well: S-122, 4" Drillpipe Location: Nabors #7ES, North Slope, Alaska Job Number: AK0705G 556 Run Date: 02 Aug 2005 Surveyor: Robert Williams; Henry Drew Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.355636 deg. N Longitude: 149.034151 deg. W Azimuth Correction: Gyro: Bearings are Relative to True North Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location • Horizontal Coordinates Calculated from Well Head Location B.P. Exploration Lease: S-PAD Well: S-122, 4" Drillpipe Location: Nabors #7ES, North Slope, Alaska Job Number: AK0705G 556 MEASURED I N C L AZIMUTH DEPTH feet deg. deg. A Gyrodata Directional Survey BORE HOLE BEARING deg. min. DOGLEG SEVERITY deg./ 100 ft. VERTICAL CLOSURE HORIZONTAL DEPTH DIST. AZIMUTH COORDINATES feet feet deg. feet 0.00 0.00 0.00 N 0 0 E 0.00 0.00 0.0 0.0 0.00 N 0.00 E ------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------- 0 - 1562 FT. RATE GYROSCOPIC SURVEY RUN INSIDE 4" DRILLPIPE ALL MEASURED DEPTHS AND COORDINATES REFERENCED TO NABORS #7ES R.K.B. OF 64.20 FT. MSL ------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------- 76.00 0.46 357.51 N 2 29 W 0.61 76.00 0.3 357.5 0.31 N 0.01 W 100.00 0.35 24.42 N 24 25 E 0.91 100.00 0.5 1.5 0.47 N 0.01 E 198.00 0.14 17.76 N 17 45 E 0.21 198.00 0.9 11.4 0.86 N 0.17 E 250.00 0.82 128.20 S 51 48 E 1.68 250.00 0.8 35.1 0.69 N 0.48 E 300.00 1.38 131.84 S 48 10 E 1.13 299.99 1.2 86.9 0.07 N 1.21 E 349.00 2.46 116.46 S 63 32 E 2.43 348.96 2.7 107.1 0.80 S 2.59 E 438.00 4.60 109.24 S 70 46 E 2.45 437.78 8.2 110.2 2.82 S 7.68 E 500.00 4.50 121.68 S 58 19 E 1.60 499.59 13.1 112.1 4.92 S 12.10 E 550.00 3.76 126.03 S 53 58 E 1.61 549.46 16.6 114.6 6.92 S 15.09 E 650.00 2.62 149.64 S 30 22 E 1.72 649.31 21.8 119.8 10.82 S 18.90 E 708.00 2.61 158.31 S 21 41 E 0.68 707.25 24.0 123.3 13.19 S 20.05 E 800.00 2.20 159.68 S 20 19 E 0.46 799.17 27.2 128.1 16.79 S 21.44 E 893.00 2.38 160.82 S 19 11 E 0.20 892.09 30.4 131.8 20.29 S 22.70 E 925.00 2.29 157.96 S 22 2 E 0.46 924.07 31.6 132.9 21.51 S 23.15 E 1000.00 1.65 172.65 S 7 21 E 1.08 999.02 33.8 135.1 23.97 S 23.85 E 1079.00 1.59 290.46 N 69 32 W 3.52 1078.01 33.7 137.1 24.71 S 22.97 E 1100.00 1.85 294.16 N 65 50 W 1.31 1099.00 33.2 137.5 24.47 S 22.39 E • 2 A Gyrodata Directional Survey B.P. Exploration Lease: S-PAD Well: 5-122, 4 " Drillpipe Location: Nabors #7ES, North Slope, Alaska Job Number: AK0705G 556 MEASURED I N C L AZIMUTH BORE HOLE DOGLEG VERTICAL CLOS URE HORIZONTAL DEPTH BEARING SEVERITY DEPTH DIST. AZIMUTH COORDINATES feet deg. deg. deg. min. deg./ feet feet deg. feet 100 ft. 1200.00 2.59 300.25 N 59 45 W 0.78 1198.92 29.6 140.1 22.67 S 18.96E 1250.00 2.69 299.72 N 60 17 W 0.20 1248.87 27.4 141.8 21.52 S • 16.97 E 1300.00 3.79 296.81 N 63 11 W 2.23 1298.79 24.8 144.4 20.20 S 14.47 E 1350.00 5.35 295.83 N 64 10 W 3.12 1348.63 21.4 149.4 18.43 S 10.90 E 1400.00 6.74 295.32 N 64 41 W 2.77 1398.35 17.3 159.2 16.16 S 6.15 E 1450.00 9.86 294.86 N 65 8 W 6.25 1447.82 13.1 181.7 13.11 S 0.39 W 1500.00 11.78 293.85 N 66 9 W 3.86 1496.93 12.9 224.0 9.24 S $.94 W 1550.00 12.79 294.19 N 65 49 W 2.02 1545.78 19.3 255.2 4.91 S 18.66 W 1562.00 13.12 292.08 N 67 55 W 4.82 1557.48 21.5 259.7 3.86 S 21.13 W Final Station Closure: Distance: 21.48 ft Az: 259.66 deg. • 3 B.P. Exploration Well: S-Pad S-122 4" Drillpipe Location: Nabors #7ES, North Slope, Alaska 0- -5 ..., -10 .. z 0 z -15 -20 -25 Outrun Gyrodata AK0705G 556 DEFINITIVE I ~, -- --C B _ L M~ _ • ~ ---- i TTOM HOLE CATED : 1562.00 ~ ~ - . ~ ~ ~ ,~-- -------- ----- --- -- ------i - ~ ~-- -- 1 ---- -- ~ -- ---- -~~ _ ® I I _J ~ i --_ ~ ~~_ ~ ~ i i ~ i ~ -20 -15 -10 -5 0 5 10 15 20 25 FASTING (ft) • • 0 0 a~ a~ ... w w C7 w J O D B.P. Exploration Well: S-Pad S-122 4" Drillpipe Location: Nabors #7ES, North Slope, Alaska 10 9- 8- 7- 6- 5 4- 3 2 1 0- 0 Outrun Gyrodata AK0705G 556 DEFINITIVE _ - - ------ ~ ~ ~ i I I ---- -----i - - - BOTTOM-FfOt ! LOCATED MD: 1562.00 --__ --- - ----- - -~ d -~ ~ - - --- ~--- _ j' _ _ - ~ ~ - ~~~ -^ I i __. i ~ 250 500 750 1000 1250 1500 1750 MEASURED DEPTH (ft) J z 0 Q Z J U Z B.P. Exploration Well: S-Pad S-122 4" Drillpipe Location: Nabors #7ES, North Slope 12.5 - 10.0 7.5 5.0 2.5 0.0 Ol~cka Y Outrun Gyrodata AK0705G 556 DEFINITIVE - I - - i ~ ~ BOTTOM HO LOCATED MD: 1562.0 E ;~ -- ~ ~' I ~ ~ ~ I i~ A s---_ ~ ~_- - __ -- -- ~_s. e __ __ __ i ~s ~ ~ i ~ 0 250 500 750 1000 1250 1500 1750 MEASURED DEPTH (ft) B.P. Exploration Well: S-Pad S-122 4" Drillpipe Location: Nabors #7ES, North Slope, Alaska 160.0 - 140.0 - 120.0 - 100.0 - 80.0 - ~ 60.0 - Q 40.0 - 20.0 0.0 - 340.0 320.0 300.0 280.0 0 Outrun Gyrodata AK0705G 556 DEFINITIVE ~ ~I I _~ ~ I _ ---- __. ____-__ ~_1 ___~ ---------- -- I - i ~ ____ ~-- I - ----~ ~ -- I j ~ ; ~ , - -- ~ , ', II I- _- . BOTTOM H OL s~ _. __~---e ~ _~ _ ___~ MD: 1562. 0 ~ ~ i ~ 250 500 750 1000 1250 1500 1750 MEASURED DEPTH (ft) • 2.~~- arc • Subject: FW: S-122 Intermediate Cement Job From: "Gagliardi, Shane T" <gaglst@BP.com> Date: Mon, 15 Aug 2005 12:03:23 -0800 To" Winton aul~ert cl~admin.state.~k.us CC: tom_mau~nder@admin.state.ak.us Winton, There was a fault in the surface hole in S-122 that caused some confusion as to where we were in the section. Consequently, we missed our initial surface casing point and had to set surface casing 600' deep compared to the prognosis. This will be an issue for the intermediate casing cement job. By covering the UG4A with 500' of cement, the calculated TOC will only be 300' from the surface casing shoe. I would like to have at least 500' for the shoe to calculated cement top to ensure the OA remains open as per our conversation. Thanks, Shane Zr~s-~$t Subject: S-122 Adjustments From:."Gagliardi, Shane T" <gaglst@BP.c©m> Date: Mon, 01 Aud 2005 12:41:07 -0800 To: winton_aubert@admin.state.ak.us Winton, Due to shallow water communication issues, we have had to run a short string of 13-3/8" casing from surface to 535'. The casing has been cemented back to surface and cut 10 inches below the landing ring. Cement samples indicate a good set at this point. We are currently running in the hole with our original 12-1/4" BHA and bit, drilling should resume and the current approved plan followed without change from this point forward. Thanks, Shane MEMORANDUM State of Alaska TO: Jim Regg ~~5~d 5 P. I. Supervisor ~~ Alaska Oil and Gas Conservation Commission DATE: August 1, 2005 FROM: John Crisp, Petroleum Inspector SUBJECT: 13 3/8 casing cement PBU# ~'-122 BPX PTD 205-081 August 1, 2005: I traveled to BP's PBU S Pad to witness the cement job on 13 3/8" casing cemented from 533' to surface. History of events leading to the RIH & cementing of 13 3/8 casing on PBU S-122 were: #1. Communication of drilling fluids to water that caused water influx in PBU S- 216's cellar. #2. Total mud loss of approximately 200 bbl's drilling mud while drilling from conductor shoe to 533' MD on S-122. #3. After doing cement job on S-216 between conductor & surface casing to a depth of 74', seepage was noticed on two other S Pad wells after drilling operations were continued. I witnessed a total of 147 bbl's of 15.7 to 15.8 cement circulated around 13 3/8 casing. After cement was circulated outside of 13" shoe, 21 bbl's were lost to formation before circulation was re-established. Cement was not circulated to surface, all indications were that cement was between 13 3/8" casing & conductor after displacing cement. Summary: I Inspected ail cellars before & after cement job & found no indications of drilling mud to surface. S Pad & surrounding tundra was inspected with no indication of mud to surface. Operator indicating the procedure for conductor repair was unsuccessful has made no contact. Attachments: None Non-Confidential Cement job PBU S-122 08-O1-OS jc.doc PBU S-122 (~i~ ~ 2~S-cog I Subject: PBU 5-122 From:.Tohn Crisp<john_cris~~~admn.state.ak.us> Date: Sun. l Tul 2~it~5 17:1 G:-~~ OSOt) -~-~ ~ (~~ ,~ c~-; "f~o: Jim FZe~T~ slim Ic~T~~("«?adt»in.statc.ak_us= ~~ I witnessed a Diverter test on Nabors 7ES PBU S-122 late 7/29/05. Got a call from Nabors 7ES 7/30/05 on PBU S-122 that they had a fresh water flow from the conductor on 5-216 while drilling 5-122 ~ 263'. Drilling was halted & a conductor cement job was performed on S-216 from 74' to surface. Rig WOC for 4 hours & continued drilling. A 200 bbl mud loss was encountered on S-122 ~ 533'. Slight fresh water flow was seen on conductors S-120 & 5-117. I inspected cellars, Pad & surrounding tundra on PBU S Pad for any mud that had broached to Surface. I saw no mud anywhere on Pad or surrounding tundra. The Rig is presently going to open the 12.25 hole drilled to 533' to 16" & run 13 3/8" casing & cement to surface. I requested they call me before RIH w/ casing so I could witness 13 3/8" cement job to surface. I witnessed a BOP test on Nabors 2ES PBU 14-30A 7/30/05. Kuparuk is contacting North Slope Office to allow us to witness MIT's on monobores. The timing has not been good so far but I intend to witness 1C-116 MIT tomorrow. I am trying to set up Misc SVS WOA for tomorrow. I have PBU DS 04 set up for 8/2/05. Nordic 1 is coming off Summer maintenance & I will try to witness BOP test. I am making PBU S-122 a priority. I hope this is appropriate. 1 of 1 8/1/2005 11:58 AM ( , , , ~ ~ ~ a FRANK H. MURKOWSKf, GOVERNOR ~~ L~ast>•-7~ OIL ~~ ti0-7 "~A 333 W. 7"' AVENUE, SUITE 100 C0111j.~1L'RVA'1'IOI~T COMl~'IISSIOIQ ~'f ANCHORAGE, ALASKA 99501-3539 PHONE (907} 279-1433 FAX (907) 276-7542 Robert Tirpack Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay 5-122 BP Exploration (Alaska) Inc. Permit No: 205-081 Surface Location: 4391' FSL, 4499' FEL, SEC. 35, T12N, R12E, UM Bottomhole Location: 1035' FSL, 2576' FEL, SEC. 22, T12N, R12E, UM Dear Mr. Tirpack: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Pl se provide at least twenty-four (24} hours notice for a representative of the Commission tness any required test. Contact the Commission's petroleum field inspector at~90~b59 ager). "Chairman DATED this' da of Ma 2005 Y Y~ cc: Department of Fish 8e Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. / I ~~~" Sj~Z~~tn@S ' ' `' STATE OF ALASKA ~~ ALAS'TA OIL AND GAS CONSERVATIONMMISSION ;,~ ,, PERMIT TO DRILL ~~ ~~ ~~~~~ tz 20 AAC 25.005 ` ~~~' ~ 'I ~, .~ ~ ~- ,. ~.~.:.~ .~.~~ 1a. Type of work ®Drill ^ Redrill ^ Re-Entry 1b. Current Well Class ^ Exploratory ®Development '~1` li~~~ple Zone ^ Stratigraphic Test ^ Service ^Development Gas ^ Single Zone 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 2S100302630-277 11. Well Name and Number: PBU 5-122 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 11797 TVD 6774 12. Field /Pool(s): Prudhoe Bay Field /Aurora Pool 4a. Location of Well (Governmental Section): Surface: 4391' NSL 4499' WEL SEC 35 T12N R12E UM '~ 7. Property Designation: ADL 028256 , , . , , , Top of Productive Horizon: 701' NSL, 1816' WEL, SEC. 22, T12N, R12E, UM 8. Land Use Permit: 13. Approximate Spud Date: June 25, 2005 /~ Total Depth: 1035' NSL, 2576' WEL, SEC. 22, T12N, R12E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 1,500' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 618930 - 5980595 Zone- ASP4 10. KB Elevation {Height above GL):Plan 64.1 feet 15. Distance to Nearest Well Within Pool 1,775 to S-103 16. Deviated Wells: Kickoff Depth: 400 feet Maximum Hole Angle: 98 de rees 17. Maximum Anticipated ~'ressures in psig (see 20 AAC 25.035) Downhole: 3495 / Surface: 2808 ~ 18. acing rogram: Size Specifications Setting Depth To Bottom uantity o emenf c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 42" 20" 215.5# A-53 Weld 80' 29' 29' 109' 109' 60 sx Arctic Set A rox. 12-1/4" 9-5/8" 40# L-80 BTC 3071' 29' 29' 3100' 2814' 59 sx Arcticset Lite, 238 sx'G' 8-3/4" 7" 26# L-80 BTC-M 10806' 29' 29' 10835' 7056' 25 sx Class 'G', 182 x Class 'G' 6-1/8" 4-1/2" 11.6# L-80 LTC 1587' 10210' 6734' 11797' 6774' 07 sx Class 'G' 19. PRESENT W ELL CONDITION SUMMARY (To be completed for Redrill-AND. Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD {ft): Junk (measured): Casin Len th Size Cement Volume MD TVD r n c r ro Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments ®Filing Fee, $100 ^ BOP Sketch ® Property Plat ^ Diverter Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ 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 to the best of my knowledge. Contact Shane Gagliardi, 564-5251 Printed Name Robert Tirpack Title Senior Drilling Engineer T Preparetl By Name/Number: Si nature ,~ ~ Phone 564-4166 Date ~/may Terrie Hubble, 564-x628 Commission Use Only Permit To Drill Number: O ... API Number: 50- D2. - 2 ,3 .2. ~ ~ Permit Approval Date: ~`f~ ~ d ~ See cover letter for other requirements Conditions of Approval: Sample Required g. Hydr ge Sulfide Measures Other: ~ ~..~,4' ~~ 35~G ~ f-c,~ , A roved i3 ,~~, Yes ~No Mud Log Required ~ ~, Yes ~,'No 'Yes ^ No Directional Survey Required Yes ^ No PPROVED BY CJs/~ HE COMMISSION Dat v- Form 10-401 Revised 06/~QQi/ ~ "' ° ' "" ~ ' - - ~ubmi~/In Duplicate Well Name: S-122 Well Plan Summary T e of Well roducer or in'ector : Horizontal Producer Surface Location: 4,391' FSL, 4,499' FEL, Sec. 35, T12N, R12E X = 618,930 Y = 5,980,595 S-122 Target 1 Kuparuk C: 701' FSL, 1,816' FEL, Sec. 22, T12N, R12E~ X = 616,216 Y = 5,987,422 Z = 6,734' TVDss S-122 Production BHL: 1,035' FSL, 2,576' FEL, Sec. 22, T12N, R12E X = 615,449 Y = 5,987,744 Z = 6,774' TVDss AFE Number: AUD5M0087 Rid: _ Nabors 7ES ~~ GL: 35.T KB: 28.5' Estimated Start Date: June, 25 2005 O eratin da s to com lete: 25.7 TD: 11,797' MD TVD: 6,774' Max Inc: 98.08° KBE: 64.1' Well Design: USH Grassroots Producer 4-'/Z" IBT-M Com letion. ~ The Kuparuk C sand will have a 4-'/z" LT&C liner com letion. Current Well Information General Distance to Nearest Property: 1,500' to the nearest PBU property line Distance to Nearest Well in Pool: 1,775' from S-122 to S-103 API Number: 50-029-XXXXX Weli Type: Development -Aurora Producer Current Status: New well, 20" X 34" insulated conductor Conductor: 20" X 34", 215.5 Ib/ft, A53 ERW set at 109' RKB BHP: 3,350 psi C~ 6,855' TVDss (9.4 ppg EMW). ~ BHT: 144°F C~ 6,710' TVDss estimated Casina/Tubina Program Hole Size Csg / Tb O.D. WUFt Grade l Conn / Burst si Collapse si Length Top MD /TVDrkb Bottom MD !TVDrkb 42" 20" 215.5# A-53 Weld 80' 29' ! 29' 109' / 109' 12-'/a" 9-5/s" 40# L-80 BTC 5,750 3,090 3,071' 29' / 29' 3,100' / 2,814' 8-3/a" 7" 26# L-80 BTC-M 7,240 5,410 10,806' 29' / 29' 10,835' / 7,056' 6-'/s" 4-'h" 11.6# L-80 LTC 6,350 7,780 1,587' 10,210' / 6734' 11,797' ! 6,774' Tubin 4-%i" 12.60# L-80 IBT-M 8,430 7,500 10,031' 29' / 29' 10,060' / 6,657' S-122 Permit to Drill Page 1 Formation Markers S-122 (Based on Schlumberger P61 (P2b)) Formation To s MD TVD TVDss Pore si EMW H drocarbons G1 404 404 340 176 8.4 No SV6 1,604 1,599 1,535 698 8.4 No Base Permafrost 1,949 1,924 1,860 No Fault #1 2,213 2,164 2,100 SV5 2,235 2,184 2,120 954 8.4 SV4 2,434 2,354 2,290 1,028 8.4 No SV3 2,911 2,714 2,650 1,185 8.4 No SV2 3,227 2,904 2,840 1,268 8.4 No SV1 3,792 3,214 3,150 1,404 8.4 No UG4 4,452 3,579 3,515 1,563 8.4 No UG4A 4,497 3,604 3,540 1,574 8.4 Yes UG3 5,085 3,929 3,865 1,716 8.4 Yes UG1 6,079 4,479 4,415 1,956 8.4 Yes To Schrader/Ma Sand 6,631 4,784 4,720 2,090 8.4 Yes Na 7,083 5,034 4,970 2,199 8.4 Yes OA 7,260 5,132 5,068 2,242 8.4 Yes Obf Base 7,806 5,434 5,370 2,374 8.4 No Fault #2 8,348 5,734 5,670 CM1 Colville Shales 9,561 6,399 6,335 No Fault #3 9,610 6,424 6,360 THRZ 10,036 6,644 6,580 No Kalubik 10,152 6,704 6,640 No TKUP 10,172 6,714 6,650 Yes Ku aruk C 10,172 6,714 6,650 3,200 9.2 Yes LCU Ku aruk B 10,569 6,919 6,855 3,350 9.4 No Ku aruk A 10,734 7,004 6,940 No Intermediate T.D. ~ 10,835 7,056 6,992 Fault #4 11,600 6,746 6,680 Production T.D." 11,797 6,774 6,710 "Intermediate TD is based on 100' MD below the LCU (Kuparuk B)" "'' Production TD is based on 50' short of polygon hardline "" Mud Pro ram: 12'/a" Surface Hole Mud Properties: Spud -Freshwater Mud Interval Densi Funnel Vis PV YP FL Chlorides PH Initial 8.8 - 9.2 250-300 20-45 50-70 NC-8.0 <500 9.0-9.5 Base Perm 9.2 - 9.5 225-250 20-40 45-60 8.0 <500 9.0-9.5 Interval TD <9.5 225-250 20-26 40-50 < 7.5 <500 9.0-9.5 8 ~/o" Intermediate Hole Mud Properties: Freshwater Mud (LSND) Interval Density Funnel Vis PV YP FL HTHP FL pH Chlorides MBT 3,067' - 9,500' 8.8 45-60 12-18 20-26 4.0-7.0 N/C 9.0-9.5 <600 < 15 9,500' - 10,834' 0.5 45-60 14-22 20-26 3.0-5.0 8.0 -10.0 9.0-9.5 <600 < 20 6'/8" Production Hole Mud Properties: (KUP C Only) Freshwater Mud (Flo Pro NT) nterval Density PV YP LSRV HTHP FL pH in C«~ 10,210' 9.4 10 - 18 30 - 35 >20,000 4 - 6 9.0 - 9.5 10,210-11,796' 9.4-9.7 10-20 18-22 >20,000 4-6 9.0-9.5 ~.~ Id ~l. ~ S-122 Permit to Drill Page 2 ,~ Survev and Loaaina Program: s 12-'/0" Hole Section: Surface Gyro will be needed (run to 1200' or as conditions dictate) O en Hole: MWD / GR Cased hole: None 8-~/a" Hole Section: MWD / GR /Res /Den / Neu / PWD (Neu/Den in record mode, GR/Res Real Time) Cased Hole: None 6-'/e" Hole Section: MWD / GR /Res /Den / Neu / ABI (All real time) Cased Hole: None Surface and Anti-Collision Issues Surface Shut-in Wells: Nearb Well S-115 S-117 Distance to Nearb Well 14.74' 15.01' S-115 and S-117 will require surface shut-in and well house removal in order to move over well S-122. Close Approach Shut-in Wells: There are NO close approach wells requiring subsurface isolation for this profile. Close Approach Well List: Well Name Ctr-Ctr Distance Reference MD Allowable Deviation Precautiona Comment S-100 46.18-ft 299-ft 40.88-ft Use Travelin C linden G ro S-101 22.97-ft 449-ft 13.56-ft Use Travelin C linder G ro S-102 61.91-ft 250-ft 57.07-ft Use Travelin C linder G ro S-109 75.54-ft 448-ft 67.57-ft Use Travelin C linder G ro S-110 87.79-ft 443-ft 78.40-ft Use Travelin C linder G ro S-112 45.67-ft 795-ft 30.75-ft Use Travelin C linder G ro S-115 12.22-ft 550-ft 2.46-ft Use Travelin C linder G ro 5-117 14.00-ft 600-ft 3.19-ft Use Travelin C linder G ro S-118 95.77-ft 754-ft 83.03 Use Travelin C linder G ro S-120 31.64-ft 500-ft 22.22-ft Use Travelin C linder G ro S-200 49.78-ft 1650-ft 29.41-ft Use Travelin C linder G ro S-213 30.94-ft 1400-ft 13.09-ft Use Travelin C linder G ro S-216 76.85-ft 400-ft 68.5-ft Use Travelin C linder G ro Cement Calculations: Casin Size: 9 5/8" in 40-Ib/ft L-80 BTC -Sin le Sty Basis: Lead: 250% a es over gauge hole in perm. Lead TOC: urf Tail: 668' of n hole with 30% excess, plus Tail TOC: 2,400' MD Total Cement Volume: Spacer 80 bbls of Viscosif~ Lead 426 bbls, 2,392 ft Tail 49.6 bbls, 279 ft ~ Temp BHST ~ 40° F. BHC 30% excess over gauge hole below permafrost trac acer weighted to 10.0 ppg (Mud .asia II) sks 10.7 ASL G + adds - /sl sks 15.8 Class G + adds - .17 /sk 65° F estimated by Schlumberger ~" 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: 7" 26 Ib/ft L-80 BTC-M -Single Stage Basis: Lead: 5,838' o n hole with 30% excess over gauge hole Lead TOC: ,9 MD 500' MD above tanned UG4A to at 4,497' MD Tail: 1,663' o open hole with 30% excess, plus 86' shoe track Tail TOC: 9,172' MD 1000' MD above tanned to KUP C at 10,172' Total Cement Volume: Spacer 50 bbls of Viscosifi acer (Mudpush II Design) ted to 11.3 ppg Lead 223 bbls, 1252 ft sks 12.0 G + adds T /sk Tail 38 bbls, 213 ft , 8 sks 15.8 G + Gasblok ~`Y":17 /sk Temp BHST =144° F, B CT 124° F estimated by Schlum erger S-122 Permit to Drill Page 3 - • • Size 14-'/2" Production Liner Basis: Tail: Based on 2,047' of open hole w/ 3 xcess + 200' excess (4" DP) + 86' shoe track + 150' overlap Cement Placement: From shoe to 1 ,0 MD TOL Total Cement Volume: Lead Tail 43 bbls / 29~-#t / 20 ks of Dowel! Premium "G" with Gasblok at 15.8 Centraiizer Recommendations: 9-5/e" Casing Centralizer Placement a) Run (25) 9 5/e" Bow-spring centralizers attached over the collar of each joint of casing from the casing shoe up to 2,100' MD (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" String Centralizer Placement a) Place 1 rigid straight blade centralizer on every joint for the first 14 joints. Do not run any centralizers on the next two full joints. b) With the exception stated above, run one centralizer per joint, floating across the entire joint up to 3,997' MD (500' MD above UG4A sand). Zonal isolation with cement is required across the UG4A sands. The centralizer program is subject to change pending modeling and hole conditions. 4'/z" Liner Centralizer Placement a) Place 1 rigid straight blade centralizer per joint, floating across the entire joint up to 10,294' MD (two joints from window). Well Control Well control equipment consisting of 5,000 psi working pressure pipe rams (2), blind/shear rams, and annular preventer will be installed and are capable of handling the maxim otential surface pressures. Based upon calculations below, BOP equipment will be tested to psi. Due to anticipated surface pressures not exceeding 3,000 psi, it will not be necessary to have two set of pipe rams installed at all times. ~ BOP regular test frequency for S-122 will be 14 days. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Intermediate Section • Maximum anticipated BHP: • Maximum surface pressure: • Planned BOP test pressure: • 7" Casing Test: • Integrity Test - 8-3/4" hole: • Kick Tolerance: • Planned completion fluid: Production Section • Maximum anticipated BHP: • Maximum surface pressure: • Planned BOP test pressure: • 4'/z" Casing Test: • Integrity Test - 6-'/a" hole: • Kick Tolerance: • Planned completion fluid: S-122 Permit to Drill 3,495 psi -Base of Kuparuk B (9.8 ppg C~ 6,855' TVDss)/ 2,808 psi -Based on a full column of gas ~ 0.10 psi/ft 3,500 psi/250 psi Rams 2,500 psi/250 psi Annular 3,500 psi 1 -ppg minimum EMW LOT 20' from 9 5/s" shoe 5. '`bbls with an 11.2 ppg EMW LOT timated 9.0 ppg Brine / 6.8 ppg Diesel 3,200 psi -Base of Kuparuk C (9.2 ppg @ 6,650' TVDss) j 2,535 psi -Based on a full column of gas @ 0.10 psi/ft ~ 3,500 psi/250 psi Rams 2,500 psi/250 psi Annular 3,500 psi 11 g minimum EMW FIT 20' from 7° shoe fini~~ fl5tifnated 9.4 ppg Brine / 6.8 ppg Diesel Page 4 • • Disposal • No annular injection in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS- 04. Any metal cuttings will be sent to the North Slope Borough. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I waste to Pad 3 for disposal. S-122 Permit to Drill Page 5 Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE Well Control A. The Ugnu may be slightly over pressured. A 10.5 ppg EMW was required in S-200; subsequent RFT / showed EMW to be 10.7 ppg. This interval was successfully drilled with a 8.9 ppg mud in S-111 recently. The over pressure in S-200 is suspected to be due to field operations/injection at that time and has not been encountered since. Hydrates and Shallow gas A. Gas Hydrates are present at S-pad and have been encountered in wells as close as S-113, S-114, S- 106 and S-102 throughout the SV5, SV4 and SV3. Setting casing through the SV3 should keep hydrate exposure from extending past the surface hole. Occasionally hydrates are encountered below the SV1. Recommended practices and precautions for drilling hydrates should be followed in the surface hole. 111. Lost Circulation/Breathing A. Lost circulation is possible. S-114 had losses of 1621 bbls and S-106 had losses of 1370 bbls. B. We do not expect breathing on this well; however S-100i, S-105 and S-106 experienced breathing issues. IV. Kick Tolerance/Integrity Testing A. The 9 5/8" casing will be cemented to surface. l B. The 7" casing will be cemented with 15.8 Ib/gal tail and 12.0 Ib/gal lead cement to 500' MD above the Top UG4A -3,997 MD. -~ a. The Kick Tolerance for the surface casing i 55 bbls with 10.5 ppg mud, 11.2 ppg LOT, and a 9.4 ppg pore pressure. Integrity Testing - "ppg EMW LOT C. The 4-%z" production liner will be cemented with 15.8 ppg tail cement to the liner top. a. The Kick Tolerance for the intermediate casing is infinte with 9.4 ppg mud, 11.0 ppg FIT and a 9.2 ppg pore pressure. Integrity Testing -11.0 ppg EMW FIT v. Stuck Pipe A. Gravel beds below the Permafrost will tend to slough in when aerated (hydrate cut) mud is being circulated out. Ensure adequate mud viscosity is maintained to avoid stuck pipe situations. B. Tight hole, hole packing-off, and lost returns have been encountered in previous wells on this pad. Pipe sticking tendency is possible if the HRZ shale gives problems. Back reaming at connections and good hole cleaning practices will contribute to favorable hole conditions C. We do not expect stuck pipe if the hole is kept adequately clean. VI. Hydrogen Sulfide S Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. Recent H2S data from the pad is as follows: Adjacent producers at Surface: Adjacent producers at TD: S-115 10 ppm S-102 20 ppm / S-117 20 ppm S-103 10 ppm VII. faults A. Four faults are expected to be crossed by S-122. No losses are expected to be associated with the faults. Details are listed below for reference: Fault 1 (Below SV-5): Fault 2 (Below Schrader Obf): Fault 3 (Above HRZ): Fault 4 (Kup HAW): 2,213' MD 2,164' TVD 8,348' MD 5,734' TVD 9,610' MD 6,424 TVD 11,600 MD 6,774 TVD 2,100' TVDss Throw: 80' W 5,670' TVDss Throw: 60' SE 6,360' TVDss Throw: 40' E 6,680' TVDss Throw: 50' W CONSULT THE S PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION S-122 Permit to Drill Page 6 S-122 Drill and Complete Procedure Summary Pre-Rig Work: 1. The S-122 conductor has been set between S-115 and S-117 Wells. 2. Weld an FMC landing ring for the FMC Gen 5 Wellhead on the conductor. 3. If necessary, level the pad and prepare location for rig move. 4. Prepare neighboring wells for the rig move and simops production. Shut in S-115 and S-117; remove well house as necessary. Rig Operations: 1. MIRU Nabors 9ES. 2. Nipple up diverter spool and function test diverter.~PU 4" DP as required and stand back in derrick. 3. MU 12-~/a" drilling assembly with Dir/GR and directionally drill surface hole to approximately 3,100' MD. The actual /° surface hole TD will be +l-100' TVD below the top of the SV3 sands. An intermediate wiper/bit trip to surface will be performed prior to exiting the permafrost. 4. Run and cement the 9 5/e", 40.0-Ib/ft. surface casing..baek'to surface. A TAM Port Collar should be on location; however, lost circulation is not expected. A TAM port collar will be run in the casing string only if hole conditions dictate. Bump plug and ensure that floats hold. ND diverter spool and NU casing /tubing head. NU BOPE and test to 3,500 psi. 5. MU 8-3/a" drilling assembly with Dir/GR/Res/Azi-Den/Neu(recorded)/PWD and RIH to float collar. Circulate and condition cement contaminated mud. Displace over to new 8.8 ppg LSND mud. 6. Test the 9-5/e" casing to 3,500 psi for 30 minutes. ~ 7. Drill new formation to 20' below 9 5/8" shoe and perform LOT. If a 11.2 ppg EMW is not obtained contact ODE. r 8. Drill tot 200' above the HRZ, ensure mud is conditioned and weighted to 10.5 ppg and perform short trip as needed. Ensure pre-reservoir meeting is held highlighting kick tolerance and detection prior to entering the HRZ. 9. Drill ahead to target TD at 10,835' MD, (approx 100' MD below LCU Kup B). /~ 10. Circulate and condition hole, POOH to run casing. Perform wiper trip ONLY if hole conditions dictate. 11. Run and cement the 7" prg.duction casing. Displace the casing with 9.4 ppg Flo-pro NT mud during cementing / operations. Bump plug and ensure that float holds. Freeze protect the 7" x 9-%a" annulus. 12. RU Schlumberger a-line. RIH w/ GR-000JB to float collar. MU 7" EZSV and RIH. Set (at 10,223 MD) such that Baker window top is at top Kuparuk C sand (10,210' MD). 13. Pressure test casing to 3,500 psi for 30 minutes. 14. MU and RIH w/ 7" Whipstock assembly. Set Whipstock such that window top is at the top of the Kuparuk Csand / (10,210' MD). Mill Window and drill 20' of new formation. Perform FIT test to 11.0 ppg EMW. POOH and LD milling. assembly. 15. MU 6-''/B"drilling assembly with MWD / GR / Res /Den / Neu (All real time). 16. Build to horizontal C~3 18°/100 ft w/ Short Pak assembly to 98° C~3 approximately 10,455'. Make bit trip, change assembly and then drill ahead to proposed TD ~ 11,797'MD / 6,774' TVD. Short trip as required and condition hole for running 4- '/z" liner. 17. Run 4-~/z "solid liner. There will be 150' of overlap into the 7" intermediate casing. Cement liner as directed. Set iine~ top packer. Release from liner and displace well to filtered 9.4 ppg KCI brine and POOH. 18. PU DPC guns and RIH w/ -1,000' of 2-'/z" Omega PJ 6 spf, 60° phasing pert guns. Tag PBTD for depth control. 19. Run 4-1/2" 11.6 ppf, L-80 LT&C completion w/ Halliburton pressure gauge (C~ 9,981' MD). RILDS Set packer C~1 10,003 MD and test tubing to 3,500 psi and annulus to 3,500 psi for 30 minutes. 20. Shear DCK valve and install TWC. 21. Nipple down the BOPE. Nipple up and test the tree to 5,000 psi. Remove TWC. 22. RU hot oil truck. Freeze protect the well from lowest GLM. Install BPV in tubing hanger. Install a VR plug in the 7"x 4-~/z° ~ annulus valve and secure the well. Ensure that IA/OA are both protected with two barriers. 23. Rig down and move off. Post-Rig Work: 1. R/U Slickline and pull ball and rod / RHC. 2. Replace the DCK shear valve with a dummy GLV. 3. Pull dummy valves in injection mandrels and replace with injection valves. 4. Pull VR plug. S-122 Permit to Drill Page 7 S-122 Detailed Drilling Procedure Job 1: MIRU Critical Issues: - Ensure the starting head has been welded on the conductor at the right height and there is adequate space to NU the diverter and subsequently the BOP once the rig is spotted. Confirm this requirement prior to the rig moving over the well. Verify that the Diverter does not require any additional spacer spools as well - Ensure the AOGCC receives 24-hour advance notification of the diverter test and subsequent BOP tests. - S-115 and S-117 will have to be shut in and require wellhouse removal before rig can be moved over the well. All surface flowlines and gas lift lines will need to be depressurized to header pressure. Discuss the move at a pre-job safety meeting and designate a spotter to ensure there is no danger of a collision. Nearb Wells Distance to S-115 15' Distance to S-117 15' - S Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. Adjacent producers at Surface: S-115 10 ppm S-117 20 ppm Adjacent producers at TD: S-103 10 ppm S-102 20 ppm The maximum level of H2S recently recorded on the pad was ~60 ppm from S-40A. The maximum level ever recorded on the pad was -130 ppm from S-32 back in 3/2001. Both of these wells are Ivishak producers while the above welts and subject well are Kuparuk wells. Reference SOP: • "Drilling/ Work over Close Proximity Surface and Subsurface Wells Procedure" Job 2: Drill 12~/a" Surface Hole Critical Issues: - At S-Pad, no significant surface hole drilling problems are present. Tight hole, bridging, and obstructions have been encountered while drilling the Permafrost. In several wells reaming and tight hole have been present with a few examples of lost circulation while cementing. One fault will be encountered in the surface hole that may cause a loss of circulation. - Close Approach: S-115 and S-117 will be required to be shut in and have the wellhouse removed due to surface location proximity to the S-122. In addition there are several close tolerance wells in the surface interval. Follow the traveling cylinder / no-go plot per established procedures. A gyro should be run to at least 900'-1200'. - Faults: One fault is expected in the S-122 surface hole section at approximately 2,250 MD. The fault is predicted to have 80' of throw to the West. - Directional: Every effort should be made to ensure a `smooth' well profile that will benefit torque / drag in the later hole sections and allow for easier 9 5/a" casing running. A graduated build profile is planned. It is preferred that DLS are not pushed ahead of plan on the surface hole, so as to minimize the chance for hole irregularity or obstructions that could cause problems while running casing. - Hole Cleaning: Good hole cleaning practices will be critical to the success of the well. Surface rotary speeds should be maximized wherever possible. The BHA is limited to 40 to 60-rpm while drilling because of the 1.83° motor bend. Vary flowrates 450-550 GPM to achieve the required directional S-122 Permit to Drill Page 8 • ~ response. The motor will be changed to a 1.5° when the bit is changed prior to exiting the permafrost making it possible to raise the rotary speed to +100-rpm prior to POOH to run casing. The new motor will also allow flowrates to be increased to 650 - 700 GPM to increase hole cleaning. Before pulling out of the hole for the final time, make sure that the hole is clean, full returns are observed and that the pipe pulls without significant overpull. Lost circulation is possible while cementing if these conditions are not satisfied. - Tight spots: During short trips, work out any tight spots as they are seen while pulling out of the hole instead of waiting and reaming them out after running back in the hole as this could lead to accidental sidetracking. Consider back-reaming across initial tight spots only if washing does not alleviate the problem. If tight spot is thought to be cuttings, run back in the hole at least the length of the BHA and circulate and condition the hole for a minimum of 30 minutes at max RPM's and GPM's. - Critical LWD Tools: It is critical for the landing of this hole section to have the GR to pick the base of the SV3 sand. If this tool fails, it will require an immediate trip out of the hole to replace. It is imperative that the surface casing isolates all of the SV3 sands. Reference RPs: • "Prudhoe Bay Directional Guidelines" • "Well Control Operations Station Bill" • Follow Schlumberger logging practices and recommendations Job 3: Run 9-g/e" Surface Casing Critical Issues: - Casing to bottom: It is imperative the casing is set in the shale below the SV3 sands to ensure wellbore integrity for the intermediate interval. Hydrates have been encountered on S-pad all the way through the SV2 and slightly beyond. It may be desirable to stop and roll the mud over half way in the hole to break the gels and reduce surging intensity on the SV sands. This will also help to ensure circulation is attained at TD at the desired cementing rates without losses. Make sure that the hole is clean and obstructions are minimized before running casing as higher doglegs and aggressive directional work could make casing running more difficult. - Casing drift: 9 5/a", 40# special drift casing is being used (8.835" ID, 8.75" drift). Ensure that casing equipment is properly drifted to ensure adequate ID for the 8-3/a" bit (float equipment, casing hanger, etc). - Cement to surface: A single-stage job will be done on this well using 250% excess in the permafrost and 30% excess below the permafrost. A TAM Port collar should be placed at 1,000-ft MD as a contingency, if hole conditions warrant. If displacement goes according to plan, bump plug and walk pressure to 3,500 psi and hold for 30 minutes for casing pressure test. - Losses during cement job: Lost circulation has been experienced on offset wells while running and cementing surface casing. The expected frac gradient for the shale below the SV3 sand is at least 12.5-ppg EMW. Follow the Schlumberger recommended pumping rates as they have modeled the expected ECD's during the entire cement job to help mitigate the potential for breaking down the formations. Reference RPs: • "Casing and Liner Running Procedure" • "Surface Casing and Cementing Guidelines" • "Surface Casing Port Collar Procedure" Job 4: Drill 8-3/a" Intermediate Hole Critical Issues: - Differential Sticking could be a problem if lost circulation is occurring or if the drill string is left stationary for an extended period of time across the permeable Schrader Sands. S-122 Permit to Drill Page 9 • • - LOT: Perform a LOT (minimum 11.2 ppg EMW to satisfy kick tolerance). KICK TOLERANCE: Based upon the max expected Kuparuk reservoir pressure of 9.4 ppg and 10.5 ppg mud, a 11.2 ppg leak-off will provide 55.3 bbls of kick tolerance. Contact Anchorage personnel if LOT is less than 11.2 ppg. Based upon off-set drilling data, a minimum leak-off of 13 ppg is expected at the 9 5/a" shoe. - Penetration Rate: Penetration rates should not exceed 600 fph instantaneous. This should allow for ECDs not to exceed 0.6ppg above calculated. If ECDs are sustained above this threshold, it is advised that drilling should be stopped and the hole circulated before continuing. - Torque: Use lubricants as per the MI program as necessary. If weight transfer problems are encountered during sliding, attempt to circulate and rotate for a minimum of 2 bottoms up to test if lubricants are truly needed or if the hole is loading up with cuttings. - Faults: Two faults are expected in the S-122 8-3/a" hole section. Losses are not expected to be associated with this fault. Details are listed below for reference: Fault #2: 8,349' MD 5,734' TVD 5,670' TVDss Throw: 60' SE Fault #3: 9,610' MD 6,424' TVD 6,360' TVDss Throw: 40' W - Screen Blinding: Add EMI 697 as per MI mud program while drilling the Ugnu/heavy oil sands. - Critical LWD Tools: It is critical to have the GR tool in order to pick the landing points for the production hole section. As mentioned above in the landing point discussion, the landing of this well depends on picking the base of the KUP B sand using the Gamma Ray. Therefore if the GR tool is lost, a trip will have to be made to change it out. - 7" casing landing point: The 7" casing setting point will be determined by depth based on changes in GR/Res curves associated with the Kup B sand. After seeing the top Kup B, TD will be picked based on drilling 100' MD past the top of the Kuparuk B sand to allow MW D logs over the entire Kuparuk C formation. This footage is critical for future well work. If tops are coming in 100' or more out from proposed, then conduct a short trip and notify town. A Rigsite Geologist will be required on site to pick casing point. Reference RPs: • Standard Operating Procedure for Leak-off and Formation Integrity Tests • Prudhoe Bay Directional Guidelines • Lubricants for Torque and Drag Management. • "ERD Operating Practices" Job 6: Run and Cement 7" Intermediate Casing Critical Issues: - Tight hole, packing off and lost circulation have been experienced while drilling though this interval. Good hole cleaning, mud conditioning, and drilling practices are required for trouble free drilling. In numerous cases tight hole has made backreaming necessary with stuck pipe and lost returns on only two wells. - Cement Job: The interval is planned to be cemented with a lead and tail slurry. The lead slurry will cover from 1000' above the shoe to 500' above the top of the UG4A and the tail will cover from the shoe up 1000'. Ensure a minimum hydrostatic equivalent of 10.5 ppg across the HRZ during pumping of cement pre-flushes. Reciprocate pipe as long as possible while cementing. Keep cementing ECD's below 13.0 ppg EMW during the displacement. - Freeze Protection: Ensure the lower production cement has reached at least a 500 psi compressive strength prior to freeze protecting. After freeze protecting the 7" x 9 5/8" casing outer annulus with 65 bbls of diesel (2,300' MD, 2,240'TVD), the hydrostatic pressure will be 7.7 ppg vs. 8.4 ppg EMW of the formation pressure immediately below the shoe. Ensure adouble-barrier at the surface on the annulus exists until the cement has set up for at least 12 hours. Trapped annulus pressure may be present after pumping the freeze protection as the hydrostatic pressure of the mud and diesel could be over 100 psi underbalance to the open hole. - Centralization/Differential Sticking: See centralizer strategy in the Well Plan Summary. Differential Sticking could be a problem if lost circulation is occurring or if the casing is left stationary for an S-122 Permit to Drill Page 10 extended period or time across the permeable sands. Ensure the casing is centralized across any permeable zones if the casing is left stationary while running in the hole. - Mud Requirements: Thin the mud as per MI's Mud Program. Thinner mud will aid in achieving good displacement and a better cement job will result from thinner mud at TD. Extra time spent circulating is warranted to ensure optimum mud properties and hole cleaning prior to the cement job. - Franks Casing Fill-up tool: Make sure that a casing fill up tool is on location prior to PU 7" casing. - TIW Valve: Ensure that a TIW valve with a cross over to 7" BTC-M casing is on the rig floor before running casing. Reference RPs: • "Intermediate Casing and Cementing Guidelines" • "Freeze Protecting an Outer Annulus" Job 7: Set Whipstock and Drill 6'/e" Horizontal Production Hole Critical Issues: - A Whipstock will be set in the 7" intermediate casing to facilitate kicking off the horizontal production hole. Once Milling is complete, make sure that all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings which have accumulated. - There are no "close approach" issues with the production hole interval of S-122. - Mud losses of 10-80 bph have been encountered in offset horizontal sections. Significant losses occurred in S-114A 07163 TVD following a 5' drilling break. Contingency LCM material and mud product should be available at the rigsite/mud plant. - Under no circumstances add any LCM (including Walnut sweeps, cellulose material) other than calcium carbonate for losses < 50 BPH without prior discussions with the Drilling Engineer/Asset Production Engineer. Significant mud losses > 50 BPH may include the use of cellulose material to arrest losses. See LCM discussion in MI Mud Program. - Lubricant concentrations should not exceed 4% total. Lubetex and/or EMI 776 concenetrations of 2% may be needed to improve weight transfer in critical kick-off section. - Fault # 4 will be cut in the 6-'/8" horizontal section C~3 approximately 11,600' MD / 6,774' TVD with 50' of throw to the West. - MWD, gamma ray, resistivity, neutron and density will be run real time in this section of the hole. - FIT: Perform a FIT (minimum 11.0 ppg EMW). Contact Anchorage personnel if FIT is less than 11.0 ppg. Reference RPs • "Standard Operating Procedure for Leak-off and Formation Integrity Tests" • "Prudhoe Bay Directional Guidelines" • "Lubricants for Torque and Drag Management" • ERD Recommended Practice Section 5.2 Operating Practices • Whipstock Sidetracks- RP Job 9: Install 4'/i" Production Liner Hazards and Contingencies - Differential sticking could be a problem. The mud system will be approximately 70 psi over balance to the Kuparuk formation. Minimize the time the pipe is left stationary while running the liner. S-122 Permit to Drill Page 11 • - Modeling shows that there should be no issues setting the ZXP packer. In the event additional weight is required to get the liner to TD, have 6 stands of weight pipe in the derrick. Reference RPs • "Running and Cementing a Liner Conventionally" Job 10: DPC Perforate Well Critical Issues: - The Kuparuk interval of the well will be TCP perforated prior to running the completion. After placing a KCL brine perf pill weighted to 9.4 ppg the well will be perforated across a 9.2 ppg EMW reservoir for an overbalance of X100 psi. Be prepared for losses upon firing guns. Ensure all responsibilities are clearly communicated with respect to perforating guns safety. Watch hole fill closely while POH with pert guns. - The Asset will provide a minimum clean out depth. This will define how far off depth the guns can be and still be fired without coming out of the hole to perform a clean out trip in the event the guns cannot reach depth due to cement/fill. - It should be stressed that while picking up and running the perforating string, only essential personnel should be on the rig floor. Normally "essential personnel" will consist of the driller, floorhands, Schlumberger perforating crew. All other personnel will stay off the rig floor and out of the cellar until the perforating string is at least 100-ft below the rotary table. - Contact Schlumberger to prepare for approximately 1000' of 2-'/z" Power Jet Omega guns at 6 spf and 60° phasing to be run on DP. Exact perforation depths will be provided after reviewing the LWD logs. Reference RPs: • "Wireline Pressure Control SOP" • "Alaska Wells Group Standard Operating Procedure: Perforating" • Follow Schlumberger perforating practices and recommendations Job 12: Run 4-~/2" Completion Critical Issues: - Keep in mind that the Kuparuk interval will be open during the running of the completion. Watch hole fill closely, verify no light fluids are introduced down hole and verify proper safety valves are on the rig floor while running this completion. - Shear valves have been failing at lower than the 2500 psi differential pressure. When testing annulus maintain no more than a 1500 psi differential. Avoid cycling pressure (pumping up and bleeding off) prior to activating shear valve as this is thought to cause shearing at lower pressures. - Extreme care should be taken when running the completion to avoid damaging the I-wire associated with the down hole pressure gauge. Ensure that the I-wire ports in the tubing hanger and adapter flange are aligned after the packer is set. Reference RPs: • "Completion Design and Running" RP • "Tubing Connections" RP Job 13: ND/NU/Release Rig S-122 Permit to Drill Page 12 • • Critical Issues: - See Job 1 for adjacent well spacing. Identify hazards in a pre-move meeting, and take every precaution to ensure good communication prior to beginning the rig move. Use spotters when moving the rig. - Diesel: Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is - 0.1 psia at 100° F. Reference RPs: • "Freeze Protecting an Inner Annulus" RP S-122 Permit to Drill Page 13 5-122 Propd~ed Completior~i 9 5/8", 40.0#, L-80, BTC, btm 4 jts 40# 3,100 K-55 BTC 2,200 HES 4 1/2"'X' nipple; I.D. = 3.813" Minimum ID = 3.813" @ 2,200' MD TREE= 4 1/16" CNV WELLHEAD = FMC ACTUATOR = LEO KB. ELEV = 64.20' AMSL CB. ELEV = 35.70' AMSL KOP = 300' Max Angle = 99° @ 11,200' Datum MD = 12,257 DatumTVD= 6,814' GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 9877 6562 65° MMG Dum BK-5 2 8106 5600 64° MMG Dum BK-5 3 7021 5000 59° MMG Dum BK-5 4 4851 3800 59° MMG DCK BK-5 PERFORATION SUMMARY REF LOG: A NGLE AT TOP PERF: Note: Refer to Production DB for historical perf data Baker 7" X 4 1/2" S-3 Packer 10,003 4 1/2", 12.6#, L-80, IBT-M tubing 10,060 Baker HMC liner hngr, ZXPpkr, w/ 10,060 TBS Baker Whip stock, 10,210 (Top of w indow ) 9,945 Baker CMD Sliding Sleeve; I.D. = 3.813" 9,970 HES 4 1/2" 'X' nipple; I.D. = 3.813" 9,981 HES 4 1/2" BHG w / 1 W ire to Surface 10,028 HES 4 1/2" 'X' nipple; I.D. = 3.813" 10,049 HES 4 1/2" 'X' nipple; I.D. = 3.813" 10,426 Pup W/'RA' Tag 11,590 Pup W/'RA' Tag HES 7" Ezsv 10,223 I r~• I ~ 0 0 7", 26.0#, L-80, 10,835 BTG M r° -~ PBTD 11,711 4 1l2", 11.6 #, L-80 LT&C liner 11,797 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNfT WELL: S-122 PERMIT No: API No: 50-029-X)CXXX BP 6cploration (Alaska] 27 26 ~ 25 S oPAD _N_ 34 135 36 ~o PROJECT _ 5~~ AREA s~ T.12N. 3 T.17N. 2 VICINITY MAP N.T.S. N 1100- -~ ------- -- --- - -- cV N ~ S-PAD i ~ ~ N 1010 i ^^~~~f~~~>•"~f~~~^ ~ ~~ ~ -~ ~ ~ ~ ~ M n M r-- W 01 !4 m N @ an r @ M cV ~O ~ d ~ d ~ @_ @ .- _@ @ @ @_ ~ ~_ @ ~_ ~ @_ @_ @_ @ ~ ~ N N ~ N N I I I I I I I I I I I I I I I I I 1 1 1 1 1 1 N ~ N N i N (n VI V1 (n N N U7 N N N N N N N N N (n N N N !n N f t f I ~ ,~~ ° 0 F ° A ~ ``-c0 ° ° =Q -~ N 840 ~ ,~P°°° ° S'r' 9 ~'° °` - ------ -- - - - --- -- ° --- * ~ °49~ ° ° LEGEND °°°°°°°°°°°°°°°°°°°°°°°°°°°°°°° AS-BUILT CONDUCTOR °°°°°°°°°°°°°°°°°°°°°°°°°°°°°°° ° ^ EXISTING CONDUCTOR c~~,~'°,°°Richard F. Allison o 106l~8 ° ° ~° NOTES: ,q°~°.°,,~°_°° - 1. DATE OF SURVEYS: MAY 20, 2005. ""~'t SSIONW- 2. REFERENCE FIELD BOOK: W005-01, PG'S 57-58. 3. COORDINATES ARE ALASKA STATE PLANE, ZONE-4 NAD 27. SURVEYOR'S CERTIFICATE 4. GEODETIC COORDINATES ARE NAD-27. I HEREBY CERTIFY THAT I AM 5. MPU S-PAD AVERAGE SCALE FACTOR IS: 0.9999165. PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN 6. HORIZONTAL CONTROL IS BASED ON S-PAD MONUMENTS S-1, THE STATE OF ALASKA AND THAT S-3 AND S-4. THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT 7. VERTICAL CONTROL IS BASED ON MON. S-4. SUPERVISION AND THAT ALL ELEVATIONS ARE BP EXPLORATION MEAN SEA LEVEL DATUM. DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF MAY 21, .2005. 8. UNITS ARE U.S. SURVEY FEET. LOCATED WITHIN PROTRACTED SEC. 35. T. 12 N.. R. 12 E.. UMIAT MERIDIAN. ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION N0. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) BOX ELE .OFFSETS Y=5,980,594.52 N 1009.97 70'21'20.288" 70.3556356° 35 72' 4,391' FSL S-122 X= 618,929.80 E 260.44 149'02'02.943" 149.0341508' . 4,500' FEL _ _ _ _ CHECKED: ~ u. ia~ ~~ CLARKE O DATE: ° 5/21/05 °° DRAWING: FR805 WOS 04-00 WOA S-PAD SHEET: ~~~~~~ 5 A~EO AS-BUILT CONDUCTOR 1 ~ 1 i°= iee~ WELL S-122 ~:~ ~ ' T y~1.'~~ i~.,~ S-122PB1 (P2b Client: BP Exploration Alaska Field: Prudhoe Bay Unit - WOA Structure I Slot: S-PAD I S-122 Well: ~~ i 1; Plan S-122 Borehole: ~ Plan 5-122PB1 e l1WUAPRC: 50029 Surrey Name 1 Date: 5.122P61 (P2b) /April 21, 2005 Tort! AHD / DDI 1 ERD ratio: 95.755° / 7354.37 ft 16.034 / 1.042 Grid Coordinate System: NAD27 Alaska State Planes, Zone D4, US Feet Location Laf/LOng: N 70.35563694, W 149.03414922 Location Grid NIE YIX: N 5980595.000 ftUS, E 618930.000 ftUS Grid Convergence Angle: +0.90964555° Sehlumperger Vertical Section Azimuth: 341.080° Vertical Section Origin: N 0.000 ft, E 0.000 ft l ND Reference Datum: Rotary Table y ND Reference Elevation: 64.20 ft relative to MSL Sea Bed 1 Ground Level Elevation: 35.70 ft relative t0 MSL Magnetic Declination: 24,566° Total Field Strength: 57630.229 nT Magnetic Dip: 80.849° Declination Date: June 25, 2005 Magnetic Declination Model: BGGM 2004 North Reference: True North Total Corr Mag North -> True North: +24.566° Comments Measured inclination Azimuth Subsea ND ND Vertical Along Hole NS EW OLS cool Face Buifd Rate Walk Rate Northing Easting Latitude Longitude Depth Section Departure ft d d ft h ft tt ft fl de 100ft de de HOOft de 11008 ftU3 ftUS Klt U.UU 0.VV 13V.UU -ti4.ZU U.UU U.VU U.UV V.UU U.UU V.UV 13U.UUM U.VV U.UU bySUSyb.UU U1S`J3U.UV N /U.Jbbli3tiy4 W 14y.U3414y21 Ndg 1.5/100 300.00 0.00 130.00 235.80 300.00 0.00 0.00 0.00 0.00 0.00 130.OOM 0.00 0.00 5980595.00 618930.00 N 70.35563694 W 149.03414922 400.00 1.50 130.00 335.79 399.99 -1.12 1.31 -0.84 1.00 1.50 130.OOM 1.50 0.00 5980594.17 618931.02 N 70.35563465 W 149.03414108 G1 404.21 1.58 130.00 340.00 404.20 -1.22 1.42 -0,91 1.09 1.50 130.OOM 1.50 0.00 5980594.10 618931.10 N 70.35563445 W 149.03414038 500.00 3.00 130.00 435.71 499.91 -4.48 5.23 -3.36 4,01 1.50 130.OOM 1.50 0.00 5980591.70 618934.06 N 70.35562775 W 149.03411666 600.00 4.50 130.00 535.49 599.69 -10.08 11.77 -7.57 9,02 1.50 130.OOM 1.50 0.00 5980587.58 618939.14 N 70.35561627 W 149.03407598 Drp 1.5/100 650.00 5.25 130.00 585.31 649,51 -13.72 16.02 -10.30 12,28 1.50 180.OOG 1.50 0.00 5980584.90 618942.44 N 70.35560881 W 149.03404955 700.00 4.50 130.00 635.13 699.33 -17.36 20.27 -13.03 15.53 1.50 130.OOM -1.50 0.00 5980582.22 618945.73 N 70.35560134 W 149.03402312 800.00 3.00 130.00 734.91 799.11 -22.96 26.81 -17.24 20.54 1.50 130.OOM -1.50 0.00 5980578.09 618950.81 N 70.35558986 W 149.03398244 900.00 1.50 130.00 834.83 899.03 -26.33 30.74 -19.76 23.55 1.50 130.OOM -1.50 0.00 5980575.62 618953.86 N 70.35558297 W 149.03395802 End Drp 1000.00 0.00 130.00 934.82 999.02 -27.45 32.05 -20.60 24.55 1.50 -70.OOM -1.50 0.00 5980574.79 618954.87 N 70.35558067 W 149.03394988 KOP Bld 3.5/100 1200.00 0.00 290.00 1134.82 1199.02 -27.45 32.05 -20.60 24.55 0.00 -70.OOM 0.00 0.00 5980574.79 618954.87 N 70.35558067 W 149.03394988 1300.00 3.50 290.00 1234.76 1298.96 -25.53 35.10 -19.56 21.68 3.50 -70.OOM 3.50 0.00 5980575.79 618951.99 N 70.35558352 W 149.03397317 1400.00 7.00 290.00 1334.32 1398.52 -19.78 44.25 -16.43 13.08 3.50 O.OOG 3.50 0.00 5980578.78 618943.34 N 70.35559207 W 149.03404298 1500.00 10.50 290.00 1433.14 1497.34 -10.23 59.46 -11.22 -1.21 3.50 O.OOG 3.50 0.00 5980583.76 618928.97 N 70.35560628 W 149.03415904 1600.00 14.00 290.00 1530.85 1595.05 3.10 80.67 -3.97 -21.14 3.50 O.OOG 3.50 0.00 5980590.70 618908.92 N 70.35562610 W 149.03432091 SV6 1604.28 14.15 290.00 1535.00 1599.20 3.75 81.71 -3.61 -22.12 3.50 O.OOG 3.50 0.00 5980591.04 618907.94 N 70.35562707 W 149.03432885 1700.00 17.50 290.00 1627.08 1691.28 20.15 107.81 5.31 -46.65 3.50 O.OOG 3.50 0.00 5980599.57 618883.28 N 70.35565146 W 149.03452800 Crv 3.5/100 1771.43 20.00 290.00 1694.72 1758.92 34.57 130.77 13.17 -68.22 3.50 76.25G 3.50 0.00 5980607.08 618861.58 N 70.35567291 W 149.03470318 1800.00 20.26 292.81 1721.54 1785.74 40.94 140.60 16.75 -77.37 3.50 73.61G 0.91 9.82 5980610.52 618852.38 N 70.35568271 W 149.03477749 1900.00 21.50 302.00 1815.00 1879.20 66.69 176.18 33.18 -108.88 3.50 65.02G 1.24 9.20 5980626.45 618820.61 N 70.35572759 W 149.03503336 Base Perm 1948.49 22.27 306.06 1860.00 1924.20 81.12 194.25 43.30 -123.85 3.50 61.25G 1.58 8.38 5980636.33 618805.49 N 70.35575524 W 149.03515488 2000.00 23.19 310.08 1907.51 1971.71 97.80 214.14 55.58 -139.50 3.50 57.54G 1.78 7.80 5980648.35 618789.65 N 70.35578877 W 149.03528194 2100.00 25.23 317.02 1998.73 2062.93 134.15 255.10 83.85 -169.10 3.50 51.21G 2.04 6.84 5980676.15 618759.61 N 70.35586601 W 149.03552230 2200.00 27.55 322.93 2088.32 2152.52 175.60 299.51 117.90 -197.57 3.50 45.92G 2.32 5.91 5980709.74 618730.60 N 70.35595904 W 149.03575355 Fault 1 Crossing 2213.19 27.87 323.64 2100.00 2164.20 181.44 305.64 122.82 -201.24 3.50 45.29G 2.45 5.38 5980714.60 618726.85 N 70.35597247 W 149.03578333 SV5 2235.88 28.43 324.82 2120.00 2184.20 191.68 316.34 131.51 -107.50 3.50 44.24G 2.49 5.22 5980723.18 618720.46 N70.35599620 W149.03583412 2300.00 30.08 327.95 2175.95 2240.15 221.99 347.68 157.61 -224.82 3.50 41.52G 2.57 4.87 5980749.00 618702.73 N 70.35606750 W 149.03597482 2400.00 32.77 332.23 2261.28 2325.48 273.15 399.80 202.81 -250.74 3.50 37.86G 2.70 4.29 5980793.79 618676.10 N 70.35619099 W 149.03618528 WeIlDesign Ver Bld( doc40x_37) S-122\Plan S-122\Plan S-122PB1\5-122P81 (P2b) Generated 4/2112005 4:23 PM Page 1 of 2 Comments Measured Inclination Azimuth Sub•Sea ND ND Vertical Along Nole NS EW DLS Tool Face Build Rate Walk Rate Northing Easting Latitude longitude Depth Section Departure ft de de ft ft ft ft ft ft de 100k de 100ft de 10011 ftUS ftUS JV4 c4J4.JD 3J./J JJJ.W LLYV.VV LJ04.W LY1./e 410.OJ LIYAO -LJY.JI JAV JO./OU L./a J.O/ J`J6VOIV.41 01600/.[O IV /V.JDOLJO/e VV 74Y.VJ0004Y3 2500.00 35.60 335.92 2344.00 2408.20 328.90 455,96 253.35 -275.23 3.50 34.SOG 2.84 3.60 5980843.93 618650.81 N 70.35632905 W 149.03638416 2600.00 38.51 339.13 2423.81 2488.01 389.02 516.21 309.03 -298.20 3.50 32.24G 2.92 3.21. 5980899.23 618626.96 N 70.35648117 W 149.03657070 2700.00 41.51 341.95 2500.39 2564.59 453.30 580.49 369.65 -319.56 3.50 30.08G 3.00 2.82 5980959.50 618604.64 N 70.35664677 W 149.03674423 2800.00 44.57 344.45 2573.48 2637.68 521.48 648.72 434.98 -339.25 3.50 28.26G 3.06 2.50 5981024.50 618583.92 N 70.35682524 W 149.03690408 2900.00 47.67 346.69 2642.79 2706.99 593.31 720.79 504.77 -357.17 3.50 26.70G 3.11 2.24 5981094.00 618564.89 N 70.35701592 W 149.03704966 SV3 2910.74 48.01 346.92 2650.00 2714.20 601.24 728.75 512.53 -358.99 3.50 26.55G 3.13 2.12 5981101.72 618562.95 N 70.35703709 W 149.03706442 3000.00 50.82 348.72 2708.07 2772.27 668.54 796.53 578.78 -373.27 3.50 25.38G 3.15 2.02 5981167.73 618547,62 N 70.35721809 W 149.03718043 9-5/8" Csg Pt 3067.95 52.97 349.99 2750.00 2814.20 721.45 849.99 631.32 -383.14 3.50 24.59G 3.17 1.88 5981220.11 618536.92 N 70.35736164 W 149.03726058 3100.00 54.00 350.57 2769.07 2833.27 746.87 875.75 656.71 -387.49 3.50 24.25G 3.19 1.80 5981245.42 618532,17 N 70.35743099 W 149.03729589 3200.00 57.20 352.28 2825.57 2889.77 828.02 958.24 738,29 -399.76 3.50 23.28G 3.20 1.71 5981326.78 618518,60 N 70.35765384 W 149.03739563 End Crv 3207.61 57.44 352.40 2829.68 2893.88 834.31 964.65 744.64 -400.62 3.50 O.OOG 3.22 1.64 5981333.12 618517.65 N 70.35767120 W 149.03740257 SV2 3226.79 57.44 352.40 2840.00 2904.20 850.16 980.82 760.66 -402.75 0.00 O.OOG 0.00 0.00 5981349.11 618515.26 N70.35771497 W149.03741993 Crv 3/100 3291.83 57.44 352.40 2875.00 2939.20 903.91 1035.64 815.00 -4f0.00 0,00 -100.34G 0.00 0.00 5981403.32 618507.15 N 70.35786342 W 149.03747880 3300.00 57.40 352.12 2879.40 2943.60 910.66 1042.52 821.82 -410.93 3.00 -100.19G -0.53 -3.50 5981410.12 618506.11 N 70.35788204 W 149.03748633 3400.00 56.92 348.59 2933.64 2997.84 993.56 1126.53 904.63 -424.99 3.00 -98.28G -0.48 -3.52 5981492.69 618490.74 N 70.35810827 W 149.03760059 3500.00 56.54 345.03 2988.51 3052.71 1076.72 1210.13 986.01 -444.05 3.00 -96.32G -0,38 -3.56 5981573.75 618470.39 N 70.35833060 W 149.03775543 End Crv 3536.74 56.42 343.72 3008.80 3073.00 1107.30 1240.76 1015.51 -452.30 3.00 O.OOG -0.31 -3.58 5981603.11 618461.67 N 70.35841118 W 149.03782243 SV1 3792.04 56.42 343.72 3150.00 3214.20 1319.78 1453.46 1219.68 -511.93 0.00 O.OOG 0.00 0.00 5981806.30 618398.81 N 70.35896895 W 149.03830681 UG4 4452.00 56.42 343.72 3515.00 3579.20 1869.04 2003.30 1747.47 -666.08 0.00 O.OOG 0.00 0.00 5982331.53 618236.32 N 70.36041080 W 149.03955906 UG4A 4497.21 56.42 343.72 3540.00 3604.20 1906.66 2040.96 1783.62 -676.64 0.00 O.OOG 0.00 0.00 5982367.50 618225.19 N 70.36050955 W 149.03964484 UG3 5084.84 56.42 343.72 3865.00 3929.20 2395.72 2530.55 2253.58 -813.89 0.00 O.OOG 0.00 0.00 5982835.18 618080.51 N 70.36179338 W 149.04076002 UG1 6079.31 56.42 343.72 4415.00 4479.20 3223.37 3359.07 3048.88 -1046.16 0.00 O.OOG 0.00 0.00 5983626.63 617835.66 N70.36396599 W149.04264757 Ma 6630.78 56.42 343.72 4720.00 4784.20 3682.34 3818.53 3489.91 -1174.97 0.00 O.OOG 0.00 0.00 5984065.52 617699.88 N 70.36517080 W 149.04369447 Na 7082.81 56.42 343.72 4970.00 5034.20 4058.54 4195.13 3851.41 -1280.55 0.00 O.OOG 0.00 0.00 5984425.27 617588.58 N 70.36615834 W 149.04455268 OA 7260.01 56.42 343.72 5068.00 5132.20 4206.02 4342.76 3993,12 -1321.94 0.00 O.OOG 0.00 0.00 5984566.29 617544.96 N 70.36654545 W 149.04488912 OBf Base 7806.06 56.42 343.72 5370.00 5434.20 4660.47 4797.70 4429.81 -1449.48 0.00 O.OOG 0.00 0.00 5985000.87 617410.51 N 70.36773840 W 149.04592598 Fault 2 Crossing 8348.49 56.42 343.72 5670.00 5734.20 5111.92 5249.62 4863.62 -1576.17 0.00 O.OOG 0.00 0.00 5985432.57 617276.96 N 70.36892343 W 149.04695610 Crv 41100 9306.80 56.42 343.72 6200.00 6264.20 5909.47 6048.03 5630.00 -1800.00 0.00 -73.13G 0.00 0.00 5986195.23 617041.01 N 70.37101698 W 149.04877626 9400.00 57.58 339.49 6250.78 6314.98 5987.60 6126.18 5704.14 -1824.67 4.00 -70.82G 1.24 -4.54 5986268.96 617015.16 N 70.37121950 W 149.04897692 End Crv 9497.82 58.94 335.18 6302.26 6366.46 6070.58 6209.35 5780.86 -1856.74 4.00 O.OOG 1.39 -4.41 5986345.16 616981.89 N 70.37142908 W 149.04923764 CM1 9561.27 58.94 335.18 6335.00 6399.20 6124.64 6263.71 5830.19 -1879.56 0.00 O.OOG 0.00 0.00 5986394.12 616958.29 N 70.37156383 W 149.04942317 Fault 3 Crossing 9609.72 58.94 335.18 6360.00 6424.20 6165.92 6305.21 5867.86 -1896.98 0.00 O.OOG 0.00 0.00 5986431.50 616940.27 N 70.37166672 W 149.04956484 Top HRZ 10036.08 58.94 335.18 6580.00 6644.20 6529.20 6670.42 6199.33 -2050.31 0.00 O.OOG 0.00 0.00 5986760.47 616781.72 N 70.37257216 W 149.05081155 Kalubik 10152.36 58.94 335.18 6640.00 6704.20 6628.28 6770.03 6289.73 -2092.12 0.00 O.OOG 0.00 0.00 5986850.19 616738.48 N 70.37281910 W 149.05115159 Top Kuparuk/C 10171.74 58.94 335.18 6650.00 6714.20 6644.79 6786.63 6304.80 -2099.09 0.00 O.ODG 0,00 0.00 5986865.14 616731.27 N 70.37286025 W 149.05120826 S-122PB1 Tgt 10229.88 58.94 335.18 6680.00 6744.20 6694.33 6836.43 6350.00 -2120.00 0.00 O.OOG 0.00 0.00 5986910.00 616709.65 N 70.37298372 W 149,05137828 LCU/Kup 8 10569.03 58.94 335.18 6855.00 6919.20 6983.30 7126.94 6613.67 -2241.96 0.00 O.OOG 0.00 0.00 5987171.68 616583.52 N 70.37370395 W 149.05237011 KupA 10733.76 '58.94 335.18 6940.00 7004.20 7123.66 7268.05 6741.74 -2301.20 0.00 O.OOG 0.00 0.00 5987298.78 616522.27 N 70.37405377 W 149.05285188 TD 10834.53 58.94 335.18 6992,00 7056.20 7209.52 7354.37 6820.09 -2337.44 0.00 O.OOG 0.00 0.00 5987376.54 616484.79 N 70.37426778 W 149.05314661 Leaal Description: Northina (Yl fftUSl Eastina 1X1 iftUSl Surface : 4391 FSL 4499 FEL S35 T12N R12E UM 5980595.00 618930.00 BHL : 3482 FSL 1590 FEL 827 T12N R12E UM 5987376.54 616484.79 WeIlDesign Ver Bld( doc40x_37) 5-122\Plan S-122\Plan 5-122P81\S-122P61 (P2b) Generated 4/21!2005 4:23 PM Page 2 of 2 ~,, ~~. ~, .~ Schlumberger WE" S-122PB1 (P2b) FIELD Prudhoe Bay Unit - WOA BTRDDTURE S-PAD Magnate Pa2nblera Sudaoe 4acation NN)2] Naha Stab Pbnea, tore 04, US Feel Mbcelareous Model: BGGM 2W0 Dip: BO Bd9° Dah: June 25, 2(105 LaL N]02120293 Nodbbg: 598059500 flU5 Gdd DOnV: M.909fi4555° Sld: 5-122 TW ReI: ftobry Tabb (fi420flabove MSl) Mag Dec: ~24.Sfi6° FS: 5]fi30.2 nT Lm: W14922.g3] Eaa9ng: fi18930.00 PUS Scale Faq: 0.99991808]8 Pbn: 5-122PB1 (P2b) Srvy Date: Rpd121. 2005 1500 ~ 3000 0 0 u~ C _~ 0 4500 6000 7500 1500 3000 4500 6000 7500 9000 10500 Ndg 1.SH 00 Drp i.5N 00 End Drp KOP Bld 3.SN 00 ................ .............Crv.$~'I~.,...,....~...,,.........,,.......,.,,,........,«.........,..,............,..... .,........,,... ...........,,.,.......,.,,..... ,..........,......,,...,......., ......,.,,........., Fault t Crossing ... _....._.._j. .. _.._.. .._.._.._.._..;_.._.._.._.._.._.._.._.._..y.._..-.....w.._.._.._.._..wi._.._.._.._.._...-..~.._.._..f.._.._.._.._.._.._.. _.._.. ~._......_.._.._.._.._.._..-.~_,.r.._.._.._.._..w.. _.. _..i...... _.. _.. _.. _... aye P ... _.._.._. _ _ VS ._......_.. _.. _.._ ._.._.._..~..-.._.._.._ .._.. _..-.._........._.. -..w.. _.._.._..-........_ - _.. ~..w..~.._..-.._..... _.. _.._.._..-.._.. _.. _.._ ....._.._.._..-......_.._ w..~.._.._..w... 9-5/8" Cag Pt _ Ertd Crv Crv 3/100 ...~.._.._. - _.._.._. ~~ _ - .._.._.. _.._.._ _.._.. _.._.. _.._.,_.._., _.._.. _.._.._......_.. _.._ - _......~.. _.._.._.._.._. _.. _.._.._.._.._.._.. _.._ ,_.._.._...... w..,..._.._ _.._.._.._.._... ° .................................... ,,,°.... acr~.....°°,.........,.,........,,..........,,.,......,,,.........,:........,,,.,.........,°.............,......,.,,.......,,.,........,,.,.......,........,..,°°,....,..............,°°..........,.........,,,,.....,...,.........,,.,........., eats t.s11s1 aj1s1.:slases11 s1tsets lxsxt is ~~p~~ ~I rt~la tlertq:: gee lrtrt-tes:lst~s vrsltsp sees ts~lxaets lsartsv~ar~allfetarxslt>elaarralrart sr.av 1,are rtrs vsa v~atlrlxasealjs tme~ttlattesxa.. at~a 11::1~t1 s1ts~tatts rtsssa e.re.vtiTSSer..:rlxnl4Ct.•.r.ssT.atrrt.n•.~%SaTn•.+t..{vv.+.~,~.4s~.avf •nrx1R'.•.wr.vv.~afn•.•<r. ;w.~.~,.tT~~~<,.~.ttgl ..atvv.tmv~T.SVT°'..+t»t.'..rt. ht~Rt¢~:..nsaT.Y.~i.tw~bR•nr..nytP.•.~.sn•.sbay..:w.vtT.vSV....+.v~.T.lSr.:.x..avl5'r::.~.~.snvrt.•,r.~lPn F::.n»aanv!.t~.tsKt•. Fault 2 Crossing ~ ~; ° ° Base Crv 4A 00 End Crv ,. Fault 3 Crossing 5-122PB1 TgI wh ..~ ..~ .. .. .. ,. :TD .... ... . ...-e.-,.-..-..-..-.~-ee-.....®..-..-~.-..-..-..-e.-..-,.-.....-..-„~.....-.....-.ee......-..-..7`9rNCS ...... .-~.... ..-.,e.,....-..-..-..-.. .-..-..-..-e..e.-..-e,.. .......,....-... nmsrr..-..-..,...-..-e.- .-. ... ,.- ..... ...,. Top Kuparuk I E :,:_:: _::m: ~~: ~.:_:: _::~::~:.®.._::_:: ._..::_::_.._,.,. .....:y::_..~.._.:_:: _. .:. r. _::_ _..~::_::_::_::_:.:: j,CL1.IjKupBK~P A_::_.._ _:.'_.._...:..~.. _::~:... .:j. .....::_::_::~. ~:: _::_.:~'.:... _: .:._...::: $-122P81 (P2b) 1500 3000 4500 6000 7500 9000 10500 Vertical Section (ft) Azim = 341.08°, Scale = 1(in):1500(ft) Origin = 0 N/-S, 0 E/-W 1500 3000 4500 6000 7500 ~~~~° Schlumherger -_ ,~~ _ ~ ~" S-122P61 (P2b) "E`D Prudhoe Bay Unit - WOA STRUCTURE S-PAD Magnetic Paramdera SuRara LCfAldl klAD2] Alaska Slate Planes. Zorre O6, US Feet Meceaeneous NbEN: BGGM 2004 Op: 80.849' Date: June 25,2005 Cal MO 21 20.293 Narb~in9: 596059500 M1S Grifi Cam: a0.90961555° Sbl: 8-122 1VD Rat: Rolary Tads (64.20fl above MSC) Me0 pec'. X24566° FS: 516]0.2 nT Lan: W14922.93] Easen9: 61890000flUS Scale Fact 0.9999160fi]6 Plan: S122P811PID) Srvy Date: Agi121, 2005 n n n Z iG 0 0 0 c n m U v v v -4000 -3000 -2000 -1000 0 1000 7000 6000 5000 4000 3000 2000 1000 0 7000 6000 5000 4000 ..........€ ................ 3000 .......................... 2000 .........L ............... 1000 g 1.SN00 m t.~1Aa...,...... :nd Drp Bld 3.51100 -4000 -3000 -2000 -1000 0 1000 «< W Scale = 1(in):1000(ft) E »> 0 r i Schlumberger Anticollision Report Company: BP Amoco Date: 4/21/2005 Time: 16:30:47 Page: 1 Field: Prudhoe Bay Reference Site: PB S Pad Co-ordina te(NE) Reference: Well: Plan S-122, Tru e North Reference VVeII: Plan S-122 Vertical (TVD) Reference: S-122 Plan 64.2 Reference WellpattF?lan 5-122PB1 llb: Sybase NO GLOBAL SCAN: Using user defined selection & scan criteria Reference: Principal Plan & PLANNED PROGRAM Interpolation Meth otlMD Interval: 50.00 ft Error Model: ISCWSA Ellipse Depth Range: 28.50 to 10834.53 ft Scan Method: Trav Cylinder No rth Maximum Radiu90000.00 ft Error Surface : Ellipse + Casing Survey Program for Definitive Wellpath Date: 2/18/2005 Validated: NO Version: 2 Planned From To Survey Toolcode Tool N ame ft ft 28.50 1800.00 Planned: Plan #2 V2 GYD-GC-SS Gyrodata gyro single shots 1800.00 3200.00 Planned: Plan #2 V2 MWD MWD - Standard 1800.00 10834.53 Planned: Plan #2 V2 MWD+IFR+MS MWD +IFR + Multi Station Casing Points MD TVD Diameter Hole Size Narne ft ft in in 3067.95 2814.20 9.625 12,250 9 5/8" 11085.75 0.00 7.000 8.750 7" Summary <---------------------- Offset Wellpath ----------------------> Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warn ft ft ft ft ft PB S Pad Plan S-111 Plan S-111 V8 Plan: PI 397.90 400.00 136.16 7.56 128.60 Pass: Major Risk PB S Pad Plan S-111 Plan S-111 P61 V3 Plan: 397.90 400.00 136.16 7.68 128.49 Pass: Major Risk PB S Pad Plan S-203 Plan S-203 (East) V3 P 1231.79 1250.00 1198.59 21.22 1177.37 Pass: Major Risk PB S Pad Plan S-203 Plan S-203 (West) V5 P 1386.17 1450.00 1175.98 20.83 1155.15 Pass: Major Risk PB S Pad Plan S-208 Plan S-208 VO Plan: S- 1224.66 1250.00 1505.97 19.64 1486.33 Pass: Major Risk PB S Pad Plan S-214 Plan S-214 V1 Plan: S- 650.26 650.00 58.79 10.80 47.99 Pass; Major Risk PB S Pad Plan S-400 S-400 VO Plan: S-400 w 657.86 650.00 268,38 10.61 257.77 Pass: Major Risk PB S Pad Plan S-401 S-401 VO Plan: S-401 w 1177.22 1200.00 198.43 21.86 176.57 Pass: Major Risk PB S Pad S-01A S-01A V1 1198.68 1200.00 734.55 20.44 714.12 Pass: Major Risk PB S Pad S-01 B S-01 B V 1 1194.80 1200.00 734.52 20.42 714.11 Pass:. Major Risk PB S Pad S-01 S-01 V1 1243.51 1250.00 724.75 26.71 698.04 Pass: Major Risk PB S Pad S-02AP61 S-02AP61 V1 1198.55 1200.00 729,36 19.14 710.22 Pass: Major Risk PB S Pad S-02A S-02A V1 1198.55 1200.00 729.36 19.14 710.22 Pass: Major Risk PB S Pad S-02 5-02 V1 1197.30 1200.00 729,36 19.13 710.22 Pass: Major Risk PB S Pad S-03 S-03 V1 1238.34 1250.00 748.45 18.68 729.76 Pass: Major Risk PB S Pad S-04 S-04 V 1 1231.37 1250.00 766.88 20.03 746.85 Pass: Major Risk PB S Pad S-05AP61 S-05AP61 V1 1197.02 1200.00 830.69 18.78 811.92 Pass: Major Risk PB S Pad S-05A S-05A V1 1197.02 1200.00 830.69 18.78 811.92 Pass: Major Risk PB S Pad S-05 S-05 V1 1190.66 1200.00 830.69 18.71 811.98 Pass: Major Risk PB S Pad S-06 S-06 V1 1197.13 1200.00 890.84 19.06 871.78 Pass: Major Risk PB S Pad S-07A S-07A V1 1197.86 1200.00 945.18 18.59 926.59 Pass: Major Risk PB S Pad S-07 S-07 V1 1197.86 1200.00 945.18 18.59 926.59 Pass: Major Risk PB S Pad S-08 S-08 V1 1230.28 1250.00 1033.07 20.00 1013.07 Pass: Major Risk PB S Pad S-08 S-08A V2 1230.28 1250.00 1033.07 20.00 1013.07 Pass: Major Risk PB S Pad S-08 S-08B V3 1230.28 1250.00 1033.07 20.00 1013.07 Pass: Major Risk PB S Pad S-09 S-09 V 1 1198.12 1200.00 1118.90 20.28 1098.61 Pass: Major Risk PB S Pad S-100 S-100 V10 299.55 300.00 46.18 5.30 40.88 Pass: Major Risk PB S Pad S-101 S-101 V3 448.83 450.00 22.97 9.41 13.56 Pass: Major Risk PB S Pad S-101 S-101 P61 V9 448.83 450.00 22.97 9.45 13.52 Pass: Major Risk PB S Pad S-102 S-102 V11 249.99 250.00 61.91 4.82 57.09 Pass: Major Risk PB S Pad S-102 S-102L1 V5 249.99 250.00 61.91 4.82 57.09 Pass: Major Risk PB S Pad S-102 S-102L1 P61 V7 249.99 250.00 61.91 4.77 57.14 Pass: Major Risk PB S Pad S-102 S-102P61 V14 249.99 250.00 61.91 4.82 57.09 Pass: Major Risk PB S Pad S-103 S-103 V6 3587.86 3400.00 125.81 63.90 61.91 Pass: Major Risk PB S Pad S-104 S-104 V1 7818.89 7550.00 443.67 215.76 227.91 Pass: Major Risk PB S Pad S-105 S-105 V5 347.21 350.00 243.05 5.97 237.08 Pass: Major Risk PB S Pad S-106 S-106 V2 293.99 300.00 211.91 6.53 205.38 Pass: Major Risk PB S Pad S-106 S-106P61 V12 293.99 300.00 211.91 6.53 205.38 Pass: Major Risk PB S Pad S-107 S-107 V36 343.05 350.00 165.75 7.07 158.67 Pass: Major Risk PB S Pad S-108 S-108 V6 391.81 400.00 118.18 7.06 111.12 Pass: Major Risk PB S Pad S-109 S-109 V8 448.18 450.00 75.54 7.96 67.57 Pass: Major Risk PB S Pad S-109 S-109PB1 V2 448.18 450.00 75.54 7.96 67.57 Pass: Major Risk • ! Schlumberger Anticollision Report Company: BP Amoco llate: 4/21/2005 Timc: 1630:47 Page: 2 Field: Prudhoe Bay Reference Site: PB S Pad Co-ordin ate(NE) Keference: Well: Pla n 5-122, True North Reference WeII: Plan S-122 Vertical ( TVD) Reference: S-122 Plan 64.2 Reference Wellpa tlP.lan S-122P61 Db: Sybase Summary <-------------------- -- Offset Wellpath ----------------------> Reference Offset Ctr-Ctr No-Go Allowable Site Wcll Wellpath MD MD llistanc eArea Deviatio n W'arninp~' ft ft ft ft ft P PB S Pad S-10AP61 S-10AP61 V1 1197.57 1199.96 1193.66 19.27 1174.39 Pass: Major Risk PB S Pad S-10A S-10A V1 1197.61 1200.00 1193.66 19.35 1174.31 Pass: Major Risk PB S Pad S-10 S-10 V1 1197.57 1199.96 1193.66 19.27 1174.39 Pass: Major Risk PB S Pad S-110 S-110 V18 442.57 450.00 87.79 9.40 78.40 Pass: Major Risk PB S Pad S-112 S-112 V20 795.07 800.00 45.67 14.92 30.75 Pass: Major Risk PB S Pad S-113 S-113 V14 293.85 300.00 151.77 6.20 145.57 Pass: Major Risk PB S Pad S-113 S-113A V3 293.85 300.00 151.77 6.04 145.72 Pass: Major Risk PB S Pad S-113 S-1136 V6 293.85 300.00 151.77 6.04 145.72 Pass: Major Risk PB S Pad S-114 S-114 V13 342.37 350.00 227.08 7.18 219.90 Pass: Major Risk PB S Pad S-114 S-114A V6 342.37 350.00 227.08 7.02 220.05 Pass: Major Risk PB S Pad S-115 S-115 ST V1 Plan: Plan 549.67 550.00 12.22 9.76 2.46 Pass: Major Risk PB S Pad S-115 S-115 V7 549.67 550.00 12.22 9.67 2.56 Pass: Major Risk PB S Pad S-116 S-116 V6 850.99 850.00 114.70 14.06 100.63 Pass: Major Risk PB S Pad S-117 S-117 V4 599.91 600.00 14.00 10.81 3.19 Pass: Major Risk PB S Pad S-118 S-118 V5 754.46 750.00 95.77 12.73 83.03 Pass: Major Risk PB S Pad S-119 S-119 V7 351.29 350.00 106.85 6.66 100.19 Pass: Major Risk PB S Pad S-11 S-11 V4 1000.00 1000.00 1285.15 19.42 1265.73 Pass: Major Risk PB S Pad S-11 S-11A V1 1000.00 1000.00 1285.15 19.41 1265.74 Pass: Major Risk PB S Pad S-11 S-11 B V 1 1000.00 1000.00 1285.16 19.41 1265.75 Pass: Major Risk PB S Pad S-120 S-120 V4 500.19 500.00 31.64 9.42 22.22 Pass: Major Risk PB S Pad S-123 S-123 V10 963.18 950.00 922.34 16.45 905.89 Pass: Major Risk PB S Pad S-12A S-12A V1 1192.20 1200.00 1372.10 19.71 1352.39 Pass: Major Risk PB S Pad S-12 S-12 V1 1226.13 1250.00 1394.84 20.28 1374.56 Pass: Major Risk PB S Pad S-13 S-13 V1 1197.55 1200.00 1477.16 20.91 1456.25 Pass: Major Risk PB S Pad S-14 Drilling091604 S-14A V 1224.33 1250.00 1567.68 37.15 1530.54 Pass: Major Risk PB S Pad S-14 S-14 V5 1224.33 1250.00 1567.68 37.15 1530.54 Pass: Major Risk PB S Pad S-15 S-15 V2 1196.44 1200.04 1084.70 19.48 1065.22 Pass: Major Risk PB S Pad S-16 S-16 V1 1098.06 1100.02 1188.00 15.54 1172.46 Pass: Major Risk PB S Pad S-17 S-17 V1 1239.15 1250.00 1300.33 18.17 1282.16 Pass: Major Risk PB S Pad S-17 S-17A V1 1239.15 1250.00 1300.33 18.17 1282.16 Pass: Major Risk PB S Pad S-17 S-17AL1 V1 1239.15 1250.00 1300.33 18.17 1282.16 Pass: Major Risk PB S Pad S-17 S-17APB1 V1 1239.15 1250.00 1300.33 18.17 1282.16 Pass: Major Risk PB S Pad S-17 S-176 V1 1239.15 1250.00 1300.33 18.17 1282.16 Pass: Major Risk PB S Pad S-17 S-17C V1 1239.15 1250.00 1300.33 18.02 1282.32 Pass: Major Risk PB S Pad 5-17 S-17CP61 V2 1239.15 1250.00 1300.33 18.02 1282.32 Pass: Major Risk PB S Pad S-17 S-17CPB2 V1 1239.15 1250.00 1300.33 18.02 1282.32 Pass: Major Risk PB S Pad S-18 S-18 V1 745.82 700.00 1419.21 14.52 1404.69 Pass: Major Risk PB S Pad S-18 S-18A V16 748.27 700.00 1419.29 14.47 1404.82 Pass: Major Risk PB S Pad S-19 S-19 V1 1238.14 1250.00 717.52 19.45 698.08 Pass: Major Risk PB S Pad S-200 Plan S-200A East V2 PI 752.11 750.00 82.79 12.68 70.10 Pass: Major Risk PB S Pad S-200 Plan S-200A West V1 PI 1651.34 1650.00 49.84 20.51 29.33 Pass: Major Risk PB S Pad S-200 S-200 V1 1649.34 1650.00 49.78 20.37 29.41 Pass: Major Risk PB S Pad S-200 S-200P61 V10 1649.34 1650.00 49.78 20.37 29.41 Pass: Major Risk PB S Pad S-201 S-201 V2 3573.68 3400.00 165.42 54.28 111.15 Pass: Major Risk PB S Pad S-201 S-201PB1 V11 4928.79 4769.00 204.51 105.52 99.00 Pass: Major Risk PB S Pad S-20 S-20 V4 1094.47 1099.99 729.29 18.00 711.29 Pass: Major Risk PB S Pad S-20 S-20A V2 1094.47 1099.99 729.29 18.00 711.29 Pass: Major Risk PB S Pad S-213 S-213 V9 1399.23 1400.00 30.94 17.81 13.12 Pass: Major Risk PB S Pad S-213 S-213A V22 1403.26 1400.00 30.95 17.86 13.09 Pass: Major Risk PB S Pad S-213 S-213AL1 V9 1403.26 1400.00 30.95 17.86 13.09 Pass: Major Risk PB S Pad S-213 S-213AL1-01 V7 1403.26 1400.00 30.95 17.86 13.09 Pass: Major Risk PB S Pad 5-213 S-213AL2 V5 1403.26 1400.00 30.95 17.86 13.09 Pass: Major Risk PB S Pad S-213 S-213AL3 V7 1403.26 1400.00 30.95 17.86 13.09 Pass: Major Risk PB S Pad S-215 S-215 V9 992.57 1000.00 1096.76 16.06 1080.70 Pass: Major Risk PB S Pad S-216 S-216 V2 400.37 400.00 76.85 8.35 68.50 Pass: Major Risk PB S Pad S-21 S-21 V1 1239.74 1250.00 756.32 18.61 737.72 Pass: Major Risk PB S Pad S-22A S-22A V 1 1200.55 1200.00 720.54 16.87 703.67 Pass: Major Risk PB S Pad S-22B S-226 V2 1200.55 1200.00 720.54 17.03 703.51 Pass: Major Risk PB S Pad S-22 S-22 V1 1200.55 1200.00 720.53 16.87 703.66 Pass: Major Risk PB S Pad S-23 S-23 V1 1201.29 1200.00 737.50 16.66 720.83 Pass: Major Risk PB S Pad S-24 S-24 V5 1237.80 1250.00 766.01 17.49 748.52 Pass: Major Risk PB S Pad S-24 S-24A V 1 1239.72 1250.00 766.05 17.52 748.53 Pass: Major Risk PB S Pad S-24 S-24B V2 1239.72 1250.00 766.05 17.52 748.53 Pass: Major Risk Schlumberger Antieollision Report Company: BP Amoco Date: 4/21/2005 Time: 16:30:47 Page: 3 Field: Prudhoe Bay Reference Site: PB S Pad Co-ordinate(NE) Reference: Well; Pla n S-122, T rue North Reference Well: Plan S-122 Vertical (T VD) Reference: S-122 Pl an 64.2 Reference ~'f'ellpatlP.lan S-122P61 Db: Sybase Summary <-------------------- -- Offset Wellpath ----------------------> Reference Offset Ctr-Cfr No-Go Allowable Site Well Wellpath A1D MD Distanc eArea Deviation Warning ft ft ft ft ft PB S Pad S-25AP61 S-25AP61 V2 1347.82 1400.00 760.03 28.57 731.46 Pass: Major Risk PB S Pad S-25A S-25A V 1 1199.42 1200.00 792.36 17.55 774.81 Pass: Major Risk PB S Pad S-25 S-25 V 1 1199.42 1200.00 792.36 17.55 774.81 Pass: Major Risk PB S Pad S-26 S-26 V1 1150.08 1150.00 807.97 16.25 791.72 Pass: Major Risk PB S Pad S-27 S-27 V1 1236.27 1250.00 845.33 18.68 826.65 Pass: Major Risk PB S Pad S-27 S-27A V3 1236.27 1250.00 845.33 18.53 826.80 Pass: Major Risk PB S Pad S-27 S-276 V7 1235.68 1250.00 845.31 18.41 826.91 Pass: Major Risk PB S Pad S-28 S-28 V4 1200.00 1200.00 865.89 18.35 847.55 Pass: Major Risk PB S Pad S-28 S-28A V 1 1200.00 1200.00 865.89 18.35 847.55 Pass: Major Risk PB S Pad S-28 S-286 V2 1200.00 1200.00 865.90 18.35 847.55 Pass: Major Risk PB S Pad S-28 S-286PB1 V7 1200.00 1200.00 865.90 18.35 847.55 Pass: Major Risk PB S Pad S-29AL1 S-29AL1 V1 1197.00 1200.00 1053.41 16.91 1036.50 Pass: Major Risk PB S Pad S-29A Plan S-29AL2 VO Plan: 1200.00 1200.00 1053.40 16.77 1036.63 Pass: Major Risk PB S Pad S-29A S-29A V 1 1197.00 1200.00 1053.41 16.91 1036.50 Pass: Major Risk PB S Pad S-29 Plan S-296 Vi Plan: S- 1200.00 1200.00 1053.40 16.87 1036.53 Pass: Major Risk PB S Pad S-29 S-29 V1 1197.00 1200.00 1053.41 16.91 1036.50 Pass: Major Risk PB S Pad S-30 S-30 V1 1234.56 1250.00 931.89 20.09 911.80 Pass: Major Risk PB S Pad S-31A S-31A V3 1231.96 1250.00 975.31 17.81 957.50 Pass: Major Risk PB S Pad S-31 S-31 V1 1231.96 1250.00 975.31 17.81 957.50 Pass: Major Risk PB S Pad S-32 S-32 V1 1050.57 1050.00 1169.18 19.15 1150.04 Pass: Major Risk PB S Pad S-33 S-33 V1 996.94 1000.00 1006.04 15.93 990.11 Pass: Major Risk PB S Pad S-34 S-34 V1 920.34 900.00 1234.16 14.39 1219.77 Pass: Major Risk PB S Pad S-35 S-35 V 1 1197.43 1200.00 1254.76 15.08 1239.68 Pass: Major Risk PB S Pad S-36 S-36 V 1 1000.00 1000.00 1315.43 15.50 1299.94 Pass: Major Risk PB S Pad S-37 S-37 V1 958.72 950.00 1345.29 15.08 1330.21 Pass: Major Risk PB S Pad S-38 S-38 V1 1196.37 1200.00 1133.99 16.05 1117.95 Pass: Major Risk PB S Pad S-40A S-40A V1 1097.77 1100.00 1334.83 14.55 1320.28 Pass: Major Risk PB S Pad S-40 S-40 V1 1097.77 1100.00 1334.83 14.55 1320.28 Pass: Major Risk PB S Pad S-41 L1 S-41 L1 V1 1325.44 1350.00 175.82 21.28 154.54 Pass: Major Risk PB S Pad S-41PB1 S-41P61 V1 1325.44 1350.00 175.82 21.28 154.54 Pass: Major Risk PB S Pad S-41 S-41 V1 1325.44 1350.00 175.82 21.28 154.54 Pass: Major Risk PB S Pad S-42P61 S-42PB1 V1 1390.19 1400.00 196.36 17.74 178.62 Pass: Major Risk PB S Pad S-42 S-42 V2 1390.19 1400.00 196.36 17.74 178.62 Pass: Major Risk PB S Pad S-43L1 S-43L1 V2 1096.93 1100.00 149.22 15.71 133.51 Pass: Major Risk PB S Pad S-43 S-43 V3 1096.93 1100.00 149.22 15.71 133.51 Pass: Major Risk PB S Pad S-44L1PB1 S-44L1PB1 V3 1297.82 1300.00 120.23 17.12 103.11 Pass: Major Risk PB S Pad S-44L1 S-44L1 V5 1297.82 1300.00 120.23 17.12 103.11 Pass: Major Risk PB S Pad S-44 S-44 V10 1297.82 1300.00 120.23 17.12 103.11 Pass: Major Risk • Field: Prudhoe Bay Site: PB S Pad Well: Plan 5-122 Wellpath: Plan S-122PB1 168 i~~' ' ___.150 3 ..41 '._ ..._. 9 r~ - `. 16. ._. 1 ~9 /~ i 17'. 0 __.100 ~_ , ~ .._ 0 ~ . F ~ ' 30 i ~h' ~ . ~ ~ \ _ - - ~,, - - 11 ~ 72\ , 0 ._y 8 °TO I~i~ , i , 7 , , 9 1" ~ -, , , 3_ ~ , ti, .~ r ~ ~_ -_ 7 .r... _ . _,. -_. \ -~ - M. - ~ ~:-~~' -t' '4 14,. 9 0 27 7 8 t.. fi ~ ~i6 _~ " / 1 ~ Y6 1 I .. 12 .. SO ~ `-.. ,' -r 13 ,, ~ 0 ~ ,' ~. ' 1 1 ~ ~ 24 ~ g ,`, .:, ~ 1 .-~~ 20 < ,, ~ ~. // ,,. YV/ - -, ~- ~ 0 ~ , ~ ~-.. ~" 8 ~ "_. . '~ i1~. ~ ., l .:. JJ - -950 _.B .. l 1S 168 180 I Travelling Cylinder Aamufh (TFO-~AZ]) [deg] vs Centre [o Centre Separation [SOft/in] Target: S-122PB1 Tgt 1 Site: PB S Pad Well: Plan 5-122 Drilling Target Conf.: 95% Based on: Planned Program Description: Vertical Depth: 6680.00 ft below Mean Sea Level Map Northing: 5986910.00 ft Local +N/-S: 6349.98 ft Map Easting : 616710.00 ft Local +E/-W: -21 ] 9.64 ft Latitude: 70°22'22.741N Longitude: 149°03'04.952W Polygon X ft Y ft Map E ft Map N ft 1 -152.38 -147.61 616560.00 5986760.00 2 -147.61 152.38 616560.00 5987060.00 3 152.38 147.61 616860.00 5987060.00 4 147.61 -I52.38 616860.00 5986760.00 ~0 ~~ ~o N ~o ~o ~o ~o ~~ p p G m c~ - o ~ ~ ~ (~ ~ cv cv cv cv i i ~~ ,,,, ~~ 3, S-122 (P5 Client: BPExpiorationAlaska Field: Prudhoe Bay Unit - WOA Structure l Slot: Well: 5-PAD / S• 122 ® ' I; Plan S-122 Borehole: ~ 1 Plan S-122 UWUAPI#: 50029 Survey Name 1 Date: 5-122 (PS) /April 15, 2005 Tort I AHD 1 DDI 1 ERD ratio: 177.643° 18390.26 ft 16.41311.236 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location LaULong: N 70.35563694, W 149.03414922 Location Grid NIE YIX: N 5980595.000 ftUS, E 618930.000 ftUS Grid Convergence Angle: +O.g0964555° Grid Scale Factor: 0.99991607 Isar Schlumherger Survey I DLS Computation Method: Minimum Curvature I Lubinski Vertical Section Azimuth: 304.740° Vertical Section Odgin: N 0.000 ft, E 0.000 ft ND Reference Datum: Rotary Table ND Reference Elevation: 64.20 ft relative to MSL Sea Bed I Ground Level Elevation: 35.70 ft relative to MSL Magnetic Declination: 24.572° iota) Field Strength: 57629.740 nT Magnetic Dip: 80.849° Declination Date: June 20, 2005 • Magnetic Declination Model: BGGM 2004 North Reference: True Narth Total Corr Mag North -> True North: +24.572° Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Hole NS EW DLS Tool Face Build Rate Walk Rate Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft R ft de 1008 de de tt00ft de Y100ft ftU5 RUS I op vvnlpsroclc Base Whipstock KOP Crv 18/100 90° Pt End Crv Crv 101100 lVL W.VV J0.54 10223.00 60.74 10235.00 60.74 10250.00 63.26 10300.00 71.70 10350.00 80.20 10400.00 88.72 10407.50 90.00 10450.00 97.25 10454.90 98.08 10679.81 98.08 10700.00 97.55 10750.00 96.19 10800.00 94.78 10850.00 93.35 10900.00 91.89 10950.00 90.42 JJ.7.10 000.14 U/3J.yY 333.98 6676.27 6740.47 333.98 6682.14 6746.34 332.88 6689.18 6753.38 329.50 6708.32 6772.52 326.43 6720.45 6784.65 323.52 6725.27 6789.47 323.09 6725.36 6789.56 320.63 6722.67 6786.87 320.35 6722.02 6786.22 320.35 6690.40 6754.60 318.38 6687.66 6751.86 313.54 6681.67 6745.87 308.71 6676.89 6741.09 303.91 6673.34 6737.54 299.13 6671.06 6735.26 294.35 6670.05 6734.25 0J40. y.`1 001~.4V OJJ4.0'1 -LI IG.00 V.VV -JV.UVV V.VU V.UU UJ000yY.00 O10/ I/.VH IV /V.J/GJY 10V VY IYJ.VO IJGU IO 5355.74 6830.64 6344.70 -2117.68 16.00 O.OOG 13.90 -9.17 5986904.73 616712.05 N 70.37296923 W 149.05135939 5364.87 6841.11 6354.10 -2122.27 0.00 -21.49G 0.00 0.00 5986914.07 616707.31 N 70.37299493 W 149.05139673 5376.49 6854.35 6365.95 -2128.19 18.00 -20.97G 16.78 -7.38 5986925.82 616701.20 N 70.37302728 W 149.05144490 5417.82 6900.50 6406.35 -2150.47 18.00 -19.67G 16.88 -6.76 5986965.86 616678.29 N 70.37313765 W 149.05162600 5462.36 6948.96 6447.42 -2176.19 18.00 -18.93G 16.99 -6.13 5987006.50 616651.93 N 70.37324981 W 149.05183514 5509.00 6998.68 6488.12 -2204.73 18.00 -18.65G 17.04 -5.82 5987046.75 616622.75 N 70.37336100 W 149.05206717 5516.11 7006.18 6494.14 -2209.21 18.00 -18.64G 17.06 -5.75 5987052.69 616618.17 N 70.37337742 W 149.05210360 5556.62 7048.56 6527.48 -2235.38 18.00 -18.80G 17.05 -5.78 5987085.61 616591.48 N 70.37346848 W 149.05231637 5561.29 7053.42 6531.22 -2238.47 18.00 O.OOG 17.04 -5.86 5987089.30 616588.33 N 70.37347871 W 149.05234149 5775.76 7276.10 6702.67 -2380.57 0.00 -105.21G 0.00 0.00 5987258.46 616443.54 N 70.37394696 W 149.05349679 5795.11 7296.10 6717.84 -2393.59 10.00 -105.47G -2.65 -9.73 5987273.42 616430.28 N 70.37398841 W 149.05360269 5843.79 7345.74 6753.51 -2428.09 10.00 -106.05G -2.72 -9.69 5987308.54 616395.22 N 70.37408583 W 149.05388318 5893.23 7395.51 6786.24 -2465.57 10.00 -106.51G -2.81 -9.64 5987340.66 616357.22 N 70.37417519 W 149.05418789 5943.07 7445.38 6815.76 -2505.75 10.00 -106.S6G -2.87 -9.60 5987369.54 616316.59 N 70.37425581 W 149.05451450 • 5992.93 7495.33 6841.86 -2548.31 10.00 -107.07G -2.92 -9.57 5987394.96 616273.62 N 70.37432708 W 149.05486052 6042.41 7545.31 6884.34 -2592.95 10.00 -107.17G -2.95 -9.56 5987416.73 616228.64 N 70.37438846 W 149.05522333 6056.24 7559.40 6870.00 -2605.85 10.00 -180.OOG -2.95 -9.55 5987422.18 616215.65 N 70.37440390 W 149.05532819 6091.38 7595.29 6884.02 -2638.89 10.00 -180.OOG -10.00 -0.05 5987435.67 616182.39 N 70.37444216 W 149.05559676 6104.42 7608.61 6889.22 -2651.15 10.00 O.OOG -10.00 -0.05 5987440.67 616170.05 N 70.37445636 W 149.05569646 6510.57 8023.48 7051.15 -3033.11 0.00 O.OOG 0.00 0.00 5987596.50 615785.60 N 70.37489833 W 149.05880137 6530.33 8043.67 7059.03 -3051.70 10.00 O.OOG 10.00 0.05 5987604.09 615766.89 N 70.37491985 W 149.05895245 6558.75 8072.69 7070.37 -3078.41 10.00 90.OOG 10.00 0.05 5987615.00 615740.00 N 70.37495079 W 149.05916965 6577.85 8092.14 7078.27 -3096.18 10.00 O.OOG 0.00 10.00 5987622.62 615722.11 N 70.37497235 W 149.05931410 6871.63 8390.26 7204.00 -3366.50 0.00 O.OOG 0.00 0.00 5987744.03 615449.86 N 70.37531553 W 149.06151161 S-122 Tgt 1 10964.09 90.00 293.00 6670.00 6734.20 11000.00 86.41 292.98 6671.13 6735.33 End Crv 11013.36 85.07 292.97 6672.12 6736.32 Crv 6/100 11429.76 85.07 292.97 6707.88 6772.08 11450.00 87.10 292.98 6709.26 6773.46 S-122 Tgt 2 11479.04 9,0.00 293.00 6710.00 6774.20 End Crv 11498.48 ~j0.00 294.94 6710.00 6774.20 TD / 4-112" Lnr 11796.61 / 90.00 294.94 6710.00 6774.20 Legal Description: Surface : 4391 FSL 4499 FEL S35 T12N R12E UM BHL : 1034 FSL 2577 FEL S22 T12N R12E UM Northing IY) fftUSl Easting (X) fftUSl 5980595.00 618930.00 5987744.03 615449.86 WeIlDesign Ver Bld( doc40x_37) 5-122\Plan 5-122\Plan 5-122\S-122 (PS) Generated 4/15/2005 8:37 AM Page 1 of 1 ~~, ~ ~~~ ~ :~m' SChlut~~~n~g~r ~~~,. a E~~ S-122 (P5) .~F~o Prudhoe Bay Unit - WOA =rRU~rVpE S-PAD 5400 5600 5800 6000 6200 6400 6600 6800 6600 0 0 `~'• 6800 c `~ F 7000 7200 5400 5600 5800 6000 6200 6400 6600 6800 Vertical Section (ft) Azim = 304.74°, Scale = 1(in):200(ft) Origin = 0 N/-S, 0 E/-W • 6600 6800 7000 • 7200 ~. ~~ ;, ~ ~~t. WE" S-122 (P5) FIFLD Prudhoe Bay Unit - WOA GTRU`TGRE S-PAD Magnetic Parameters SuHece Locepon NTDZ] Nbska Sbte Pones. Zone OC, US Fael M'acelhneous Model: SGGM 2004 Dip: 80.649° Dais: June 20. 2006 Lal: N]0 21 20.293 NoMng: 596059500 flU5 G~q Conv: W.90964556° Sbl: 5122 ND Ref: Robry TaOb (64 20 fl above MSL) Map Da: X24.6]2° F6: 6)fi29.]nT ton: W1492293] Fasap: 616830.00 kUS Scale Fact 099991606]6 Plan: 5121 (P6) Sivy Dab: i?pN 22. 2006 -3600 -3400 -3200 -3000 -2800 -2600 -2400 -2200 7200 7000 A A A Z 0 0 N .:. 6800 a~ `~ v v v 6600 6400 -2000 ~, 7D 14112" Lni, End f$v S•122 Tgt 2 Crv 6N 00 „, ••., KOP Crv 18N 00 ~~Base W6ipstoek \ op Whipbtoek -2 B1 (P ) -3600 -3400 -3200 -3000 -2800 -2600 «< W Scale = 1(in):200(ft) E »> -2400 -2200 -2000 7200 7000 6800 • 6600 6400 L ~ • Schlumberger Anticollision Report Company: BP Amoco Date: 4/15/2005 'l'ime: 09:13.13 Page: I Field: Prudhoe Bay Reference Site: PB S Pad Co-ordinate(NE) Reference: Well: Plan S-122, Tru e North Reference Well: Plan S-122 Vertical (TVD) Reference: S-122 Plan 64.2 Reference WellpatlPJan S-122 Ub: Sybase NO GLOBAL SCAN: Using user defined selection & scan criteria Reference: Principal Plan & PLANNED PROGRAM Interpolation MethodMD Interval: 50.00 ft Error Model: ISCWSA Ellipse Depth Range: 10210.00 to 11796.61 ft Scan Method: Trav Cylinder North Maximum Radiu9D000.00 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 4/15/2005 Validated: No Version: 3 Planned From To Survey Toolcode Tool Name ft ft 28.50 1800.00 Planned: Plan #2 V2 (1) GYD-GC-SS Gyrodata gyro single shots 1800.00 10210.00 Planned: Plan #2 V2 (1) MWD+IFR+MS MWD + IFR + Multi Station 10210.00 11796.61 Planned: Plan #5 V1 BLIND Blind drilling Casing Points A1D CVU Diameter Hole Size \ame ft ft in in 3067.95 2814.20 9.625 12.250 9 5/8" 10467.00 6784.52 7.000 8.750 7" 11758.92 6774.20 4.500 6.125 4-1/2" Summary <______________________ Offset Wellpath ----------------------> Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MU UistanccArea Deviation Warning ft ft ft ft ft PB S Pad Plan S-111 Plan S-111 V8 Plan: PI 10539.42 10000.00 1334.55 260.72 1073.83 Pass: Major Risk PB S Pad Plan S-111 Plan S-111 P61 V3 Plan: 10539.42 10000.00 1334.55 260.87 1073.68 Pass: Major Risk PB S Pad Plan S-122 Plan S-122PB1 V2 Plan: 10249.91 10250.00 1.56 178.49 -176.93 FAIL: Major Risk PB S Pad S-03 S-03 V1 11694.48 11800.00 3787.80 511.74 3276.06 Pass: Major Risk PB S Pad S-102 S-102 V11 11686.79 9400.00 2359.31 542.13 1817.18 Pass: Major Risk PB S Pad S-102 S-102L1 V5 11686.79 9400.00 2359.31 541.53 1817.78 Pass: Major Risk PB S Pad S-102 S-102L1PB1 V7 11686.79 9400.00 2359.31 541.42 1817.89 Pass: Major Risk PB S Pad S-102 S-102P61 V14 Out of range PB S Pad S-103 S-103 V6 11265.11 10078.00 1536.70 399.94 1136.76 Pass: Major Risk PB S Pad S-107 S-107 V36 11670.96 8400.00 3747.02 483.43 3263.59 Pass: Major Risk PB S Pad S-119 S-119 V7 11687.36 8050.00 3919.14 466.12 3453.02 Pass: Major Risk • Field: Prudhoe Bay Site: PB S Pad Well: Plan 5-122 Wellpath: Plan S-122 6S 0 50 .. .. 150 .. ,~..... 3 Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [SOft/in] Site: PB S Pad Drilling Target Conf.: 90% Description: Map Northing: 5987422.00 ft Map Fasting :616216.00 ft Latitude: 70°22'27.852N Polygon X ft 1 374.90 2 -57.93 3 -763.94 4 -757.90 5 304.91 6 598.54 Target: 5-122 Tgt 1 Yft -578.07 -121.11 140.16 520.14 53.17 -351.58 Well.; Plan S-122 Based on: Planned Program Vertical Depth: 6670.00 ft below Mean Sea Level Local +N/-S: 6869.80 ft Local +E/-W: -2605.49 ft Longitude: 149°03'19.171 W Map E ft Map N ft 616600.00 5986850.00 616160.00 5987300.00 615450.00 5987550.00 615450.00 5987930.00 616520.00 5987480.00 616820.00 5987080.00 a • J J ~ N J U 0 ~o ~ c~ o m ~ ~- r~ o m ~_ ~ m m m m c~ N N N N I I - TERRIE L NUBBLE BP EXPLORATION AK INC „M PO BOX 196612 IVIB 7-5 2 20.1 ANCHORAGE, astercard Check" _ 8s-si12s _ AK 99519-6612 PAY TO THE DATE. ~'p2~~ C 'ORDER OF . Q°~ First aUona Dank Alaska '` Anchorage, AK 99501 MEMO ~~ 1 2 5 200060:99 i4~r~ 6227~~~L5.5.6,,. p20L • • • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ~~v( S- / 2 2 PTD# Z.OS- O ~ I CHECK WHAT ADD-ONS "CLUE" APPLIES OPTIONS) MtTLTI The permit is for a new wellbore segment of LATERAL existing well , Permit No, API No. (If API number Production should continue to be reported as last two (2) digits a function of the original API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(f), all (PIS records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject to full EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce/infect is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the SAMPLE Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Rev: 04/01/05 C\jody\transmittal_checklist WELL PERMIT CHECKLIST Fieltl & Pool PRUDHOE BAY, AURORA OIL - 640120 C Well Name: PRUDHOE BAY UN AURO S-122 Program DEV Well bare seg ^ PTD#:2050810 Company BP EXPLORATION (ALASKA) INC Initial ClasslType DEV! 1-OIL GeoArea Unit On/Off Shore On Annular Disposal ^ Administration 1 Permit fee attached - Yes - - - - 2 Lease number appropriate - - - - - -Yes - - - ------------------------------------------- 3 Uniquewell_nameandnumber_____________________________ _________Ye5__-.- .--.------_-_---.--._- 4 Welllocakedin-a_de_finedpool-------------___- _Yes--_-,_ _-.__-___-__-__- - - 5 Well located properdistance_fromdri1ling unit_boundary_ _ _ - Yes _ _ , - - - - - - 6 Well locatedproperdistancefromotherwells_____________________ _______-Yes_____ ----________-__--_---________-_--_--_,-_-__ ------------------------ 7 Sufficient acreageavail_ablein.dlil_lingunit-.__---------------_- __-__-_-_Yes_-_-._ _-._---_____-___-___,-_--_-__-.__-__-_--_____-__--_-- _-_--_ 8 If deviated, is-wehboreplat_included__________________________ __-__-__ Yes____- __,___-_-_____-___-_- - - - 9 Operator only affected party__-----__- __ - - -_-__-__Yes_-__-- __, - - - - - 10 Operatorhas_appropriate-bond in force ------ -- - -- - -- --- -- Yes-- --- - --- ---------- -- --- ----- ---- ------ -- ------ --- ---- 11 Permit-can be issued withoutconseryationQrder-------------_-_- __--__-__Yes--_-_- __.__--__-___-__-____-,______-_-__-_-____-__--_--_-__-_---_- Appr Date 12 Permitcanbeissuedwithoutadministrativeapproval--_-___-_-__- -_- --__-Yes______ _________________________-____ - -- -------- RPC 5/2512005 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strata authorizedbyJojectionOrder#(put_I9#incomrnents)-(For_ NA_______ _____________________________-___-__--_-__-,__-__-_--_--__-_-_--_-- 15 All wells within 114-mile area of review identified (For service well only) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ _ _ - _ - - - _ . - _ - - ------------------------------------------------------------ 16 Pre-produced injector duration ofpre-production less than_ 3 months-(For service well only) - _ NA_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - 17 ACMP-Finding of Consistency-has been issued_forthis p[oject_ - _ - - _ NA- _ - - _ Engineering 18 Conductorsi[ing_pravided__-____--_____ _-__ _,__-__--Yes__.__ -20'"x34"-@109'_______________ 19 Surface casingprQtects allknown USDWS - - - - - Yes - - - - - - - - 20 CMT-vol_ adequate-to circul_ate_on conductor_ & su_rf,csg _ - - _ - _ _ _ _ - _ _ - - _ _ _ _ _ - _ Yes _ - _ _ _ _ Adequate excess_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - _ _ _ -------------------------------- 21 CMT_vol- adequate.to tie-in long string tosurf csg- N0 - - - - - - - - - - - - - 22 CMT_will coyer all knownproductive horizons_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ --- Yes - _ _ - - _ -------- _ _ _ _ - - - - - _ ---------------------------------------------------------- 23 Casing designs adequate for C,TB&-permafr_ost------------------ ---- ----Yes------ ---------------------------------------------.------------------- 24 Adequatetankage.orreservepit____________________________ ___---_-Yes_--_-- -Nabors-TES,-_--______--_____--_-__--__._ - - - - - 25 If a-re-drill, has_a_ 10-4.03 for abandonment been approved - _ _ - - _ - - - - - - - - - - - - - NA_ _ _ _ _ _ _ -New well, _ _ - _ _ _ _ _ _ - - _ - . _ ----------------------------------------------- 26 Adequatewellboreseparation.proposed________________________ _______-Yes_____ __.___,___-_.-_-- ---------------------------------------------------- 27 1f_divertertequired,doesitmeetregulations_____________________ __-_,_-Yes-__-__ _-___.-_. Appr Date 28 Drillingfluid_programschematic&equiplistadequate-_-_----------- ---------Yes____- _MaxMW-10,5_ppg._-_-.__-_____,_____----_--_----___.____-___-_-- WGA 5125!2005 29 BOPES, do they meet regulation - - - - - - - - Yes - - - - - - - - - - - - - - 30 BOPE_press rating appropriate; test to_(put psig incomments)- - - - - - - - - - - - - -Yes _ _ - - Test to 3500 ps!• _MSP 2808 psi.- _ _ _ - _ - - - - 31 Choke-manifold complies wlAPl_RP-53(May84)__-__-__-_-___-_ _-____-_Yes_-___- ___-__ --------------------------------------------------------------- 32 Work willoccur-withoutoperationshutdown_____________________ ___,__Yes__-___ -__-- --__, ---------------------------------------------------------- 33 IspresenceofH2Sgasprobable___ -_ -- --No_____ _NotapH2Spad._-__--_-__--_-_._._--__-_------------------- --- 34 Mechanical condition of wells within AOR verified (For service well only - NA_ _ Geology 35 Permit-can be issued w/o hydrogen_sulfide measures - - . - - - - - No- _ - - - _ _ - -- - - - 36 Data-presented onpote_olio/overpressurezones____-_-___-_-____ _-__-__-NA_______ _________-_--__-__-_--_-___-_-- - - Appr Date 37 Seismicanalysisofshallowgas_zones_________________________ ________NA_-__-- _--_- - - - - - RPC 5/2512005 38 Seabed condition survey-(ii off_-shore) - _ - - _ - - NA- - - - 39 _ Contact name/phone for weekly progress_reports [exploratory only]. - ,NA_ _ _ Geologic Engineering Public Commissioner: Date: Commissioner: Date s ner Date ~~.~ .~~~s~S ~~~~ Szs-~r ~~Q~" •
