Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
210-010
From:Wallace, Chris D (CED) To:AOGCC Records (CED sponsored) Subject:FW: OPERABLE: Injector S-41A (PTD #2101010) AA for water injection only Date:Tuesday, October 26, 2021 9:34:36 AM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Monday, October 25, 2021 3:40 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: OPERABLE: Injector S-41A (PTD #2101010) AA for water injection only Mr. Wallace, Injector S-41A (PTD #2101010) AA 3C.004 has been received for continued water injection only. The well is now classified as OPERABLE and may remain online under conditions laid out in the approval. 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 (CED) <chris.wallace@alaska.gov> Sent: Wednesday, October 13, 2021 1:08 PM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: [EXTERNAL] Re: Request to keep Injector S-41A (PTD #2101010) on Water Injection Andy, Water only injection is approved until the Admin Approval request can be processed. Any questions please get back to me. Regards Chris From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Wednesday, October 13, 2021, 12:55 PM To: Wallace, Chris D (CED) Cc: Regg, James B (CED); Oliver Sternicki; PB Wells Integrity Subject: Request to keep Injector S-41A (PTD #2101010) on Water Injection Mr. Wallace, Injector S-41A (PTD #2101010) is currently Under Evaluation for TxIA communication. A passing AOGCC witnessed MIT-IA was performed on 09/02/21 with the well on MI, but still exhibited TxIA communication when on MI. The well was swapped to PWI on 09/21/21. After additional monitoring, Hilcorp has submitted a request for Administrative Approval to continue Water Only Injection. Hilcorp requests your approval to keep the well on water only injection while the AA is processed. Please let me know if you have any questions or concerns. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: Alaska NS - PB - Field Well Integrity Sent: Friday, September 17, 2021 7:36 AM To: Alaska NS - PB - Field Well Integrity <PBWellsIntegrity@hilcorp.com>; Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: UPDATE UNDER EVALUATION: Injector S-41A (PTD #2101010) Slow TxIA while on MI Mr. Wallace, Injector S-41A (PTD #2101010) was found to have slow TxIA communication while shut on MI on 08/06/21. An AOGCC MIT-IA Passed on 09/02/21 confirming competent well barriers. TxIA communication was observed when the well was placed back on MI injection. The well will now be put on PWI UNDER EVALUATION for an additional 28 day monitoring period and AA application for continued injection on PWI only. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: Alaska NS - PB - Field Well Integrity Sent: Friday, August 20, 2021 12:13 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: UNDER EVALUATION: Injector S-41A (PTD #2101010) Slow TxIA while shut in Mr. Wallace, Injector S-41A (PTD #2101010) MI injection was shut in on 08/06/21. The IA casing pressure was found to be 720 psi on 08/19/21 with a slow uptrend over the preceding 10 days. DHD bled the IAP with mixed gas / liquid returns to 200 psi and subsequent monitoring indicates a 1 psi / hour build up rate. The well is now classified as UNDER EVALUATION and on a 28 day clock to be resolved. Plan Forward: 1. Fullbore: AOGCC MIT-IA x1.1 maximum anticipated injection pressure 2. Well Integrity: Apply for AA for continued WAG service. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Sent: Wednesday, July 7, 2021 5:51 AM To: Alaska NS - PB - EOC Specialists <EOCSpecialists@hilcorp.com>; Alaska NS - PB - Wells Optimization Engineers <WellsOE@hilcorp.com>; Alaska NS - PB W - GC2 - Field Lead Operator <GC2FieldLO@hilcorp.com>; Alaska NS - PB W - GC2 - Foreman <GC2Foreman@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad HUQ <AlaskaNS-PBW-GC2-WellpadHUQ@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad LV <AlaskaNS-PBW-GC2-WellpadLV@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad MN <AlaskaNS-PBW-GC2-WellpadMN@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad RJ <AlaskaNS-PBW-GC2-WellpadRJ@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad S <AlaskaNS-PBW- GC2-WellpadS@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad W <AlaskaNS-PBW-GC2- WellpadW@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad Z <AlaskaNS-PBW-GC2- WellpadZ@hilcorp.com>; Alaska NS - PB W - GC3 - ProdContCentLeads <GC3ProdContCenterLeads@hilcorp.com>; Brian Glasheen <Brian.Glasheen@hilcorp.com>; Brodie Wages <David.Wages@hilcorp.com> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com>; Aras Worthington <Aras.Worthington@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: OPERABLE: Injector S-41A (PTD #2101010) AA cancelled All, The AA cancellation has been processed and the well is now classified as OPERABLE. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Sent: Monday, July 5, 2021 10:26 AM To: Alaska NS - PB - EOC Specialists <EOCSpecialists@hilcorp.com>; Alaska NS - PB - Wells Optimization Engineers <WellsOE@hilcorp.com>; Alaska NS - PB W - GC2 - Field Lead Operator <GC2FieldLO@hilcorp.com>; Alaska NS - PB W - GC2 - Foreman <GC2Foreman@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad HUQ <AlaskaNS-PBW-GC2-WellpadHUQ@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad LV <AlaskaNS-PBW-GC2-WellpadLV@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad MN <AlaskaNS-PBW-GC2-WellpadMN@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad RJ <AlaskaNS-PBW-GC2-WellpadRJ@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad S <AlaskaNS-PBW- GC2-WellpadS@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad W <AlaskaNS-PBW-GC2- WellpadW@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad Z <AlaskaNS-PBW-GC2- WellpadZ@hilcorp.com>; Alaska NS - PB W - GC3 - ProdContCentLeads <GC3ProdContCenterLeads@hilcorp.com>; Brian Glasheen <Brian.Glasheen@hilcorp.com>; Brodie Wages <David.Wages@hilcorp.com> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com>; Aras Worthington <Aras.Worthington@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: UPDATE UNDER EVALUATION: Injector S-41A (PTD #2101010) AA cancellation in progress All, Injector S-41A (PTD #2101010) no longer exhibits TxIA communication on MI after the extended packing DGLV was set. The AOGCC has given approval to keep the well online while the AA for TxIA communication is cancelled. The Under Evaluation clock will be reset for tracking purposes until the cancellation is processed. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: Alaska NS - PB - Field Well Integrity Sent: Saturday, March 27, 2021 6:00 AM To: Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com>; Alaska NS - PB - EOC Specialists <EOCSpecialists@hilcorp.com>; Alaska NS - PB - Wells Optimization Engineers <WellsOE@hilcorp.com>; Alaska NS - PB W - GC2 - Field Lead Operator <GC2FieldLO@hilcorp.com>; Alaska NS - PB W - GC2 - Foreman <GC2Foreman@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad HUQ <AlaskaNS-PBW-GC2-WellpadHUQ@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad LV <AlaskaNS-PBW-GC2-WellpadLV@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad MN <AlaskaNS- PBW-GC2-WellpadMN@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad RJ <AlaskaNS-PBW-GC2- WellpadRJ@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad S <AlaskaNS-PBW-GC2- WellpadS@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad W <AlaskaNS-PBW-GC2- WellpadW@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad Z <AlaskaNS-PBW-GC2- WellpadZ@hilcorp.com>; Alaska NS - PB W - GC3 - ProdContCentLeads <GC3ProdContCenterLeads@hilcorp.com>; Brian Glasheen <Brian.Glasheen@hilcorp.com>; Brodie Wages <David.Wages@hilcorp.com> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Aras Worthington <Aras.Worthington@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: UPDATE UNDER EVALUATION: Injector S-41A (PTD #) AOGCC approved trial period on MI All, Injector S-41A (PTD # 210101) is currently not taking MI and is shut in. The well will remain Under Evaluation and the clock will be adjusted as needed when the well does return to injection to ensure there is a full 60 day trial period of MI. Please respond with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Sent: Thursday, March 18, 2021 6:25 AM To: Alaska NS - PB - EOC Specialists <EOCSpecialists@hilcorp.com>; Alaska NS - PB - Wells Optimization Engineers <WellsOE@hilcorp.com>; Alaska NS - PB W - GC2 - Field Lead Operator <GC2FieldLO@hilcorp.com>; Alaska NS - PB W - GC2 - Foreman <GC2Foreman@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad HUQ <AlaskaNS-PBW-GC2-WellpadHUQ@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad LV <AlaskaNS-PBW-GC2-WellpadLV@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad MN <AlaskaNS-PBW-GC2-WellpadMN@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad RJ <AlaskaNS-PBW-GC2-WellpadRJ@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad S <AlaskaNS-PBW- GC2-WellpadS@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad W <AlaskaNS-PBW-GC2- WellpadW@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad Z <AlaskaNS-PBW-GC2- WellpadZ@hilcorp.com>; Alaska NS - PB W - GC3 - ProdContCentLeads <GC3ProdContCenterLeads@hilcorp.com>; Brian Glasheen <Brian.Glasheen@hilcorp.com>; Brodie Wages <David.Wages@hilcorp.com> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com>; Aras Worthington <Aras.Worthington@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: UNDER EVALUATION: Injector S-41A (PTD #) AOGCC approved trial period on MI All, Injector S-41A (PTD # 210101) currently operates under AA AIO 3B.002 for PWI only due to slow TxIA when on MI. On 03/06/21 Slickline replaced the DGLV in sta #2 with an extended packing DGLV and loaded the IA with 9.8 ppg brine to remediate the TxIA when on MI. The AOGCC has granted a 60- day trial period on MI to evaluate the repair. The well is now classified as UNDER EVALUATION and can be placed on MI. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1 Guhl, Meredith D (CED) From:Wallace, Chris D (CED) Sent:Wednesday, September 22, 2021 7:17 AM To:AOGCC Records (CED sponsored) Subject:FW: UPDATE UNDER EVALUATION: Injector S-41A (PTD #2101010) Slow TxIA while on MI From: Alaska NS ‐ PB ‐ Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Sent: Friday, September 17, 2021 7:36 AM To: Alaska NS ‐ PB ‐ Field Well Integrity <PBFieldWellIntegrity@hilcorp.com>; Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: UPDATE UNDER EVALUATION: Injector S‐41A (PTD #2101010) Slow TxIA while on MI Mr. Wallace, Injector S‐41A (PTD #2101010) was found to have slow TxIA communication while shut on MI on 08/06/21. An AOGCC MIT‐IA Passed on 09/02/21 confirming competent well barriers. TxIA communication was observed when the well was placed back on MI injection. The well will now be put on PWI UNDER EVALUATION for an additional 28 day monitoring period and AA application for continued injection on PWI only. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659‐5102 M: (907) 232‐1005 From: Alaska NS ‐ PB ‐ Field Well Integrity Sent: Friday, August 20, 2021 12:13 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: UNDER EVALUATION: Injector S‐41A (PTD #2101010) Slow TxIA while shut in Mr. Wallace, Injector S‐41A (PTD #2101010) MI injection was shut in on 08/06/21. The IA casing pressure was found to be 720 psi on 08/19/21 with a slow uptrend over the preceding 10 days. DHD bled the IAP with mixed gas / liquid returns to 200 psi and subsequent monitoring indicates a 1 psi / hour build up rate. The well is now classified as UNDER EVALUATION and on a 28 day clock to be resolved. Plan Forward: 1. Fullbore: AOGCC MIT‐IA x1.1 maximum anticipated injection pressure 2. Well Integrity: Apply for AA for continued WAG service. 2 Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659‐5102 M: (907) 232‐1005 From: Alaska NS ‐ PB ‐ Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Sent: Wednesday, July 7, 2021 5:51 AM To: Alaska NS ‐ PB ‐ EOC Specialists <EOCSpecialists@hilcorp.com>; Alaska NS ‐ PB ‐ Wells Optimization Engineers <WellsOE@hilcorp.com>; Alaska NS ‐ PB W ‐ GC2 ‐ Field Lead Operator <GC2FieldLO@hilcorp.com>; Alaska NS ‐ PB W ‐ GC2 ‐ Foreman <GC2Foreman@hilcorp.com>; Alaska NS ‐ PB W ‐ GC2 ‐ Wellpad HUQ <AlaskaNS‐PBW‐GC2‐ WellpadHUQ@hilcorp.com>; Alaska NS ‐ PB W ‐ GC2 ‐ Wellpad LV <AlaskaNS‐PBW‐GC2‐WellpadLV@hilcorp.com>; Alaska NS ‐ PB W ‐ GC2 ‐ Wellpad MN <AlaskaNS‐PBW‐GC2‐WellpadMN@hilcorp.com>; Alaska NS ‐ PB W ‐ GC2 ‐ Wellpad RJ <AlaskaNS‐PBW‐GC2‐WellpadRJ@hilcorp.com>; Alaska NS ‐ PB W ‐ GC2 ‐ Wellpad S <AlaskaNS‐PBW‐GC2‐ WellpadS@hilcorp.com>; Alaska NS ‐ PB W ‐ GC2 ‐ Wellpad W <AlaskaNS‐PBW‐GC2‐WellpadW@hilcorp.com>; Alaska NS ‐ PB W ‐ GC2 ‐ Wellpad Z <AlaskaNS‐PBW‐GC2‐WellpadZ@hilcorp.com>; Alaska NS ‐ PB W ‐ GC3 ‐ ProdContCentLeads <GC3ProdContCenterLeads@hilcorp.com>; Brian Glasheen <Brian.Glasheen@hilcorp.com>; Brodie Wages <David.Wages@hilcorp.com> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Alaska NS ‐ PB ‐ Field Well Integrity <PBFieldWellIntegrity@hilcorp.com>; Aras Worthington <Aras.Worthington@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; John Condio ‐ (C) <John.Condio@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: OPERABLE: Injector S‐41A (PTD #2101010) AA cancelled All, The AA cancellation has been processed and the well is now classified as OPERABLE. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659‐5102 M: (307)399‐3816 From: Alaska NS ‐ PB ‐ Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Sent: Monday, July 5, 2021 10:26 AM To: Alaska NS ‐ PB ‐ EOC Specialists <EOCSpecialists@hilcorp.com>; Alaska NS ‐ PB ‐ Wells Optimization Engineers <WellsOE@hilcorp.com>; Alaska NS ‐ PB W ‐ GC2 ‐ Field Lead Operator <GC2FieldLO@hilcorp.com>; Alaska NS ‐ PB W ‐ GC2 ‐ Foreman <GC2Foreman@hilcorp.com>; Alaska NS ‐ PB W ‐ GC2 ‐ Wellpad HUQ <AlaskaNS‐PBW‐GC2‐ WellpadHUQ@hilcorp.com>; Alaska NS ‐ PB W ‐ GC2 ‐ Wellpad LV <AlaskaNS‐PBW‐GC2‐WellpadLV@hilcorp.com>; Alaska NS ‐ PB W ‐ GC2 ‐ Wellpad MN <AlaskaNS‐PBW‐GC2‐WellpadMN@hilcorp.com>; Alaska NS ‐ PB W ‐ GC2 ‐ Wellpad RJ <AlaskaNS‐PBW‐GC2‐WellpadRJ@hilcorp.com>; Alaska NS ‐ PB W ‐ GC2 ‐ Wellpad S <AlaskaNS‐PBW‐GC2‐ WellpadS@hilcorp.com>; Alaska NS ‐ PB W ‐ GC2 ‐ Wellpad W <AlaskaNS‐PBW‐GC2‐WellpadW@hilcorp.com>; Alaska NS 3 ‐ PB W ‐ GC2 ‐ Wellpad Z <AlaskaNS‐PBW‐GC2‐WellpadZ@hilcorp.com>; Alaska NS ‐ PB W ‐ GC3 ‐ ProdContCentLeads <GC3ProdContCenterLeads@hilcorp.com>; Brian Glasheen <Brian.Glasheen@hilcorp.com>; Brodie Wages <David.Wages@hilcorp.com> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Alaska NS ‐ PB ‐ Field Well Integrity <PBFieldWellIntegrity@hilcorp.com>; Aras Worthington <Aras.Worthington@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; John Condio ‐ (C) <John.Condio@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: UPDATE UNDER EVALUATION: Injector S‐41A (PTD #2101010) AA cancellation in progress All, Injector S‐41A (PTD #2101010) no longer exhibits TxIA communication on MI after the extended packing DGLV was set. The AOGCC has given approval to keep the well online while the AA for TxIA communication is cancelled. The Under Evaluation clock will be reset for tracking purposes until the cancellation is processed. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659‐5102 M: (307)399‐3816 From: Alaska NS ‐ PB ‐ Field Well Integrity Sent: Saturday, March 27, 2021 6:00 AM To: Alaska NS ‐ PB ‐ Field Well Integrity <PBFieldWellIntegrity@hilcorp.com>; Alaska NS ‐ PB ‐ EOC Specialists <EOCSpecialists@hilcorp.com>; Alaska NS ‐ PB ‐ Wells Optimization Engineers <WellsOE@hilcorp.com>; Alaska NS ‐ PB W ‐ GC2 ‐ Field Lead Operator <GC2FieldLO@hilcorp.com>; Alaska NS ‐ PB W ‐ GC2 ‐ Foreman <GC2Foreman@hilcorp.com>; Alaska NS ‐ PB W ‐ GC2 ‐ Wellpad HUQ <AlaskaNS‐PBW‐GC2‐WellpadHUQ@hilcorp.com>; Alaska NS ‐ PB W ‐ GC2 ‐ Wellpad LV <AlaskaNS‐PBW‐GC2‐WellpadLV@hilcorp.com>; Alaska NS ‐ PB W ‐ GC2 ‐ Wellpad MN <AlaskaNS‐PBW‐GC2‐WellpadMN@hilcorp.com>; Alaska NS ‐ PB W ‐ GC2 ‐ Wellpad RJ <AlaskaNS‐PBW‐GC2‐ WellpadRJ@hilcorp.com>; Alaska NS ‐ PB W ‐ GC2 ‐ Wellpad S <AlaskaNS‐PBW‐GC2‐WellpadS@hilcorp.com>; Alaska NS ‐ PB W ‐ GC2 ‐ Wellpad W <AlaskaNS‐PBW‐GC2‐WellpadW@hilcorp.com>; Alaska NS ‐ PB W ‐ GC2 ‐ Wellpad Z <AlaskaNS‐ PBW‐GC2‐WellpadZ@hilcorp.com>; Alaska NS ‐ PB W ‐ GC3 ‐ ProdContCentLeads <GC3ProdContCenterLeads@hilcorp.com>; Brian Glasheen <Brian.Glasheen@hilcorp.com>; Brodie Wages <David.Wages@hilcorp.com> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Aras Worthington <Aras.Worthington@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; John Condio ‐ (C) <John.Condio@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: UPDATE UNDER EVALUATION: Injector S‐41A (PTD #) AOGCC approved trial period on MI All, Injector S‐41A (PTD # 210101) is currently not taking MI and is shut in. The well will remain Under Evaluation and the clock will be adjusted as needed when the well does return to injection to ensure there is a full 60 day trial period of MI. Please respond with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance 4 Ryan.Holt@Hilcorp.com P: (907) 659‐5102 M: (907) 232‐1005 From: Alaska NS ‐ PB ‐ Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Sent: Thursday, March 18, 2021 6:25 AM To: Alaska NS ‐ PB ‐ EOC Specialists <EOCSpecialists@hilcorp.com>; Alaska NS ‐ PB ‐ Wells Optimization Engineers <WellsOE@hilcorp.com>; Alaska NS ‐ PB W ‐ GC2 ‐ Field Lead Operator <GC2FieldLO@hilcorp.com>; Alaska NS ‐ PB W ‐ GC2 ‐ Foreman <GC2Foreman@hilcorp.com>; Alaska NS ‐ PB W ‐ GC2 ‐ Wellpad HUQ <AlaskaNS‐PBW‐GC2‐ WellpadHUQ@hilcorp.com>; Alaska NS ‐ PB W ‐ GC2 ‐ Wellpad LV <AlaskaNS‐PBW‐GC2‐WellpadLV@hilcorp.com>; Alaska NS ‐ PB W ‐ GC2 ‐ Wellpad MN <AlaskaNS‐PBW‐GC2‐WellpadMN@hilcorp.com>; Alaska NS ‐ PB W ‐ GC2 ‐ Wellpad RJ <AlaskaNS‐PBW‐GC2‐WellpadRJ@hilcorp.com>; Alaska NS ‐ PB W ‐ GC2 ‐ Wellpad S <AlaskaNS‐PBW‐GC2‐ WellpadS@hilcorp.com>; Alaska NS ‐ PB W ‐ GC2 ‐ Wellpad W <AlaskaNS‐PBW‐GC2‐WellpadW@hilcorp.com>; Alaska NS ‐ PB W ‐ GC2 ‐ Wellpad Z <AlaskaNS‐PBW‐GC2‐WellpadZ@hilcorp.com>; Alaska NS ‐ PB W ‐ GC3 ‐ ProdContCentLeads <GC3ProdContCenterLeads@hilcorp.com>; Brian Glasheen <Brian.Glasheen@hilcorp.com>; Brodie Wages <David.Wages@hilcorp.com> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Alaska NS ‐ PB ‐ Field Well Integrity <PBFieldWellIntegrity@hilcorp.com>; Aras Worthington <Aras.Worthington@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; John Condio ‐ (C) <John.Condio@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: UNDER EVALUATION: Injector S‐41A (PTD #) AOGCC approved trial period on MI All, Injector S‐41A (PTD # 210101) currently operates under AA AIO 3B.002 for PWI only due to slow TxIA when on MI. On 03/06/21 Slickline replaced the DGLV in sta #2 with an extended packing DGLV and loaded the IA with 9.8 ppg brine to remediate the TxIA when on MI. The AOGCC has granted a 60‐day trial period on MI to evaluate the repair. The well is now classified as UNDER EVALUATION and can be placed on MI. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659‐5102 M: (307)399‐3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. NECE VED STATE OF ALASKA • I • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS OCT 0 6 2017 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operatio GCC, ❑ Suspend 0 Perforate 0 Other Stimulate IA. Alter Casing 0 Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: d GI ci 5-7)- 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 210-010 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number 50-029-22787-01-00 7. Property Designation(Lease Number): ADL 0028262 8. Well Name and Number PBU Z-03A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 10887 feet Plugs measured feet true vertical 9000 feet Junk measured feet Effective Depth: measured 10859 feet Packer measured 9299 feet true vertical 8993 feet Packer true vertical 8325 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 33-113 33-113 1490 470 Surface 3072 9-5/8"40#L-80 32-3104 32-3080 5750 3090 ' Intermediate 9439 7"26#L-80 30-9469 30-8494 7240 5410 Production Liner 27 2-7/8"6.4#13CR8 9315-9342 8341-8368 10570 11160 Perforation Depth: Measured depth: 9967-10227 feet 10255-10475 feet 10525-10570 feet 10592-10702 feet 10735-10780 feet 10800-10810 feet 10833-10853 feet True vertical depth: 8868-8896 feet feet 8899-8917 feet 8923-8929 feet 8932-8949 feet 8955-8968 feet 8975-8979 feet 8986-8991 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 28-9469 28-8494 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: NOV , Intervals treated(measured): sc��NED N 9967'-10227',10255'-10475',10525'-10570',10592'-10702',10735'-10780',10800'-10810',10833'-10853'. 9� Treatment descriptions including volumes used and final pressure: 10 Bbls Methanol/Water,220 Bbls Slick 1%KCL w/SafeLube,92 Bbls NH4CL+F103 w/SafeLube,117 Bbls Diesel+776,98.5 Bbls NHrCL w/F103,91 Bbls 12%HCL Acid,91 Bbls 9:1 Mud Acid,35 Bbls Wax Beads,264 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 49 659 369 1624 309 Subsequent to operation: 144 931 1060 1701 237 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory 0 Development Q Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil EI Gas 0 WDSPL ❑ Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt N/A Authorized Name: Peru,Cale Contact Name: Peru,Cale Authorized Title: Petroleur�,Engine, ) Contact Email: Cale.Peru©bp.com Authorized Signature: //�� Date: !0/6 //7 Contact Phone: +1 9075644522 Form 10-404 Revised 04/2017 1/7-1— it d{ L 7—I L �ir/O�l� � RBDMS /" OCT 1 1 2017 Submit Original Only • • Alaska Oil and Gas Conservation Commission RECEIVE 333 West Seventh Avenue Anchorage, AK 99501-3572 OCT 06 AOGC< _ RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary October 5, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Acid Stimulation for Well Z-03A, PTD # 210-010. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 • • Packers and SSV's Attachment PBU Z-03A SW Name Type MD TVD Depscription Z-03A TBG PACKER 9298.75 8325.12 4-1/2" Baker S-3 Perm Packer Z-03A PACKER 9310 8336.22 3-1/2" Baker 45 KB Packer • • N m ._5= 01- DN oC - 7- -C. aL //Q�N� 0 U D a);,--rftf U m .'" a) .. O o � EUEvF- _o � oamrn Cl) uia)i_ ct 2 _Q s- a)• = � rnE o c 7 L U Cl) a) 2 Z C a a) c a N (0 o 0 O , C 't vs N O co 3 cm'( o CO co a) C U 73 C7 C �' O O x O. 0 O 0 O N 0 C > -O O CD m3 Q w V a O 'N -p C co Q C _W Z C , o N x .+ . O a) L n � N30_75 O O +-- ao ag u) 'E U 3 •c 73 Q o -0 CD ,.= o - 'rnao a � � ai = a � to. Q � a) o 3 U 0Y O u) E rn 2 m i a cu x a) U co = as CL • a ..0 r) N o � CO 0 c =a. 0 ui C Co ) o ) J - c 2 oo = c a ib E o a rnm EmE NU a) a) 000 co m aa) u) if) a) ai o ca CC > � O rnu, a) > Ls CuL .. CnE 2 I"- J in > N. N— LO CA o ods N co N C N a. c 2 a � o a) � � v o � L 'Q E � � 3 0 F- E o ami coN orno 20 N pQE 'cinaE N n. oEa. G� oUo OrnU oN a) apo0- a) N2 .0 0) acn = u) a) oE U 0)al 3 -+3 � o U u) aii ao EQ0 E (1' 3 -a 1E- I- � voo a o2 -*mEwa Q �a) E QL .. a) ' E C a)d o oo o o 2 0 m o « 2 0 O0 m UN U C o U) 0. O N _ - 7 * Nm 0 ~0 Cu w U) U C cn N ' 0_-a a o _ N COE OUCCa) r- O 4=' :C/ " ) 06 :.- '0 O •- - M 0 E o O co O a) ' U ~ � co��. o . aQto oZv 15 '75 p20c Uu) H coU ~ o + =C 0 a 5 Q - 0 o �o0 °' � Q' u) cc � O _I-- ='.. co UD '° aZ coca) UU U aoio _ _ U a L cm 4- a) a) Lo > a) w aL) c = > LO > m m ? L _� c o o O m co a) o a) U � � oc o ...= ma) . oQoa) � 0 - 0 E O O O J O u) w a) _ N L E a a) a ca a) a) 3 O _, 04 N n o Fo- m QC), o N Q-0 H o *k o o m m e g U - O >- - a) � U O I-- 0E- co a) ) rxH 1 o - - •� ol� a) a0E- � N al m rnNg U � cna w * Ja. U -, 2 _ a_.S4 i_ a : U � F- 2w : w F- pN- N- N. ti >- O O O O I- N CV 5 co co In F- a) a) a) o) 0 Q • • N C O_ Co E a� L 7 C_ O. c >+ � a d o N O o CCIa a 0 a) a) -0 _ � _ J co P. N co as co co O 3 M M C J _O O CO U u- v v) J Q a) a) + c- J � J V -10a) = m Y X v s v 2 = N ccooUcnZOZr- rn � co A N rn x_ 01 0) rn M m - N III TREE= ClW SAFETY NOTES: WELL ANGLE>70"@ 10811' ""4- WELLHEAD= RC Z-03A 1/2"CHROME TUBING 82-3/8"CHROME LNR(DEPTHS ACTUATOR= BAKER AREELMD)~' KB.H_EV= 83.75' .. BF.a.EV= 54.05' � KOP= 2573' Max Angle= 88 n 10149' Q �-I- 2101' 1- 9-5/8"TYPE H ES C6IAEIMTER Cletum I4O= 10050' ' ' 2240' -I4-1/2"HES X NP,0=3.813" I Datum ND= 8800'SS GAS LFT-1R 20"CONDUCTOR,91.5#,H-40,D=19.124" H 110' ilk ST MD ND (BV TYPE VLV LATCH FORT DATE 9 3264 3225 28 KBG2-1R DOMF BK 16 11/29/12 9-5/8"CSG,40#,L-80 BTC,D=8.835" H 3104' 8 4213 4020 33 KBG2-1R OM1' BK 0 05/30/08 7 5577 5168 34 KBG2-1R DOM_ BK 16 11/29/12 Minimum ID =1.920" @ 9316' 6 6396 5843 33 KRG2-1R DMY BK 0 11/28/12 2-3/8" PUP JOINT C 5 7217 6531 33 KBG2-1R DOME BK 16 11/29/12 4 7830 7044 34 KBG2-1R OW BK 0 05/30/08 3 8440 7558 32 KBG2-1R DOME BK 16 11/29/12 7"MARKER JOINT H 7392' I—. 2 8886 7936 28 KBG2-1 R DMY BK 0 05/30/08 1 9205 8233 13 KBG2-1R SO BK 20 02/09/13 ' ' I 9273' H4-1/2"HES X MP,D=3.813" Z ' 9294' -I r X 4-1/2"BKR S-3 PKR,D=3.875" 0I 9310' H4-1/2"BOT KB LIP,D=2.370' I ESTIMATED TOP OF CEMENT H .••9320 K , I 9315' H2-7/8"SPACER PUP JOINT,D=1.920" TUBING PUNCH(03/01/10) -I 9320'-9325' j��� 9318' H4-1/2"FESS X NP,D=3.813"(BEHIND CT LNR) •• ••• 9342' H3-1/2"BTT DEPLOY SLV,D=3.00" I ♦•4 I ♦♦ ••••. •••• •••, •j j• 9348' --{3-12"X 2-3/8"STL XO PN,D=1.92" •••• •�•• •••• •••• ♦♦ ♦♦ TOP',Jr WHIPSTOCK --I 9479' -� • �• ���. ••4,,;, C 3.80"MLLOUT WINDOW(Z-03A) 9469'-9477 � •�• s::r I4-1/2'FEZDRLL PKR(03/01/10) H 9482• • ES • 4-1/2"TBG,12.6#,13CR VAM TOP, - 9495' .-.'iii•..i•4•i .0152 bpf,D=3.958' �,•�• •••••• 17"CSG,26#,L-80 BUTT-M,.0383 bpf,D=6.276" -I 9700'1-4 ` PERFORATION SUMMARY ` REF LOG:SWS MGR/CCL ON 03/25/10 /IAA ` ANGLE AT TOP PERE:73°6-k 9967' ` Note:Refer to Production DB for historical pert data ` SIZE SPF INTERVAL Opn/Sqz DATE SOZ 1.56" 6 9967-10227 O 03/26/10 1.56" 6 10255-10475 0 03/26/10 J '�t%•••. 1.56' 6 10525-10570 0 0326/10 I �� I I 10859' 1.56" 6 10592-10702 O 03/26/10 1.56" 6 10735-10780 0 03/26/10 2-3/8'LNR,4.44#,13CR-80 STL,.0039 bpf,D=1.992" --I 10887' I 1.56" 6 10800-10810 O 03/26/10 1.56" 6 10833-10853 O 03/26/10 DATE REV BY COM48YTS DATE REV BY COM U1TS FRUDHOE BAY UNIT 09!28197 JLM ORIGINAL COMPLETION 10/25/12 RCT/JM) GLV 00&SET XX PLUG(10/10/12) WELL Z-03A 06/02/08 N3S RlNO 01/12/13 511-1/SV GLV 00&RLL PLUG(11/30/12) PERMT No:'t2100100 03/27/10 NORIJC 2 CTD SIDTRACK(Z-03A) 02/11/13 GJF/JMD GLV 00(02/09/13) AA No: 50-029-22787-01 04/05/10 SM41'PJC FWAL DRLG CORRECTIONS 07/06/17 FOJM? REMOVED SAFETY NOTE SEC 19,T11 N,R12E,976'FML&1427'FWl 06/02/11 JLJ/PJC GLV OO(05/20/11) 10/03/12 MaS/JMD GLV OO(10/01/12) BP Exploration(Alaska) • Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWelllntegrityCoordinator@bp.com> Sent: Sunday,August 07, 2016 6:38 AM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M TL;AK, OPS GC2 Wellpad Lead;AK, OPS GC2 Facility OTL; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS Prod Controllers;AK, OPS Well Pad Z; Peru, Cale; Zoesch, Eric; Regg,James B (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, OPS FF Well Ops Comp Rep;Wallace, Chris D (DOA); Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey;Obrigewitch, Beau; Pettus, Whitney; Sternicki, Oliver R;Tempel, Troy;Worthington,Aras J Subject: OPERABLE: Producer Z-03A(PTD#2100100) Passed TIFL All, Producer Z-03A(PTD#2100100) passed a Tubing Integrity Fluid Level test on 08/06/16.The passing test confirms two competent well barrier envelopes.The well is reclassified as Operable. Thanks, Adrienne McVey Well Integrity Superintendent—GWO Alaska (Alternate:Jack 0:(907)659-5102Lau) DIED JAN 1. 2.011, C:(907)943-0296 H:2376 Email: AKDCWellIntegrityCoordinator@BP.com Fr. : AK, GWO SUPT Well Integrity Sen • Sunday, July 31, 2016 9:22 AM To: A , ''S GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS GC2 Facility OTL; Cismoski, Doug A; Dani- Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Prod Controllers; AK, OPS Well Pad '• Peru, Cale; Zoesch, Eric; 'chris.wallace@alaska.gov' Cc: AK, GWO SUPT We tegrity; AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; Pettus, Whitney; Sternicki, Oliver R; AK, OPS ell Ops Comp Rep; 'Regg, James B (DOA) (iim.reqgalaska.gov)' Subject: UNDER EVALUATION: A(PTD #2100100) High Inner Annulus Pressure Over MOASP All, Producer Z-03A(PTD#2100100)was reported to have ler annulus pressure over MOASP on July 30 2016.Wellhead pressure was confirmed to be (T/IA/OA) 2110/2060/170 psi. •ad is expected to remain shut in until mid week.The well is now reclassified as Under Evaluation and well barriers will be - ified or repaired within 28 days. Plan Forward: 1. Operations: Put on Production 2. Downhole Diagnostics:Warm TIFL 3. Well Integrity: Further Diagnostics as Required Please call with any questions or concerns. 1 • • Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Sent: Sunday,July 31, 2016 9:22 AM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M IL;AK, OPS GC2 Wellpad Lead;AK, OPS GC2 Facility OTL; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS Prod Controllers;AK, OPS Well Pad Z; Peru, Cale; Zoesch, Eric;Wallace, Chris D (DOA) Cc: AK, GWO SUPT Well Integrity;AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity; Pettus,Whitney; Sternicki, Oliver R;AK, OPS FF Well Ops Comp Rep; Regg, James B (DOA) Subject: UNDER EVALUATION:Z-03A (PTD#2100100) High Inner Annulus Pressure Over MOASP All, Producer Z-03A(PTD#2100100)was reported to have inner annulus pressure over MOASP on July 30 2016. Wellhead pressure was confirmed to be (T/IA/OA) 2110/2060/170 psi.Z pad is expected to remain shut in until mid week.The well is now reclassified as Under Evaluation and well barriers will be verified or repaired within 28 days. Plan Forward: 1. Operations: Put on Production 2. Downhole Diagnostics:Warm TIFL 3. Well Integrity: Further Diagnostics as Required Please call with any questions or concerns. Ryan Holt BP Alaska-Well Integrity G'I/V Global Wells Organization Office: 907.659.5102 foto ®C 3 .2..015 SC1 s • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. La - ®1 o Well History File Identifier Organizing (done) ❑ Two -sided III IIIII II III II III ❑ Rescan Needed III IIIII II II III III RES N DIGITAL DATA OVERSIZED (Scannable) Color Items: ❑Diskettes, No. '" q E] Maps: Greyscale Items: Other, No/Type: c� V�O1 ❑ Other Items Scannable by a Large Scanner ❑ Poor Quality Originals: OVERSIZED (Non - Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: Maria Date: �(,� `� /s/ Pro Proofing III IIIIIIIIIII IIIII BY: Maria Date: f C® flo /s/ Scanning Preparation x 30 = + = TOTAL PAGES 5 (Count does not include cover sheet) BY: Maria Date: 11 0 /s/ Scanning III IIIIIIIIIII IIIII Product g Stage 1 Page Count from Scanned File: L (Count does include cov heet) Pa a Count Matches Number in Scanning Preparation: YES NO 9 g BY: Maria Date: I / / /C, C, 1 /s/ M P 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 IIIII R eScan ned III 111111 IIIII II III B Y: Maria Date: /s/ Comments about this file: Quality Checked III IIIII III II II III 10/6/2005 Well History File Cover Page.doc RECEIVED STATE OF ALASKA . A KA OIL AND GAS CONSERVATION COMMIIICN APR 16 2Q13 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon U Repair Well U Plug Perforations Lf Perforate U Other U Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other El Re -enter Suspended Well❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Na me: BP Exploration (Alaska), Inc Development❑ Exploratory ❑ 210 -010 -0 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 . 50- 029 - 22787 -01 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028262 ' PBU Z -03A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): - To Be Submitted PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 10887 feet Plugs measured None feet true vertical 8999 feet Junk measured None feet 1 Effective Depth measured 9273 feet Packer measured See Attachment feet true vertical 8299.77 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" 91.5# H-40 33 - 113 33 - 113 1490 470 Surface 3072 9 -5/8" 40# L -80 32 - 3104 32 - 3079.94 5750 3090 Intermediate None None None None None None Production 9439 7" 26# L -80 30 - 9469 30 - 8346.1 7240 5410 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 9967 - 10227 feet 10255 - 10475 feet 10525 - 10570 feet 10592 - 10702 feet 10735 - 10780 feet 10800 - 10810 feet 10833 - 10853 feet True Vertical depth 8867.94 - 8896.32 feet 8898.88 - 8916.93 feet 8922.52 - 8928.84 feet 8932.28 - 8949.33 feet 8955 - 8967.83 feet 8975.14 - 8978.61 feet 8985.78 - 8991.07 feet Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# 13Cr80 29 - 9469 29 - 8494.17 Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: SCANNED APR 2 4 2013. 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 618 837 199 964 294 Subsequent to operation: 509 1377 306 1518 334 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development El r Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil , isi Gas U WDSPLU 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.O. Exempt: N/A Contact Nita Summerhays Email Nita.Summer Printed Name Nita Summerha s / Title Petrotechnical Data Technician ZANIF : • nat _ / i /�/�i AFAW. � �!� Phone 564 -4035 Date 4/16/2013 ).3-, )/\ 1-r R8DMS APR 18 2013 A 4-m/3 Form 10-404 Revised 10/2012 /� / Submit Original Only `t L • Daily Report of Well Operations Y p p ADL0028262 ACTIVITYDATE 1 SUMMARY •' aveinegras ins a e• =no Curren • :t®®, ®® wovesa' , ®e® 440 bbls). Stacked out well to 1440/1420/120. Bled IAP from 1420 psi to 320 psi in 1 hr. During IA bleed, IA FL inflowed 6270', TP increased 60 psi. Monitor for 1 hr. IA FL unchanged, IAP increased 220 psi. Returned to WPO for POP. Job complete. Final WHPs= 1500/320/120. 9/25/2012 SV,WV= Closed. SSV, MV =Open. IA, OA =OTG. NOVP. ** *WELL FLOWING ON ARRIVAL * ** SET WHIDDON C -SUB @ 9287' SLM PULL S/O FROM STA #1 @ 9194' SLM / 9205' MD AND SET NEW S/O PULLED EMPTY WHIDDON C -SUB. RDMO ** *WELL LEFT S/I PAD OP NOTIFIED ON DEPARTURE * ** 10/1/2012 ?/I/O = 770/1180/30. Temp = SI. WHPs T & IA FL (FB request). AL SI @ casing valve, ALP = 1670 psi. TBG FL @ -5060' (between sta #8 & 9, 188 bbls). IA FL @ 6396' (sta #6, 112 bbls). 10/14/2012 SV, WV = Closed. SSV, MV = Open. IA & OA = OTG. NOVP. 09:10 T /I /O = 290/1260/100. Temp = 80II. TIFL FAILED (Pre ACID). ALP = 1260 psi, AL open © casing valve. OAP from tree gauge, unable to access below grating. IA FL @ 9205' (Sta #1, SO). TP stacked out to 1500 psi in 1 hour. Bled IAP from 1300 psi to 400 psi in 3 hours. IA FL rose 4535' in 2nd hour to 4670'. IA FL rose 3506' in 3rd hour to 1140'. During one hour monitor TP increased 110 psi, IAP increased 200 psi, Tbg FL rose 284' to 8326', and IA FL fell out 768' to 1932'. Turn well over to Pad Op. Job Complete. Final WHPs = 1470/600/100. 1/31/2013 SV, WV = C. SSV, MV = O. IA, OA = OTG. NOVP. 1700 hrs. ** *WELL FLOWING ON ARRIVAL * ** (g /1 - integrity) SET 4 -1/2" WHIDDON C -SUB @ 9290' SLM PULL STA #1 BK -OGLV @ 9181' SLM /9205' MD (check was stuck open with debris) 2/8/2013 ** *CONT. ON 2/9/13 WSR * ** * * *CONT. FROM 2/8/13 WSR * ** (g /I - integnty) SET STA #1 BK -OGLV @ 9181' SLM /9205' MD PULL 4 -1/2" WHIDDON C -SUB @ 9290' SLM 2/9/2013 ** *WELL S/I ON DEPARTURE * ** ?/I/O = 300/1470/140. Temp = 82 °. TIFL PASSED (Pre Acid). Post OGLV CIO. ALP = 1470 psi, AL open @ casing valve. IA FL @ 9205' (Sta # 1, SO). Stacked out tubing pressure to 1540 psi in 1 hour and 15 minutes. Bled IAP from 1600 psi to 430 psi in 2 hours. During 1 hour monitor TP, IAP, OAP and IA FL unchanged. Turned well over to Pad Op. Job Complete. Final WHPs = 1540/430/140. 2/11/2013 SV, WV = C. SSV, MV = O. IA, OA = OTG. NOVP. 1700 hrs. CTU -8 w/ 1.5" coil, drift to td contingent mill scale memory GR /CCL /S TP. Spot unit, RU, MU 1.75" drift assembly w /BOT Tempress Adg. assembly OAL 20.26', RIH. Tagged @ 10.818' pumped down w /Tempress tool to 10,839'. Wgt back 10833', Flag @ 10813', POOH for log. RD drift assembly, MU memory Logging assembly, GR /CCL /Caliper /Spinners /Temp /Press, 1.69" x 20.76' OAL. PT & RIH and begin logging passes 3/19/2013 »job in progress« ASRC TEST UNIT 1. CTU Acid FCO &Test 8 Hr. STBY for CTU * ** Continued on WSR 3/19/2013 3/20/2013 * ** ASRC Test Unit ** *Continued from WSR 3/19/13 * ** CTU Acid FCO & Test 8 Hr- Standby for 3/20/2013 CTU, Standby for well support** *Continue to WSR 2/21/13 * ** • • Daily Report of Well Operations ADL0028262 T /I /0= 1025/1272/25, Temp =ST Load IA for CTU (Pre SIT) Pumped bbls meth followed by 190 bbls of crude to load IA. Pumped 2 bbls of diesel cap to freeze protect hardline 3/20/2013 SV,WV,SSV,AL =Shut/ MV,IA,OA =Open. FWHP's= 1790/969/13. CTU -8 w/ 1.5" coil, drift to td contingent mill scale memory GR /CCL /STP. make 40,60,80 fpm logging passes, perform stop counts and pull jewelry log pass from 10823'ctm to 8800'ctm, pooh. POP off, check data. Tools had plugging w /smoo, Main spinner OK, 3 stop counts OK, called Pad Engr, will modify Acid schedule for 2nd stg of job. FP flow line & Tbg w /Meth. RDMOL. 3/20/2013 « <1st Stage of Job Completed »> ASRC Test Unit #1 ***Continued from WSR 3/20/13 * ** CTU Acid 1-00 & Test 8 Hr Well Test * ** Inlet Z -03, Outlet Z -01, Standby for Well Support, Rig Up, PT ** *Continue to WSR 3/21/2013 2/22/13 * ** CTU -8 w/ 1.5" coil, Job Scope: Mud acid stimulation w/ wax bead diversion. Rig up. Function test BOP's. MU BHA; 1.5' ctc, two stingers, jsn. (oal= 12.3') 3/22/2013 * *job continued on WSR 03- 23 -13 ** ASNC Test Unit. Inlet Z -03 OuflefZ -01 ** *Continued from WSR 3/21/13 * ** CTU Acid FCO 3/22/2013 & Test 8 Hr Well Test * ** Standby CTU ** *Continue to WSR 2/23/13 * ** Continued from WSR 03- 22 -13, CTU 8 w/ 1.5" CT. Scope; Mud Acid Stimulation. Finish pressure test. PJSM with Acid pump crew. * RIH w/ 1.5" ctc, two stingers, JSN with large port. Pump initial NH4CL sweep. Pump 1st stage Acid 23 bbls of 12% HCL and 23 bbls of 9:1 Mud Acid followed by 34 bbls of 3% NH4CL +F -103. Swap to Wax beads. At 4 bbls into diversion, beads locked up in coif. By -pass micro motion and pressure to 4500 psi and pushed beads to nozzle, locked up at nozzle. Park at 9800' and held circ pressure up until beads melted. Phone APE, decision was made to continue without wax beads. Come online with NH4CL down coil. Pump 2nd stage 12% HCL and 9:1 Mud Acid. 3/23/2013 * *job continued on WSR 03- 24 -13 ** ASRC Test Unit. Inlet Z -03 Outlet Z -01 ** *Continued from WSR 3/22/13 * ** CTU Acid FCO 3/23/2013 & Test 8 Hr Well Test * ** Assist CTU ** *Continued on WSR 3/24/13 * ** Continued from WSR 03- 23 -13, CTU 8 w/ 1.5" CT. Scope; Mud Acid Stimulation. Continue RIH w/ 1.5" BHA with large ports. Swap to NH4CL after 2nd Acid stage. recip across perfs.pumped 3rd acid stage while recip across perfs.Overflush with 68 bbls of 3% NH4CL. pooh. FP well with 30 bbls of 60/40 meth. RDMO 3/24/2013 * *job complete ** FLUIDS PUMPED BBLS 5 DIESEL 100 1%KCL W /SL & SLK 247 60/40 METH 3 METH 190 CRUDE 68 12% HCL 520 NH4CL 44 9:1 MUD ACID 1177 TOTAL Casing / Tubing Attachment ADLOO28262 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 91.5# H -40 33 113 33 113 1490 470 LINER 271 3- 3/16" 6.2# L -80 9440 9711 8465.31 8715.29 PRODUCTION 9290 7" 26# L -80 30 9469 30 8346.1 7240 5410 SURFACE 3072 9 -5/8" 40# L -80 32 3104 32 3079.94 5750 3090 TUBING 9440 4 -1/2" 12.6# 13Cr80 29 9469 29 8494.17 8430 7500 LINER 1545 2 -3/8" 4.44# 13Cr80 9342 10887 8367.89 8999.92 • • • Packers and SSV's Attachment ADL0028262 SW Name Type MD TVD Depscription Z -03A PACKER 9294 8236.69 4 -1/2" Baker S -3 Perm Packer Z -03A PACKER 9310 8252.47 4 -1/2" BOT Perm Packer TIC = CRN • SA TES: WELL ANGLE> 70° @ 10811' "" 4- ` WELLHEAD= FMC Z-03A 112 "C ROME TUBING 8.2- 318 " CHROME LNR (DEPTHS ACTUATOR= BAKER C ARE ELMO) r GAP BETWEEN OVERSHOT @ 9505' & 143. ELEV = 83.75' ( I LW @ 9508' *** BF.1 = 54.05' KOP = ° 2573' • • 2101' — I9 -5/8" TYPE H ES CEMENTER Max Angle = _ 88 .' 10149' Datum ND= 10050' I 2240' 41!2" F ES X MP, D = 3.813" Datum TV D = 8800' SS GAS LFT MANDRELS 20" CONDUCTOR, 91.5#, H-40, D = 19.124" H 110' , ST MD I VI) DEV TY FE VLV LATCH PORT DATE 9 3264 3225 28 KBG2 -1R DOME BK 16 11/29/12 9 -5l8' CSG, 40#, L -80 ETC, D = 8.835" H 3104' 8 4213 4020 33 KBG2-1R MN BK 0 05/30/08 7 5577 5168 34 KBG2 -1R DOME BK 16 11/29112 Minimum ID = 1.920" ( 9316' 6 6396 5843 33 KBG2 -1R DMY BK 0 11/28/12 2 -3/8" PUP JOINT lig 5 7217 6531 33 KBG2 -1R DOME BK 16 11/29/12 4 7830 70.44 34 KBG2 -1R DMY BK 0 05/30/08 3 8440 7558 32 KBG2 -1R DOME BK 16 11/29/12 7" MARKER JON —I 7392' 2 8886 7936 28 KBG2-1R OW BK 0 05/30/08 1 9205 8233 13 KBG2 -1R SO BK 20 02/09/13 I 9273' H4- 1 /2 "HESX NIP, D =3.813" 9294' --17" X 4 -1 /2" BKR S-3 PKR, D = 3.875" - I 9310' H41/2" BOT KB LIP, D = 2.370' o on ESTIMATED TOP OF CB ENT N —9320 IIMEIII H2-7/8 SPACER PUP JONT, D = 1.920" I TUBING PUNCH 03/01/10 9320' - 9325' •=• IM 9318' j--14-1 /2" FiES X NP, ID = 3.813" (BERND CT LNR) I ( 1 9 --•1 H •. • • g∎ i►•ii ►�.. � •� 9342' H3-1/2* BTT DEPLOY SLV , D = 3.00" . i ∎i i ■ •-•- 4 9393'!8' j--1 3 -1/2" X 2 -3/8" STL XO PN, D= 1.9T I •.• • � • ► ❖i ∎ ► ••■ ,•• I TOP OF VVHPSTOCK I- 9479' % � / 3.80" M LLOUT WINDOW (Z -03A) 9469 ' - 9477' I4 -1/2" HES EZDRLL PKR (03/01/10) I— 9482' :•4 l 'AAA ••••� •• v 4- 112" TBG, 12.6#, 13CR VAM TOP, — 9495' ,•i- � t ••• • • i e e • • •1 • •i 0152 bpf, , D = 3.958" ∎ •• ∎ • ■ • • 1 ` �•••••��• •,� ••••• y, ` ••••1 , ,r �•••••�•� 7" CSG, 26#, L -80 BUTT -M, .0383 bpf, D = 6.276" 1-1 9700' ` PERFORATION SUMMARY .. ` REF LOG: SWS MGR/ CCL ON 03/25/10 %WA W A ANGLE AT TOP PEE 73° @ 9967 ` Note: Refer to Production OB for historical perf data SCE SFF INTERVAL Opn /Sqz DATE SQZ 1.56" 6 9967 - 10227 0 03/26/10 . 1.56" 6 10255 - 10475 0 03/26/10 P3TD —I 10859' �.•., • 1.56" 6 10525 - 10570 O 03/26/10 1.56" 6 10592 - 10702 O 03/26/10 1.56" 6 10735 - 10780 0 03/26/10 I2 -3/8" LNR, 4.44#, 13CR-80 STL, .0039 bpf, D = 1.992' (--I 10887' 1.56" 6 10800 - 10810 O 03/26/10 1.56" 6 10833 - 10853 O 03/26/10 DATE REV BY CONTENTS DATE REV BY COMMENTS I FRUDHOE BAY UNIT 09/28/97 JLM ORIGINAL COMPLETION 10/25/12 RCT /JMD GLV C/O & SET XX FtUG (10/10/12) VVELL Z -03A 06/02/08 N3S RWO 01/12/13 SLFVSV GLV CIO & PULL PLUG (11/30/12) PERMIT No: '100100 03/27/10 NORDIC 2 CTD SIDTRACK (Z -03A) 02/11 /13 G.F /JMD GLV 0/0 (02/09/13) API No: 50-029-22787-01 04/05/10 SLATY PJC RNAL DRLG CORRECTIONS SEC 19, T11 N, R12E, 976' FM_ & 1427' FWL 06/02/11 JLJ! PJC GLV C/O (05/20/11) 10/03/12 MSS/JMD GLV 00 (10/01/12) BP Exploration (Alaska) DATA SUBMITTAL COMPLIANCE REPORT 11/10/2010 Permit to Drill 2100100 Well Name /No. PRUDHOE BAY UNIT Z -03A Operator BP EXPLORATION (ALASKA) INC API No. 50- 029 - 22787 -01 -00 MD 10887 TVD 9000 Completion Date 3/27/2010 Completion Status 1 -OIL Current Status 1 -OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, RES, GR / CCL (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH/ Type Med /Frmt Number Name S Med N o Start Stop CH Received Comments ED C Lis 19692 Gamma Ray 9038 10856 Case 5/24/2010 Memory Corellation Log, LIS Veri, GR, CCL pt LIS Verification 8867 10887 Open 7/6/2010 LIS Veri, GR, ROP, RAD, RPS, RPD, RAS D C Lis 19819 ttfiduction /Resistivity 8867 10887 Open 7/6/2010 LIS Veri, GR, ROP, RAD, RPS, RPD, RAS og Induction /Resistivity 25 Blu 9476 10887 Open 716/2010 MD MPR, GR Log Gamma Ray 25 Blu 9476 10887 Open 7/6/2010 MD GR g See Notes 5 Col 8860 10890 Open 7/6/2010 Depth Shift Monitor Plot C Directional Survey 9466 10887 Open apt Directional Survey _ 9466 10887 Open Well Cores /Samples Information: . Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 11/10/2010 Permit to Drill 2100100 Well Name /No. PRUDHOE BAY UNIT Z -03A Operator BP EXPLORATION (ALASKA) INC API No. 50- 029 - 22787 -01 -00 MD 10887 TVD 9000 Completion Date 3/27/2010 Completion Status 1 -0I1- Current Status 1 -OIL UIC N ADDITIONAL INFORMATION Well Cored? Y 46 Daily History Received? 6/N Chips Received? Y Formation Tops N Analysis `TThT Received? — Comments: Compliance Reviewed By: _ Date: INTEQ Log & Data Transmittal Form To: State of Alaska -AOGCC 333 W. 7 Ave. Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: Z -03A Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 color print — GR Directional Measured Depth Log (to follow) 1 color print — MPR/Directional Measured Depth Log (to follow) i LAC Job #: 3073707 y 2M Jim oa Sent by: Holly Vann Date: 06/29/2 u V Received by: Date: Ij (s L 2 0 c I; AIM 9 a CM QWA. OMNaskm PLEASE ACKNOWLEDGE RECEIPT BY SIGNING MMURNING OR FAXING YOUR COPY FAX: (907) 267 -6623 _ Baker Hughes INTEQ W� /11 7260 Homer Drive BAKM Anchorage, Alaska 99518 Nuoffn Direct: (907) 267 -6612 INTEQ FAX: (907) 267 -6623 BAKER HUCWMES Balser Atlas PRINT DISTRIBUTION LIST COMPANY BP EXPLORATION (ALASKA) INC COUNTY NOR '1H SLOPE BOROUGH WELL NAME Z -03A STATE ALASKA FIELD PRUDHOE BAY UNIT DATE 6/28/2010 THIS DISTRIBUTION LIST AUTHORIZED BY HOLLY VANN SO #: 3073707 Copies of Copies Digital Copies of Copies Digital Each Log of Film Data Each Log of Film Data 2 Company BP EXPLORATION (ALASKA) INC I Company DNR - DIVISION OF OIL & GAS Person PETROTECHNICAL DATA CENTER Person CORAZON MANAOIS Address LR2 -1 Address 550 WEST 7TH AVE 900 E BENSON BLVD. SUITE 800 ANCHORAGE, AK 99508 ANCHORAGE. AK 99501 1 Company EXXON MOBIL PRODUCTION CO Company Person FILE ROOM Person Address 800 BELL STREET Address EMB GSC 3082A HOUSTON, TX 77002 1 Company STATE OF ALASKA - AOGCC Company Person CHRISTINE MAHNKEN Person Address 333 W. 7TH AVE Address SUITE 100 ANCHORAGE, AK 99501 Company Company Person Person Address Address Company Company Person Person Address Address Data Disseminated By: BAKER ATLAS -PDC 17015 Aldine Westfield Houston Texas 77073 This Distribution List Completed BX �� Page 1 of l 1 11%- MAY �y \J {\ y 05/24/10 MA1 l9 fR? ScwMherg NO. 5520 Alaska Data & Consulting Services Ab s t o O N t - U, Off $$ 0"t Company: State of Alaska 2525 Gambell Street, suite 408 �,� Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job If Log Description Date SL Color CD H-25 BCRD -00017 PRODUCTION PROFILE 05/09/10 1 1 B-1 3A BBSK -00018 1BE—i—licl GRAVEL PAC1 BG PUNCWMP T 5!06!10 1 1 D -27A BCRD -00021 LDL 05/12/10 1 1 H-1 7A BAUJ -00020 MEM PRODUCTION PROFILE — 04!10 1 1 F -12 AVYO -00069 PRODUCTION PROFILE 05/03/10 1 1 07-32" BBUO -00016 SCMT — 05104110 1 1 Z -03A BD88 -00006 CH EDIT PD R EM O ELATI 03/25!10 7 F -23A BBSK -00007 02117110 1 1 C-1 3A AVYO -00060 AST — 4 02/16/10 I 1 I 1 E -33B AWJI -00078 MCNL 03125110 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 4 i I RECEIVE " STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APR 2 2 2010 WELL COMPLETION OR RECOMPLETION REPORT AME M . GM- r -o mff "" On 1a. Well Status: ® Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 ® Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other No. of Completions One ❑ Service ❑ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aband.: 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 3/27/2010 210 -010 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 3/18/2010 50 029 - 22787 - 01 - 00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 3/23/2010 PBU Z -03A 976' FNL, 1427' FWL, SEC. 19, T11 N, R1 2E, UM 8. KB (ft above MSL): 83 15. Field / Pool(s): Top of Productive Horizon: 3920' FNL, 3816' FWL, SEC. 19, T11 N, R1 2E, UM GL (ft above MSQ: 54.05' Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD +TVD): Oil Pool 4345' FNL, 3342' FWL, SEC. 19, T11 N, R12E, UM 10859' 8993' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD +TVD): 16. Property Designation: Surface: x 599151 y 5959100 Zone ASP4 10887' 9000' ADL 028262 TPI: x 601578 y 5956188 Zone ASP4 11. SSSV Depth (MD +TVD): 17. Land Use Permit: Total Depth: x- 601110 Y - 5955756 Zone- ASP4 None 18. Directional Survey: ® Yes ❑ No 19. Water depth, if offshore: 20. Thickness of Permafrost (TVD): Submit electronic and printed information per 20 AAC 25.050 N/A ft MSL 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re- Drill/Lateral Top Window MD/TVD: MW D, GR, RES, GR / CCL 9469' 8494' 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 91. H -40 Surfa ce Surface 30" Arctic Set 4 12-1/4" 7 7" 26# L -80 30' 4 94' 8-1/2" 446 sx I 'G' 3 -3/16" 6.2# 9440' 1 9711' 4-1/8" Uncemented Liner 4 24. Open to production or injection? ® Yes ❑ No 25. TUBING RECORD If Yes, list each interval open SIZE DEPTH SET MD PACKER SET MD / TVD (MD +TVD of Top & Bottom; Perforation Size and Number): 1.56" Gun Diameter, 6 spf 4 -1/2 ", 12.6#, 13Cr 9469' 9294'/ 8320' MD TVD MD TVD 9967'-10227' 8868'- 8896' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 10255'- 10475' 8899'- 8917' 10525'- 10570' 8923'- 8929' DEPTH INTERVAL (MD ) AMOUNT AND KIND OF MATERIAL USED 10592 10702' 8932' 8949' 2600' Freeze Protected w/ 45 Bbls of Diesel 10735'- 10780' 8955' - 8968' 10800'- 10810' 8975' - 8979' 10833'- 10853' 8986'- 8991' 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): April 10, 2010 Gas Lift Date of Test: Hours Tested: Production For OIL -BBL: GAS -MCF: WATER -BBL: CHOKE SIZE: GAs-OIL RATIO: 4/11/2010 6 Test Period 838 2,240 -0- 176 2,673 Flow Tubing Casing Press: Calculated OIL -BBL: GAS -MCF: WATER -BBL: OIL GRAVITY -API (CORR): Press. 400 780 24 -Hour Rate ♦ 3,351 8,958 -0- 25 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes ® No Sidewall Core(s) Acquired? ❑ Yes ® No If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results r , 71. None r " 8F1E,p R8DMS APR 2 3 Form 10-407 Revised 12/2009 CON UED ON REVERSE /0 bmit Original Only u •Z9 �-- I G � T,�,/d 9 i 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well Tested? ❑ Yes ® No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Sag River 9699' 8706' None Shublik 9731' 8731' Eileen 9870' 8826' Sadlerochit / Zone 4 9953' 8864' Formation at Total Depth (Name): Sadlerochit / Zone 4 9953' 8864' 31. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 32. 1 hereby certify that the foregoing i true and correct to the best of my knowledge. Signed: Terrie Hubble dum§ Title: Drilling Technologist Date: PBU Z -03A 210 -010 Prepared ByNam&Wumber. Terrie Hubble, 564 -4628 Well Number Permit No. / Approval No. Drilling Engineer: Sean McLaughlin, 564 -4387 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: 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. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50 -029- 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 Submit Original Only BP EXPLORATION Page 1 of 15 Operations Summary Report Legal Well Name: Z -03 Common Well Name: Z -03 Spud Date: 9/1/1997 Event Name: REENTER +COMPLETE Start: 3/10/2010 End: 3/27/2010 Contractor Name: NORDIC CALISTA Rig Release: 3/27/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 3/13/2010 23:00 - 00:00 1.00 RIGID P PRE MOVE RIG OFF OF MPF PAD. 3/14/2010 00:00 - 20:35 20.58 RIGID P PRE MOVE RIG FROM MPL PAD TO SPINE ROAD. MOVE RIG FROM SPINE ROAD TO Z PAD ACCESS ROAD. MOVE RIG DOWN Z PAD ACCESS ROAD & ONTO THE BACKSIDE OF Z PAD. 20:35 - 20:37 0.03 RIGD P PRE ARRIVE ON THE BACKSIDE OF Z PAD. 20:37 - 00:00 3.38 RIGD P PRE LID HERCULITE LINER. RU OA HOSE FOR GAUGE READINGS. RU T -MATS. DISCOVER THAT WE CAN "T SPOT STRAIGHT ON WELL AS WE LOSE THE ABILITY TO LOWER THE REEL TO THE GROUND DUE TO ELECTRICAL BOXES & WALKWAY IN FRONT OF THE RIG. DISCUSS WITH PAD OP & GET APPROVAL & REMOVE LARGE SNOW BERM NEXT TO WALK WAY TO GAIN MORE PAD ACCESS. 3/15/2010 00:00 - 01:00 1.00 RIGU P PRE CONTINUE TO CLEAN SNOW FOR MORE ACCESS IN FRONT OF THE RIG RIG. 01:00 - 03:45 2.75 RIGU P PRE -37F AMBIENT, TAKE FREQUENT WARM UP BREAKS. ATTEMPT TO MOVE RIG OVER WELL. ISSUES ARE: CLOSE PROXIMITY TO ADJACENT WELL & RIG STAIR CASE, SPOTTING AT A ANGLE & T -MAT PLACEMENT & REQUIRED ACCESS FOR REEL SWAP. READJUST T -MATS. SPOT OVER WELL. SPOT CUTTINGS BOX. 03:45 - 06:00 2.25 RIGU P PRE RD ADAPTOR FLANGE. RD CHOKE HOSE. PLACE 2X6'S UNDER CELLAR BOX BEAM. SET RIG DOWN AGAIN. 06:00 - 12:00 6.00 RIGU P PRE ACCEPT RIG AT 06:00 AM. SPOT SECONDARY EQUIPMENT. INSTALL CHOKE HOSE. STAB BOPE. 12:00 - 17:30 5.50 RIGU P PRE ND TREE CAP & NU BOPE. RU THE MPD LOOP. CLEAN PITS OF WELDING AND GLUING DEBRIS. 17:30 - 18:00 0.50 RIGU P PRE CREW CHANGE OUT & PERFORM WALK ABOUNDS. 18:00 - 20:00 2.00 RIGU P PRE C/O BOP RAMS FOR BIG TOOLS - 20:00 - 21:00 1.00 BOPSUF P PRE FILL STACK WITH WATER. 21:00 - 00:00 3.00 BOPSUF P PRE PERFORM BI- WEEKLY BOPE TEST PER AOGCC BEGS, 250 /PSI /3500PS1. LOU GRIMALDI WAIVED WITNESS TO TEST. 3/16/2010 00:00 - 02:30 2.50 BOPSUF P PRE CONTINUE TO TEST BOPE PER AOGCC BEGS, 250PSI /3500PSI - PASS. LOU GRIMALDI WAIVED WITNESS TO TEST. 02:30 - 02:45 0.25 BOPSU P PRE PJSM REGARDING RU & PULLING BPV. 02:45 - 04:15 1.50 BOPSUF P PRE RU BPV LUBRICATOR. PRESSURE TEST 250PSI /500PSI. PULL BPV. RD BPV LUBRICATOR. ISSUES WITH THE SSV OVER STROKING OPEN, BLEED DOWN SSVP & CLOSE SSV SLIGHTLY. -25PSI WHP. 04:15 - 08:00 3.75 BOPSUF P PRE PRESSURE TEST MPD LOOP, 250PSI /3500PSI. 08:00 - 08:20 0.33 BOPSUF P PRE BLOW DOWN BOPE. 08:20 - 08:40 0.33 BOPSUF P PRE PJSM TO SLIP AND CUT DRILL LINE. 08:40 - 10:45 2.08 BOPSUF P PRE SLIP AND CUT DRILL LINE. 10:45 -11:00 0.25 BOPSUF P PRE PJSM TO PU INJECTOR AND PUMP SLACK. 11:00 -13:00 2.00 BOPSU P PRE CIRC COIL TO WATER. PRESS TEST SWIVEL TO 4300 PSI, PRESS TEST PACK OFF PER AOGCC BEGS 250PSI /3500PSI - PASS. Printed: 4/12/2010 1:12:56 PM BP EXPLORATION Page 2 of 15 Operations Summary Report Legal Well Name: Z -03 Common Well Name: Z -03 Spud Date: 9/1/1997 Event Name: REENTER +COMPLETE Start: 3/10/2010 End: 3/27/2010 Contractor Name: NORDIC CALISTA Rig Release: 3/27/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 3/16/2010 13:00 - 13:45 0.75 STWHIP P WEXIT PUMP SLACK. GOOD E -LINE MOVEMENT. BLOW BACK END OF COIL WITH AIR. 13:45 -14:00 0.25 STWHIP P WEXIT SAFETY MEETING. REVIEW PROCEDURE, HAZARDS AND MITIGATION FOR CUTTING COIL. 14:00 - 14:45 0.75 STWHIP P WEXIT CUT OFF 300' OF COIL. 14:45 - 16:30 1.75 STWHIP P WEXIT M/U CTC AND PULL TEST WITH 30K. M/U UQC AND TEST E -LINE. 16:30 - 18:30 2.00 STWHIP N SFAL WEXIT REPAIR GUN LINE IN RIG PITS. 18:30 - 19:45 1.25 STWHIP P WEXIT FILL COIL & PRESSURE TEST CTC TO 4000PSI - GOOD. PLACE INJECTOR OVER BUNG HOLE & SWAP REEL TO GEOVIS - PUMP FORWARD TO COMPLETE SLACK MANAGEMENT. OPEN WELL - DEAD & FLOW CHECK FOR 15 MIN WHILE COMPLETING PJSM FOR PU BHA. PREP FLOOR VALVE. SUCK DOWN MPD LOOP. 19:45 - 20:00 0.25 STWHIP P WEXIT PJSM REGARDING MU MILLING BHA. 20:00 - 20:50 0.83 STWHIP P WEXIT MU WINDOW MILLING BHA, MILLS ARE 3.80 ". PU 5'_ LUBERICATOR FOR PRESSURE UNDEPLOYMENT. SET BHA IN 3" SLIPS & STRIP OVER WELL, OPEN 3" SLIPS & GET TAG UP MEASUREMENT FOR PRESSURE UNDEPLOYMENT. 20:50 - 23:00 2.17 STWHIP P WEXIT RIH WITH WINDOW MILLING BHA. 23:00 - 23:50 0.83 STWHIP P WEXIT LOG DOWN FOR TIE -IN FROM 8932'. MINUS 45' CORRECTION. 23:50 - 00:00 0.17 STWHIP P WEXIT RIH. 3/17/2010 00:00 - 00:10 0.17 STWHIP P WEXIT RIH & DRY TAG AT 9468'. 00:10 - 06:00 5.83 STWHIP P WEXIT MILL HS WINDOW FROM FIRST MW AT 9467.07' WHILE SWAPPING WELL TO NEW GEO -VIS. PUMP 1.95BPM/2230PS1 (REDUCE RAPE DUE TO POSSIBLE BACKLASH WITH MOTOR TORQUE & 1 -1/2" MT CONNECTION) W/ 50 -150 PSI DIFF, 1 -2.5K WOB W/ 9.69 ECD PVT 337. TIME MILL 0.1' EVERY 6 MIN. MIX 14 50LB SACKS OF RESINEX INTO MUD SYSTEM. ESTABLISH MILLING PATTERN. BLED DOWN IA FROM 25OPSI to 10PSI. MILLED TO 9473'. 06:00 - 11:00 5.00 STWHIP P WEXIT MILL 3.80" HIGHSIDE WINDOW THRU 4 -1/2" AND 7" CASING. 1.9 BPM, 2600 FREE SPIN, 2700 -2800 PSI, 2 -3K WOB, 1/2 FPH, 9.7 ECD, NO STALLS. MILLED TO 9474'. 11:00 -14:00 3.00 STWHIP P WEXIT MILL 3.80" HIGHSIDE WINDOW THRU 4 -1/2" AND 7" CASING. 1.9 BPM, 2700 FREE SPIN, 2800 -3000 PSI, 3K WOB, 10 DEG INCL, 9.8 ECD, NO STALLS. MILLED TO 9475'. 14:00 - 17:00 3.00 STWHIP P WEXIT MILL. 1.9 BPM, 2700 FREE SPIN, 2900 -3000 PSI, 3.5K WOB, 10 DEG INCL, 9.8 ECD, MILLED TO 9476'. 17:00 - 19:00 2.00 STWHIP P WEXIT MILL. 1.9 BPM, 2700 FREE SPIN, 2900 -3000 PSI, 3.5K WOB, 10 DEG INCL, 9.8 ECD, MILLED TO 9476.4 19:00 - 00:00 5.00 STWHIP P WEXIT MILL. 1.84 BPM, 2830 FREE SPIN, 2900 -3000 PSI, 3 -3.9K WOB, 10 DEG INCL, 9.83 ECD, APPEARS TO HAVE EXITED THE 7" AT 9477.3'. HOLD 630PSI WHP - 11.18PPG ECD. MILLED TO MIDNIGHT DEPTH OF 9477.6' Printed: 4/12/2010 1:12:56 PM BP EXPLORATION Page 3 of 15 Operations Summary Report Legal Well Name: Z -03 Common Well Name: Z -03 Spud Date: 9/1/1997 Event Name: REENTER +COMPLETE Start: 3/10/2010 End: 3/27/2010 Contractor Name: NORDIC CALISTA Rig Release: 3/27/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 3/18/2010 00:00 - 00:25 0.42 STWHIP P WEXIT CONTINUE TO MILL FROM 9477.6' USING 1.84 BPM, 2830 FREE SPIN, 3400 -3500 PSI, 3 -3.5K WOB, 10 DEG INCL, 11.17 ECD MILL TO 9478' 00:25 - 03:35 3.17 STWHIP P WEXIT MILL 10' OF RAT HOLE FROM 9478' TO 9488'. BOTTOMS UP SAMPLE REVIELS 5 -10% KINGAK. 03:35 - 04:45 1.17 STWHIP P WEXIT BACKREAM & REAM WINDOW THREE TIMES. HOLDING 11 PPG ECD, DRY FRIFT WINDOW - SMOOTH. 04:45 - 06:15 1.50 STWHIP P WEXIT POH FOLLOWING PRESSURE SCHEDULE. HOLD 900 PSI AT SURFACE FOR 11 # ECD. 06:15 - 06:30 0.25 STWHIP P WEXIT SAFETY MEETING. REVIEW PROCEDURE, HAZARDS AND MITIGATION FOR PRESSURE UNDEPLOYMENT OF MILLING BHA. 06:30 - 09:30 3.00 STWHIP P WEXIT PRESSURE UNDEPLOY 3.80" COILTRAK / BAKER MILLING BHA. WINDOW MILL GAUGED AT 3.79" NO -GO. GOOD CONDITION. 09:30 - 10:00 0.50 DRILL P PROD1 SAFETY MEETING. REVIEW PROCEDURE, HAZARDS AND MITIGATION FOR PRESSURE DEPLOYMENT OF COILTRAK DRILLING BHA. 10:00 - 13:00 3.00 DRILL P PROD1 PRESSURE DEPLOY COILTRAK DRILLING BHA WITH 1.2 DEG MOTOR AND USED HYC RAZOR EDGE BC BIT #1. HOLD 900 PSI WHP. BHA CAL = 69.11'. TEST COILTRAK TOOLS. 13:00 - 14:45 1.75 DRILL P PROD1 RIH WITH COILTRAK DRILLING BHA. FOLLOW 11# ECD PRESSURE SCHEDULE. 14:45 -15:10 0.42 DRILL P PROD1 LOG GR TIE -IN. -35' CORRECTION. 15:10 -15:20 0.17 DRILL P PROD1 RIH, RIH CLEAN THRU HS WINDOW. TAG BOTTOM AT 9489'. 15:20 - 17:30 2.17 DRILL P PROD1 DRILL KINGAK SHALE BUILD SECTION. HOLD 470 PSI WHP. 2.4 BPM, 3900 PSI FREE SPIN, 3900 -4200 PSI, 4K WOB, 10 -20 FPH, 1 OR TF, 11 ECD, DRILLED TO 9530'. 17:30 - 22:15 4.75 DRILL P PROD1 DRILL KINGAK SHALE BUILD SECTION. HOLD 470 PSI WHP. 2.4 BPM, 3900 FREE SPIN, 3900 -4200 PSI, 4K WOB, 10 FPH, 11 ECD. PVT 320 DRILL TO 9562'. 22:15 - 22:25 0.17 DRILL P PROD1 WIPER TO THE WINDOW & TO TD - CLEAN. PVT 318 22:25 - 00:00 1.58 DRILL P PROD1 DRILL KINGAK SHALE BUILD SECTION. HOLD 470 PSI WHP. 2.47 BPM, 4170 FREE SPIN, 4200 -4300 PSI, 4 -5K WOB, 5 -10 FPH, 11 ECD. PVT 318 DRILL TO MIDNIGHT DEPTH OF 9576'. 3/19/2010 00:00 - 05:00 5.00 DRILL P PROD1 CONTINUE TO DRILL KINGAK SHALE BUILD SECTION FROM 9576'. HOLDING 470 PSI WHP. 2.47 BPM, 4170 FREE SPIN, 4200 -4300 PSI, 4 -5K WOB, 5 -8 FPH, 10.9 ECD. DRILL TO 9611'. PVT 312 05:00 - 08:30 3.50 DRILL P PROD1 DRILL KINGAK SHALE, HOLDING 470 PSI WHP FOR 11 PPG ECD 2.5 BPM, 4150 FREE SPIN, 4200 -4500 PSI, 4K WOB, HS TF, Printed: 4/12/2010 1:12:56 PM BP EXPLORATION Page 4 of 15 Operations Summary Report Legal Well Name: Z -03 Common Well Name: Z -03 Spud Date: 9/1/1997 Event Name: REENTER +COMPLETE Start: 3/10/2010 End: 3/27/2010 Contractor Name: NORDIC CALISTA Rig Release: 3/27/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From -To Hours Task Code NPT Phase Description of Operations 3/19/2010 05:00 - 08:30 3.50 DRILL P PROD1 25 DEG INCL, 8 FPH, DRILLED TO 9640'. 08:30 - 10:00 1.50 DRILL P PROD1 DRILL KINGAK SHALE, HOLDING 470 PSI WHP FOR 11 PPG ECD 2.5 BPM, 4200 FREE SPIN, 4200 -4500 PSI, 4K WOB, HS TF, 25 DEG INCL, 8 FPH, DRILLED TO 9650'. 10:00 - 10:20 0.33 DRILL P PROD1 WIPER TO WINDOW, CLEAN HOLE. 10:20 -11:00 0.67 DRILL P PROD1 LOG TIE -IN OF RA TAG TO MOTHER WELLBORE. ADD 1 FT. LOG PAST RA TAG. RA TAG = 9477.5'. TOP OF WINDOW = 9469' BOTTOM OF WINDOW = 9479' 11:00 - 11:20 0.33 DRILL P PROD1 RIH CLEAN THRU WINDOW AND TO BOTTOM. 11:20 -13:30 2.17 DRILL P PROD1 DRILL KINGAK SHALE, HOLDING 470 PSI WHP FOR 11 PPG ECD 2.4 BPM, 3900 PSI FREE SPIN, 4000 -4300 PSI, 4 -5K WOB, 20R TF, 30 DEG INCL, 10 FPH, DRILLED TO 9670'. 13:30 -16:15 2.75 DRILL P PROD1 DRILL KINGAK SHALE, HOLDING 470 PSI WHP FOR 11 PPG ECD 2.4 BPM, 3900 PSI FREE SPIN, 4000 -4300 PSI, 4 -5K WOB, 8 FPH DRILLED TO 9690'. 16:15 -18:00 1.75 DRILL P PROD1 DRILL KINGAK SHALE, HOLDING 470 PSI WHP FOR 11 PPG ECD 2.4 BPM, 4200 -4300 PSI, 40R TF, 33 DEG INCL, 4 -5K WOB, 11 ECD, DRILLED TO 9709'. TVD = 8630'. 18:00 -18:45 0.75 DRILL P PROD1 CIRC BOTTOMS UP AND CONFIRM SAG RIVER CUTTINGS. POH SLOW AT 5 FPM WHILE CIRC BOTTOMS UP. BOTTOM'S UP REVIELED SAG RIVER. 18:45 -18:55 0.17 DRILL P PROD1 LOG FOR TIE -IN FROM 9500' ACROSS RA TAG WITH REDUCED PUMP RATE., PLUS 1.5' CORRECTION. 18:55 - 19:05 0.17 DRILL P PROD1 RIH & TAG BOTTOM AT 9711'. 0 6•r 3 /�c �h' 19:05 - 19:10 0.08 DRILL P PROD1 WIPER TO WINDOW - CLEAN. 19:10 - 20:05 0.92 DRILL P PROD1 PULL THROUGH WINDOW - CLEAN. OPEN EDC & CIRCULATE WELL TO 11 PPG BRINE. SLOWLY PUH. 20:05 - 21:55 1.83 DRILL P PROD1 POH & LAY IN THE REST OF THE 11 PPG BRINE. PJSM REGARDING MU LINER WHILE POH. 21:55 - 22:20 0.42 DRILL P PROD1 FLOW CHECK. 22:20 - 22:35 0.25 DRILL P PROD1 POP OFF WELL. LD 5' LUBRICATOR. BLOW DOWN BHI TOOLS. LD BHI TOOLS. LD MOTOR & BIT. BIT WAS 1 -1 WITH 1 PLUGGED JET ON THE NOSE. 22:35 - 22:50 0.25 CASE P LNR1 P REP FLOOR TO RUN LINER. 22:50 - 23:05 0.25 CASE P LNR1 PJSM REGARDING MU LINER. 23:05 - 00:00 0.92 CASE P LNR1 MU ALUMINUM BULL NOSE + 8 JTS OF 3- 3/16" TCII LINER + 3- 3/16" PJ + XO + LINER HANGER, BAKER LOC ALL CONNECTIONS. 3/20/2010 00:00 - 01:15 1.25 CASE P LNR1 CONTINUE TO MU 3- 3/16" LINER. MU BHI COIL TRAC TOOLS TO SETTING TOOL WITH 1/2" BALL ON SEAT. PU INJECTOR & STAB ONTO WELL. POWER UP & TEST TOOLS. OPEN EDC. Printed: 4/12/2010 1:12:56 PM BP EXPLORATION Page 5 of 15 Operations Summary Report Legal Well Name: Z -03 Common Well Name: Z -03 Spud Date: 9/1/1997 Event Name: REENTER +COMPLETE Start: 3/10/2010 End: 3/27/2010 Contractor Name: NORDIC CALISTA Rig Release: 3/27/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From -To Hours Task Code NPT Phase Description of Operations 3/20/2010 01:15 - 03:35 2.33 CASE P LNR1 RIH, CIRC MIN RATE THRU EDC. 03:35 - 04:00 0.42 CASE P LNR1 LOG DOWN FOR TIE -IN FROM 9260', MINUS 38' CORRECTION. 04:00 - 04:30 0.50 CASE P LNR1 RIH. WT CK AT 9400'= 32K, 18K RIW. NO SET DOWNS. WT CK AT 9700'= 35K, 17K RIW. TAG BOTTOM AT 9709.5'. LINER LANDED AT TD. CLOSE EDC. SET HANGER PER PROCEDURE. APPEARS TO BE SET. TOP OF 3- 3/16" DRILL LINER AT 9440'. 2.786" ID IN XO BELOW HANGER. 04:30 - 06:15 1.75 CASE P LNR1 POH WITH LINER RUNNING BHA. 06:15 - 06:30 0.25 CASE P LNR1 SAFETY MEETING. REVIEW PROCEDURE, HAZARDS AND MITIGATION FOR LAYING OUT BHA AND CHANGING TWO BOP RAMS FOR SMALL TOOLS. 06:30 - 07:30 1.00 CASE P LNR1 LAY OUT COILTRAK AND BAKER RUNNING TOOLS. ALL LOOKS GOOD. 07:30 - 11:45 4.25 BOPSUF P LNR1 CHANGE OUT BOP RAMS FOR 2 -3/8" LINER AND 2" COIL P RESSURE / FUNCTION TEST 2" COMBI AND 2 -3/8" COMBI R AMS. SEND PRESSURE TEST REPORT TO AOGCC. 11:45 -12:00 0.25 DRILL P LNR1 SAFETY MEETING. REVIEW PROCEDURE, HAZARDS AND MITIGATION FOR LAYING DOWN LUBRICATOR FOR MPD. 12:00 - 13:00 1.00 DRILL P LNR1 LAY OUT LUBRICATOR USED FOR MPD. 13:00 - 15:00 2.00 DRILL P LNR1 MAKE UP 2 -3/8" BHI UQC. TEST E -LINE. M/U 2.74" DIAMOND MILL, STRING MILL, MOTOR, 1 JT CSH, UP /DWN JARS, COILTRAK AND CTC. BHA OAL = 76.79'. 15:00 -17:30 2.50 DRILL N SFAL LNR1 NOT ABLE TO MAKE UP 7" OTIS QUICK CONNECTON ON LUBRICATOR BELOW INJECTOR, THREADS WERE DAMAGED. CHANGE OUT LUBRICATOR. PRESSURE TEST LUBRICATOR. 17:30 - 19:50 2.33 DRILL P LNR1 RIH WITH 2.74" MILLING BHA. DRY TAG ALUMINUM SHOE AT 9746'. CORRECT TO 9710.5' 19:50 - 21:00 1.17 DRILL P LNR1 MILL ALUMINUM SHOE WHILE SWAPPING HOLE TO NEW 8.8PPG GEO -VIS. USING 1.5BPM /3000PS1 FS, 0.5 -1K WOB. MILL - 5' OF RAT HOLE. GOOD INDICATION OF ALUMINUM OVER THE SHAKER. 21:00 - 21:20 0.33 DRILL P LNR1 BACKREAM & REAM SHOE AREA - CLEAN. 21:20 - 23:00 1.67 DRILL P LNR1 POH. PJSM REGARDING LD MILLING BHA. 23:00 - 23:30 0.50 DRILL P LNR1 TAG UP. FLOW CHECK. POP OFF. BLOW DOWN & LD MILLING BHA. BOTH MILLS WERE 2.73" GO. 23:30 - 00:00 0.50 DRILL P LNR1 DIAL UP MOTOR TO 1.3 AKO, SCRIBE SAME & MU T -REX BICENTER BIT, LOC -TITE SAME. SIMULTANEOUSLY CLEAN OUT POSSUM BELLY, SHAKER, REMOVE & INSPECT SCREENS. CLEAN OUT REEL FILTER SCREEN - ALMOST PLUGGED - 50OPSI DIFFERENTIAL. 3/21/2010 00:00 - 00:30 0.50 DRILL P PROD1 MU LATERAL BHA. STAB ONTO WELL WITH INJECTOR. POWER UP & TEST TOOLS. SET COUNTERS. 00:30 - 02:10 1.67 DRILL P PROD1 RIH WITH LATERAL BHA, CIRC THRU BIT AT MIN RATE. 02:10 - 02:20 0.17 DRILL P PROD1 LOG DOWN FOR TIE -IN FROM 9530' ACROSS RA TAG, MINUS 37.5'. 02:20 - 02:30 0.17 DRILL P PROD1 RIH & TAG BOTTOM AT 9716'. 02:30 - 03:20 0.83 DRILL P PROD1 DRILL FROM 9716' 1.8/3135/30R W/ 100 -300 PSI DIFF, 1 -2.4K WOB W/ 9.86 ECD AT 37 DEG AT 8589' TVD AT Printed: 4/12/2010 1:12:56 PM f BP EXPLORATION Page 6 of 15 Operations Summary Report Legal Well Name: Z -03 Common Well Name: Z -03 Spud Date: 9/1/1997 Event Name: REENTER +COMPLETE Start: 3/10/2010 End: 3/27/2010 Contractor Name: NORDIC CALISTA Rig Release: 3/27/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From -To Hours Task Code NPT Phase Description of Operations 3/21/2010 02:30 - 03:20 0.83 DRILL P PROD1 20- 50' /HR. PVT 408 DRILL TO 9730'& A STALL - BASE OF THE SAG RIVER. 03:20 - 04:55 1.58 DRILL P PROD1 100% LOSSES AT 9730'. DRILL FROM 9730' 1.5/2500/358 W/ 50 -75 PSI DIFF, 2.4 -3.5K WOB W/ 9.00 ECD AT 38 DEG AT 8589' TVD AT 10- 15' /HR. PVT 408 DRILL TO A STALL AT 9754'. PVT 273 04:55 - 06:00 1.08 DRILL P PROD1 LOSSES INSTANTANEOUSLY CURED TO 37% LOSS RATE & IMPROVING. DRILL FROM 9754' 1.51N/2500PS1/1.27OUT/20R W/ 50-75 PSI DIFF, 2.4 -3.5K WOB W/ 9.76 ECD AT 40 DEG AT 10- 157HR. PVT 260 DRILL TO 9771'. PVT 242. 06:00 - 07:45 1.75 DRILL P PROD1 CONTINUE TO DRILL FROM 9771' 1.51N/2500PSI/1.30UT/25R W/ 50 -75 PSI DIFF, 1.0 -2.5K WOB W/ 9.86 ECD AT 41 DEG AT 10- 207HR. PVT 242 FLUID LOSS AT 70 %. 1.5 IN / 0.5 OUT. STAKING WT, VERY SLOW ROP DRILL TO 9797'. 07:45 - 08:00 0.25 DRILL P PROD1 WIPER TO SHOE AT 9711'. 31K UP WT, CLEAN HOLE. 08:00 - 09:15 1.25 DRILL P PROD1 DRILL, STACKING WT, 1.7 BPM, 3050 PSI FREE SPIN, 3100 PSI, .6 BPM RETURNS, 2.5K WOB, 9.7 ECD, HS TF, 3 FPH. DRILLED TO 9802'. 09:15 -11:30 2.25 DRILL P PROD1 POH TO CHECK BIT. FULL RETURNS WHILE POH. 11:30 -11:45 0.25 DRILL P PROD1 SAFETY MEETING. REVIEW PROCEDURE, HAZARDS AND MITIGATION FOR LAY OUT BHA AND CUTTING COIL. 11:45 -14:30 2.75 DRILL P PROD1 LAY OUT BHA. BIT HAD ONE PLUGGED PORT ON PILOT, (1,1,1) CUT 100' COIL FOR CHROME MANAGEMENT. M/U CTC AND PULL TEST. M/U UQC AND TEST E -LINE. PRESSURE TEST CTC AND UQC. 14:30 - 14:45 0.25 DRILL P PROD1 SAFETY MEETING. REVIEW PROCEDURE, HAZARDS AND MITIGATION FOR M/U DRILLING BHA. 14:45 - 15:15 0.50 DRILL P PROD1 M/U COILTRAK / RES LATERAL DRILLING BHA #6 WITH 1.7 DEG MOTOR AND RE -CON HCC BC BIT. BHA CAL = 68.09'. 15:15 - 17:00 1.75 DRILL P PROD1 RIH WITH DRILLING BHA #6. CIRC 0.4 BPM, 1300 PSI. 17:00 - 17:20 0.33 DRILL P PROD1 LOG TIE -IN AT RA TAG. -37.5' CORRECTION. 17:20 - 17:30 0.17 DRILL P PROD1 RIH CLEAN TO BOTTOM. TAG AT 9802'. 17:30 - 23:15 5.75 DRILL P PROD1 DRILL SHUBLIK BPM, 1.1 BPM RETURNS, 3000 PSI FREE SPIN, 3100 -3300 PSI, 10 RTF, 2.5 -3K WOB, PVT 230. DRILL TO 9860'& BEGIN HAVING 90% LOSSES. DRILL TO 9888'. PVT 141 23:15 - 23:20 0.08 DRILL P PROD1 50' WIPER - CLEAN. 23:20 - 23:30 0.17 DRILL P PROD1 DRILL, 1.5 BPM, 0.25 BPM RETURNS, 2750 PSI FREE SPIN, 50 -75 PSI MW, 10 RTF, 2.5 -3K WOB, PVT 120. DRILL TO 9891' WITH 50' ROP & THEN STACKS OUT. 23:30 - 00:00 0.50 DRILL P PROD1 STACKING ISSUES & IT APPEARS THAT THE CUTTINGS ARE STRUNG OUT IN THE HOLE. GETTING LOW ON GEO -VIS. Printed: 4/12/2010 1:12:56 PM 0 it BP EXPLORATION Page 7 of 15 Operations Summary Report Legal Well Name: Z -03 Common Well Name: Z -03 Spud Date: 9/1/1997 Event Name: REENTER +COMPLETE Start: 3/10/2010 End: 3/27/2010 Contractor Name: NORDIC CALISTA Rig Release: 3/27/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From -To Hours Task Code NPT Phase Description of Operations 3/21/2010 23:30 - 00:00 0.50 DRILL P PROD1 SLOWLY PUH, PUMP MIN RATE & LET CUTTINGS FALL DOWN HOLE. SHUFFLE TRUCKS & SWAP COIL TO 2% KCL. 3/22/2010 00:00 - 00:15 0.25 DRILL P PROD1 RIH WHILE SWAPPING COIL TO KCL. 00:15 - 04:50 4.58 DRILL P PROD1 WITH THE CHOKE CLOSED & PUMPING 2% KCL, DRILL IN EILEEN FORMATION FROM 9891 ',1.5 BPM, 0 BPM RETURNS, 2467 PSI FREE SPIN, 10 -35 PSI MW, 30 RTF, 2.5 -4K WOB. OCCASIONALLY CHECK RETURNS - 0.2- 0.35BPM. DRILL TO 9994' 04:50 - 05:10 0.33 DRILL P PROD1 PERFORM 150' WIPER - 34.5K PUW, 18K RIW - SEEMS FINE. 05:10 - 07:00 1.83 DRILL P PROD1 WITH THE CHOKE CLOSED & PUMPING 2% KCL, CONTINUE TO DRILL IN EILEEN FORMATION FROM 9994', 1.6 BPM, 0 BPM RETURNS, 2150 PSI FREE SPIN, 100 -150 PSI MW, 35 RTF, 1.5 -4K WOB. OCCASIONALLY CHECK RETURNS - 0.2- 0.35BPM. ATTEMPT TO PUMP DOWN BACKSIDE. DRILLED TO 10050 07:00 - 07:20 0.33 DRILL P PROD1 DRILL LATERAL IN Z4 WITH KCL AND CLOSED CHOKE. 30 PSI WHP 1.5 BPM, 2500 PSI FREE SPIN, 2600 -2700 PSI, 70R TF, 1.8 K WOB, 50 -100 FPH, DRILLED TO 10100'. 07:20 - 08:20 1.00 DRILL P PROD1 WIPER TRIP, 36K UP WT. CLEAN PICKUP, OVERPULL AT 9730'. CLEAN UP LOSS AREA, WIPER UP TO 9300'. RIH CLEAN TO BOTTOM. 08:20 - 09:20 1.00 DRILL P PROD1 DRILL LATERAL IN Z4 WITH KCL AND CLOSED CHOKE. 80 PSI WHP 1.6 BPM, 2550 FREE SPIN, 2700 -2900 PSI, 90 R TF, 2.5K WOB, 150 FPH, 88 DEG INCL, DRILLED TO 10200'. 09:20 - 09:30 0.17 DRILL P PROD1 WIPER TO WINDOW. 09:30 - 09:45 0.25 DRILL P PROD1 LOG GR TIE -IN AT RA TAG. ADD 4'. 09:45 - 10:00 0.25 DRILL P PROD1 RIH CLEAN TO BOTTOM. 10:00 - 12:00 2.00 DRILL P PROD1 DRILL LATERAL IN Z4 WITH KCL AND CLOSED CHOKE. 50 PSI WHP 1.7 BPM, 2500 PSI FREE SPIN, 2600 -2900 PSI, 10OR TF, 2 -3K WOB, 150 FPH, 85 DEG INCL, 9.3 ECD, DRILLED TO 10300'. 12:00 - 12:50 0.83 DRILL P PROD1 WIPER TO SHOE. CLEAN HOLE. RIH CLEAN TO BOTTOM. 12:50 -15:10 2.33 DRILL P PROD1 DRILL LATERAL IN Z4 WITH KCL AND CLOSED CHOKE. 20 PSI WHP 1.6 BPM, 3000 FREE SPIN, 3100 -3300 PSI, 90 R TF, 85 DEG INCL, DRILLED TO 10400'. 15:10 - 17:00 1.83 DRILL P PROD1 WIPER TO 9200', CLEAN HOLE. BULLHEAD 20 BBL GEOVIS DOWN BACKSIDE OF COIL. RIH, SAT DOWN IN SHALE AT 10270'. WORK THRU IT. RIH TO BOTTOM. 17:00 -18:15 1.25 DRILL P PROD1 DRILL LATERAL IN Z4 WITH KCL AND CLOS CHOKE. 90 PSI WHP. 1.6 BPM, 2500 FREE SPIN, 2700 -2900 PSI, 10OR TF, 3K Printed: 4/12/2010 1:12:56 PM 0 0 BP EXPLORATION Page 8 of 15 Operations Summary Report Legal Well Name: Z -03 Common Well Name: Z -03 Spud Date: 9/1/1997 Event Name: REENTER +COMPLETE Start: 3/10/2010 End: 3/27/2010 Contractor Name: NORDIC CALISTA Rig Release: 3/27/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From -To Hours Task Code NPT Phase Description of Operations 3/22/2010 17:00 - 18:15 1.25 DRILL P PROD1 WOB, DRILL TO 10,495 18:15 - 19:30 1.25 DRILL P PROD1 WIPER TO 9200', MULTIPLE OP'S, MOSTLY 10,280' & 9790'. WHP VARIES FROM 300 -90PSI BULLHEAD 20 BBL GEOVIS DOWN BACKSIDE OF COIL. RIH, SAT DOWN IN SHALE AT 10,000 & 10270'. REDUCE PUMP RATE TO GET THRU. RIH TO BOTTOM. 19:30 - 21:50 2.33 DRILL P PROD1 DRILL LATERAL IN Z4 FROM 10,495' WITH KCL AND CLOSED CHOKE. 200 -90 PSI WHP. 1.74 BPM, 2900 FREE SPIN, 3000 -3400 PSI, 10OR TF, 1 -3K WOB, DRILL TO 10,600' 21:50 - 22:30 0.67 DRILL P PROD1 WIPER TO 9711' (SHOE), OP'S AT 10,290' & 9810', OTHERWISE CLEAN, 33K PUW. 22:30 - 22:35 0.08 DRILL P PROD1 PUH TO 9500'. 22:35 - 22:50 0.25 DRILL P PROD1 LOG DOWN FOR TIE -IN FROM 9500', PLUS 2.5'. 22:50 - 23:15 0.42 DRILL P PROD1 WIPER TO BOTTOM. SET DOWNS AT 10,000', GOT THRU WITH REDUCED PUMP RATE. 23:15 - 00:00 0.75 DRILL P PROD1 DRILL LATERAL IN Z4 FROM 10,600' WITH KCL AND CLOSED CHOKE. 200 -90 PSI WHP. 1.70 BPM, 2500 FREE SPIN, 2600 -3000 PSI, 90R TF, 1.5 -3.5K WOB, DRILL TO MIDNIGHT DEPTH OF 10688'. 3/23/2010 00:00 - 00:15 0.25 DRILL P PROD1 CONTINUE TO DRILL LATERAL IN Z4 WITH KCL AND CLOSED CHOKE. 200 -90 PSI WHP. FROM 10,688' 1.70 BPM, 2500 FREE SPIN, 2600 -3000 PSI, 90R TF, 1.5 -3.5K WOB, DRILL TO MIDNIGHT DEPTH OF 10,700'. 00:15 - 01:00 0.75 DRILL P PROD1 WIPER TO 9711' (SHOE), OP'S AT 10,290',9900 & 9810', OTHERWISE CLEAN, 33K PUW. 01:00 - 02:55 1.92 DRILL P PROD1 DRILL LATERAL IN Z4 FROM 10,700' WITH KCL AND CLOSED CHOKE. 190 -90 PSI WHP. 1.80 BPM, 3300 FREE SPIN, 3400 -3600 PSI, 90 -10OR TF, 1.5 -3.5K WOB, DRILL TO 10,800'. 02:55 - 04:15 1.33 DRILL P PROD1 WIPER TO 9711' (SHOE), OP'S AT 10,290',9900 & 9810', OTHERWISE CLEAN, 33K PUW. 04:15 - 05:45 1.50 DRILL P PROD1 DRILL LATERAL IN Z4 FROM 10,800' WITH KCL AND CLOSED CHOKE. 120 -40 PSI WHP. 1.72 BPM, 3150 FREE SPIN, 3300 -3500 PSI, 90 -10OR TF, 1 -3K WOB, DRILL TO 10,888'. 05:45 - 07:15 1.50 DRILL P PROD1 GEO WIPER. SLOWLY PUH WHILE GEO LOOKS AT DRILLING LOGS. GEO CALLED TD AT 10,888' TO PREVENT DRILLING INTO 41 N SHALE. CONTINUE LONG WIPER TO 9100' TO ENSURE 4 -1/2" TUBING IS CLEAN OF CUTTINGS. 07:15 - 07:40 0.42 DRILL P PROD1 LOG GR TIE -IN AT RA TAG. ADDED 6.5'. 07:40 - 10:30 2.83 DRILL P PROD1 RIH AND REAM SHALES AT 9950, 10250 AND 10500'. GOT RETURNS FOR THE FIRST TIME WHILE REAMING SHALES. CIRC GEOVIS WITH 80% RETURNS, CIRC BOTTOMS UP. Printed: 4/12/2010 1:12:56 PM BP EXPLORATION Page 9 of 15 Operations Summary Report Legal Well Name: Z -03 Common Well Name: Z -03 Spud Date: 9/1/1997 Event Name: REENTER +COMPLETE Start: 3/10/2010 End: 3/27/2010 Contractor Name: NORDIC CALISTA Rig Release: 3/27/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From -To Hours Task Code NPT Phase Description of Operations 3/23/2010 07:40 - 10:30 2.83 DRILL P PROD1 1.5 BPM / 1.2 BPM RETURNS. DID SEE CUTTINGS ON SHAKER WITH BOTTOMS UP. CIRC UNTIL CLEAN. 10:30 - 12:00 1.50 DRILL P PROD1 REAM SHALES AT 10250 AND 10500' WITH GEOVIS. 1.6 BPM, 1.2 RETURNS. RIH AND TAGGED FINAL TD AT 10,887'. T DWN WT = 16K, UP WT = 34K. CIRC NEW GEOVIS LINER PILL TO BIT WHILE REAMING NEAR TD. 12:00 - 13:00 1.00 DRILL P PROD1 POH WHILE LAYING IN NEW 40 BBL GEOVIS LINER PILL 1.6 BPM / 1.3 BPM RETURNS. PULL ABOVE LINER SHOE. OPEN EDC. 13:00 - 14:45 1.75 DRILL P PROD1 POH. FLAG COIL AT 8000' EOP. POH WHILE CIRC 2.7 BPM WITH 2.0 BPM RETURNS. 14:45 -15:00 0.25 DRILL P PROD1 SAFETY MEETING. REVIEW PROCEDURE, HAZARDS AND MITIGATION FOR UO BHA AND PUMP OUT SLACK. 15:00 - 16:00 1.00 DRILL P PROD1 LAY OUT COILTRAK DRILLING BHA. BIT GRADED AT 4,2,1. REMOVE UQC AND CTC. M/U BAKER CTC AND PULL TEST WITH 30K. FUNCTION TEST BOPE - GOOD. 16:00 - 18:45 2.75 CASE P RUNPRD PUMP OUT E -LINE SLACK. CUT OFF 280' OF E -LINE. CAP E -LINE. CIRC 3/4" STEEL BALL. CIRC 34.5 BBL. BALL LANDED. RECOVER BALL. PRESSURE TEST BAKER CTC. 18:45 - 19:05 0.33 CASE P RUNPRD PREP RIG FLOOR TO RUN 2 -3/8" LINER. 19:05 -19:35 0.50 CASE P RUNPRD SAFETY MEETING. REVIEW PROCEDURE, HAZARDS AND MITIGATION FOR RUNNING 2 -3/8" LINER WITH INNER 1" CSH CEMENTING STRING. 19:35 - 21:30 1.92 CASE P RUNPRD MU 49 JTS 2 -3/8" STL CHROME LINER, FILL AT 50 %. 21:30 - 22:10 0.67 CASE P RUNPRD PREP RIG FLOOR TO RUN 1" CSH. 22:10 - 22:30 0.33 CASE P RUNPRD PJSM RE: MU 1" CSH INNER STRING. 22:30 - 00:00 1.50 CASE P RUNPRD MU 1" CSH INNER STRING. IAP = 0 PSI OAP = 20 PSI CONTINUED ON DIMS REPORT 03/23/10 3/24/2010 00:00 - 00:55 0.92 CASE P RUNPRD CONTINUED FROM DIMS REPORT 03/23/10. IAP = 0 PSI. OAP = 20 PSI. CONTINUE MAKING UP 1" CSH. NO -GO W/ CSH. SPACE OUT LEAVING 17.04' OF STINGER STUNG IN. FILL ANNULAR VOID BETWEEN INNER STRING AND LINER AND TEST TO 500 PSI TO ENSURE STINGER IS STUNG IN AND SEALING - GOOD. 00:55 - 01:25 0.50 CASE P RUNPRD MU BAKER LINER RUNNING TOOLS. 01:25 - 02:15 0.83 CASE P RUNPRD MU 181.93' OF 2- 1/16" CSH. 02:15 - 02:50 0.58 CASE P RUNPRD PU INJECTOR. MU TO LINER. 02:50 - 05:15 2.42 CASE P RUNPRD FILL HOLE. RIH W/ LINER CIRCULATING AT MINIMUM RATE. TO TAL LENGTH OF BHA AND LINER IS 1736.94'. AT 04:40 - RIH AT 75 FPM AT 8550' MD PUMPING AT 0.26 BPM. RETURNS ARE -0.35 BPM - LOSING -35% RETURNS. Printed: 4/12/2010 1:12:56 PM BP EXPLORATION Page 10 of 15 Operations Summary Report Legal Well Name: Z -03 Common Well Name: Z -03 Spud Date: 9/1/1997 Event Name: REENTER +COMPLETE Start: 3/10/2010 End: 3/27/2010 Contractor Name: NORDIC CALISTA Rig Release: 3/27/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From -To Hours Task Code NPT Phase Description of Operations 3/24/2010 02:50 - 05:15 2.42 CASE P RUNPRD AT 05:00 - WEIGHT CHECK PRIOR TO EXITING WINDOW. UP WEIGHT 36K CLEAN WHILE PUMPING AT 0.26 BPM. RIH TO FLAG. RECORD (BUT DID NOT CORRECT) DEPTH AT FLAG. OFF OF MECHANICAL COUNTER, CORRECTION WOULD BE -31'. CONTINUE RIH. RIH CLEAN TO BOTTOM. 05:15 - 05:45 0.50 CASE P RUNPRD TAG BOTTOM AT 10915' M D THREE TIMES (TAG IS HARD AND CONSISTENT). PU CLEAN EACH TIME OFF BOTTOM AT 40K LB WHILE PUMPING AT 0.3 BPM. STILL LOSING -35% RETURNS. PRE TASK MEETING REGARDING DROPPING BALL. LINER SHOE AT TD AT 10,887'. PBTD IS AT 10858'. TOP OF LINER 3.70" DEPLOYMENT SLEEVE IN 4 -1/2" TAILPIPE AT 9342'. 05:45 - 09:30 3.75 CASE P RUNPRD LAUNCH 5/8" STEEL BALL. BALL ON SEAT AT 27.5 BBLS. SHEARED AT 4100 PSI. PICK UP FREE FROM LINER AT 31K UP WT. STACK 1 O DOWN. CIRC WELL TO SLICK KCL WATER. ORDERED SWS CEMENT PUMPERS. 1.6 BPM, 1.0 BPM RETURNS WITH GEOVIS IN HOLE. 3600 PSI. WITH SLICK KCL AROUND, CIRC. 1.4 BPM WITH 1.2 BPM RETURNS. 2800 PSI. SWAP RIG PITS OVER TO KCL WATER. CIRC TOTAL OF 435 BBLS KCL WHILE SWAPPING AND GETTING READY TO CEMENT. 09:30 -11:15 1.75 CEMT P RUNPRD PO AND RIG UP SWS CEMENTING EQUIPMENT. 11:15 -11:30 0.25 CEMT P RUNPRD SAFETY MEETING. REVIEW PROCEDURE, HAZARDS AND MITIGATION FOR PUMPING LINER CEMENT JOB WITH SWS. 11:30 -12:10 0.67 CEMT P RUNPRD BATCH MIX CEMENT. CEMENT AT WT AT 1200 HRS. PUMP 5 BBL KCL WATER TO WARM CEMENT LINE. PRESS TEST CMT LINE WITH 4000 PSI. 12:10 -13:25 1.25 CEMT P RUNPRD STG 8 BBL KCL WATER, 1.1 BPM, 1700 PSI STG 14 BBL, 15.8 PPG G CEMENT WITH 35% SILICA FOR HIGH TEMP. 5 BBL CMT, 1.2 BPM, 1.0 BPM RETURNS, 2300 PSI, 15.9 PPG 10 BBL CMT, 1.2 BPM, 1.0 BPM RETURNS, 2800 PSI, 15.9 PPG 14 BBL CMT, STOP PUMP. ISOLATE COIL FROM SWS. SEND BIOZAN TO CEMENT VAN, VAC CMT LINE. ZERO IN AND OUT TOTALIZERS STG BIOZAN DISPLACEMENT, 37.6 BBL DISPL TO LEAVE 2 BBL CMT IN COIL. 10 BBL DISPL, 1.4 BPM, 2800 PSI, 1.2 BPM RETURNS 20 BBL DISPL, 1.4 BPM, 2650 PSI, 1.3 BPM RETURNS 25.7 BBL DISPL, CEMENT AT SHOE, ZERO OUT TOTAL 30 BBL DISPL, 1.0 BPM, 3800 PSI, 0.7 BPM RETURNS 32 BBL DISPL, 0.5 BPM, 1300 PSI, 0.3 BPM RETURNS 34 BBL DISPL, 0.4 BPM, 1500 PSI, 0.1 BPM RETURNS 36 BBL DISPL, 0.3 BPM, 1400 PSI, NO RETURNS, 37.6 BBL, 0.4 BPM, 1440 PSI, 0.1 BPM RETURNS, STOP Printed: 4/12/2010 1:12:56 PM BP EXPLORATION Page 11 of 15 Operations Summary Report Legal Well Name: Z -03 Common Well Name: Z -03 Spud Date: 9/1/1997 Event Name: REENTER +COMPLETE Start: 3/10/2010 End: 3/27/2010 Contractor Name: NORDIC CALISTA Rig Release: 3/27/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From -To Hours Task Code NPT Phase Description of Operations 3/24/2010 12:10 - 13:25 1.25 CEMT P RUNPRD PUMP. 2 BBL UNDER DISPLACED. 6.4 BBL CEMENT RET URNED UP BA CKSID E OF LINER. 13:25 - 14:20 0.92 CEMT P RUNPRD PICKUP CLEAN, 34K UP WT. PICK UP TO 10830'. CIRC BIOZAN 1.6 BPM, 2800 PSI, JET BACK IN, LIGHT TAG AT FLAPPER VALVE. POH 50 FPM, CIRC 1.4 BPM, 1.2 BPM RETURNS. CIRC AT TOP OF LINE FULL RETURNS, 1.4 BPM IN / OUT. _ 1950 PSI. y 14:20 -15:45 1.42 CEMT P RUNPRD POH, CIRC 1.6 BPM, 2100 PSI. CIRC AT SURFACE, 1.6 BPM, FULL RETURNS. 15:45 -16:00 0.25 CEMT P RUNPRD SAFETY MEETING. REVIEW PROCEDURE, HAZARDS AND MITIGATION FOR LAYING OUT LINER RUNNING TOOLS AND INNER STRING. 16:00 - 18:00 2.00 CEMT P RUNPRD LAY OUT 6 JTS, 2- 1/16" CSH AND BAKER LINER TOOLS. RECOVERED 5/8" STEEL BALL. STANDBACK 24 STDS 1" CSH INNER STRING. LAY OUT STINGER. 18:00 - 19:00 1.00 CEMT P RUNPRD LOWER OUT BOT TOOLS. 19:00 - 20:10 1.17 CEMT P RUNPRD PJSM. CUT AND REBOOT WIRE. MU SWIZZLE ASSEMBLY. STAB ON. 20:10 - 20:30 0.33 CEMT P RUNPRD JET STACK W/ SWIZZLE ASSEMBLY. FLUSH ALL LEGS OF CHOKE MANIFOLD AND REEL HOUSE IRON. 20:30 - 21:00 0.50 CEMT P RUNPRD PJSM. LD SWIZZLE ASSEMBLY. PU BOT CLEANOUT BHA (1- 11/16" MOTOR AND 1.875" PARABOLIC DIAMOND SPEED MILL). 21:00 - 22:00 1.00 CEMT P RUNPRD RIH W/ 27 STANDS 1" CSH. 22:00 - 22:30 0.50 CEMT P RUNPRD PU 2 JTS 2- 1/16" CSH. STAB ON INJECTOR. GET FAX FROM SLB LAB: CEMENT HAS REACHED 600 PSI COMPRESSIVE STRENGTH. 22:30 - 00:00 1.50 CEMT P RUNPRD RIH W/ CLEANOUT ASSEMBLY. WEIGHT CHECK AT 9250' MD - 29K CLEAN. RIH WEIGHT 19200 LB. CIRCULATING AT 0.25 BPM AT 300 PSI CIRCULATING PRESSURE. RETURNS 1:1. IAP = 0 PSI OAP = 20 PSI CONTINUED ON DIMS REPORT 03/25/10. 3/25/2010 00:00 - 01:00 1.00 CEMT P RUNPRD CONTINUED FROM DIMS REPORT 03/24/10 IAP = 0 PSI OAP = 20 PSI CONTINUE RIH W/ CLEANOUT ASSEMBLY. CIRCULATING AT 0.75 BPM AT 1000 PSI W/ FULL RETURNS. RIH THROUGH LINER TOP CLEAN. INCREASE RATE TO 1.1 BPM AT 1830 PSI FREESPIN. 01:00 - 01:15 0.25 CEMT P RUNPRD RIH TO PBTD W/ NO WEIGHT BOBBLES (LINER CLEAN). TAG PBTD AT 10891' (UNCORRECTED), STALL MOTOR. PU CLEAN AT 32K LB. 01:15 - 03:30 2.25 CEMT P RUNPRD PULL TO SURFACE CIRCULATING AT 1.1 BPM AT 1890 PSI. RETURNS 1:1. RECIPROCATE ACROSS LINER TOP DEPTH AS POOH CIRCULATING. 03:30 - 03:45 0.25 CEMT P RUNPRD PJSM FOR STANDING BACK CSH AND LD CLEANOUT ASSEMBLY. 03:45 - 06:00 2.25 CEMT P RUNPRD UNSTAB. STAND BACK 2- 1/16" CSH AND 1" CSH. LD Printed: 4/12/2010 1:12:56 PM • 0 BP EXPLORATION Page 12 of 15 Operations Summary Report Legal Well Name: Z -03 Common Well Name: Z -03 Spud Date: 9/1/1997 Event Name: REENTER +COMPLETE Start: 3/10/2010 End: 3/27/2010 Contractor Name: NORDIC CALISTA Rig Release: 3/27/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From -To Hours Task Code NPT Phase Description of Operations 3/25/2010 03:45 - 06:00 2.25 CEMT P RUNPRD CLEANOUT ASSEMBLY. 06:00 - 06:30 0.50 EVAL P LOWERI SAFETY MEETING. REVIEW PROCEDURE, HAZARDS AND MITIGATION FOR M/U SWS MEMORY LOGGING BHA AND RUN 27 STDS OF 1" CSH WORKSTRING. 06:30 - 08:30 2.00 EVAL P LOWERI M/U SWS MEMORY GR / CCL LOGGING TOOLS, 27 STD OF 1" CSH WORKSTRING AND 2 JTS OF 2- 1/16" CSH AND CTC. BHA OAL = 1749.4'. 08:30 - 13:00 4.50 EVAL P LOWERI RIH WITH SWS MEMOR LO GGING GR / CCL BHA. CIRC 0.4 BPM, 250 PSI. �! RIH PAST TOP OF LINER CLEAN. RIH AND TAG PBTD AT 10893' UNCORRECTED. 10,858' CORRECTED. 13:00 - 13:45 0.75 EVAL P LOWERI LOG UP to 9100' AT 45 FPM WHILE LAYING IN FLOPRO PERF PILL. 13:45 -15:00 1.25 EVAL P LOWERI POH WITH MEMORY LOGGING BHA. 15:00 - 15:15 0.25 EVAL P LOWERI SAFETY MEETING. REVIEW PROCEDURE, HAZARDS AND MITIGATION FOR STANDING BACK CSH AND LAYING OUT LOGGING TOOLS. 15:15 -17:15 2.00 EVAL P LOWERI STAND BACK 27 STDS OF 1" CSH AND LAY OUT LOGGING TOOLS. 17:15 -18:00 0.75 EVAL P LOWERI PRESSURE TEST LINER LAP WITH 2000 PSI. CHART TEST. F AILED TEST. PRESS BLED OFF FROM 800 PSI TO 200 PSI IN 2 MIN. 18:00 - 20:30 2.50 EVAL P LOWERI CREW CHANGE. PJSM. LOAD PERF GUNS. PREP GUNS. PREP FLOOR FOR RUNNING GUNS. SLT MEETING. REVIEW LOG W/ SLB MEMORY. CORRECTION OF ( -32'). FIND PBTD AT 10860.6' MD. 20:30 - 20:45 0.25 EVAL P LOWERI PJSM FOR PU PERF GUNS. 20:45 - 23:00 2.25 EVAL P LOWERI PU PERF GUNS. SEND ELECTRONIC COPY OF TIE -IN LOG TO TOWN GEO FOR REVIEW AS PER REQUEST. TOWN GEO VERBALLY APPROVES PREVIOUSLY AGREED UPON PERF PICKS. 23:00 - 23:10 0.17 EVAL P LOWERI PJSM FOR MU CSH. 23:10 - 23:50 0.67 EVAL P LOWERI MU 1" CSH. MU 2- 1/16" CSH. MU INJECTOR AND STAB ON. 23:50 - 00:00 0.17 EVAL P LOWERI RIH W/ PERF GUN ASSEMBLY. IAP = 0 PSI OAP = 20 PSI CONTINUED ON DIMS REPORT 03/26/10 3/26/2010 00:00 - 02:05 2.08 PERFOB P LOWERI CONTINUED FROM DIMS REPORT 03/25/10 IAP = 0 PSI OAP = 20 PSI CONTINUE RIH W/ PERFORATING ASSEMBLY. CIRCULATING AT 0.34 BPM AT 305 PSI W/ FULL RETURNS. 02:05 - 03:00 0.92 PERFOB P LOWERI TAG PBTD AT 10890.3' CTMD. PU CLEAN AT 33K AT 10886' CTMD WHILE PUMPING 0.33 BPM AT 300 PSI W/ FULL RETURNS. RBIH AT 19300' RIH WEIGHT, REPEAT TAG NOT PUMPING W/ SAME RESULTS. PARK Printed: 4/12/2010 1:12:56 PM • BP EXPLORATION Page 13 of 15 Operations Summary Report Legal Well Name: Z -03 Common Well Name: Z -03 Spud Date: 9/1/1997 Event Name: REENTER +COMPLETE Start: 3/10/2010 End: 3/27/2010 Contractor Name: NORDIC CALISTA Rig Release: 3/27/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From -To Hours Task Code NPT Phase Description of Operations 3/26/2010 02:05 - 03:00 0.92 PERFOS P LOWERI IN TENSION AT FULL UP WEIGHT AT 10886.0' CTMD. MECHANICAL COUNTER READS 9150'. CORRECT DEPTH TO READ BOTTOM SHOT AT PBTD OF 10859.9' MD. PUH TO POSITION BOTTOM SHOT AT 10853' MD. INITIATE EFIRE FIRING SEQUENCE. DETONATE PERF GUNS ON THE FLY. GOOD INDICATION OF FIRE AT SURFACE W/ SONIC SHOT INDICATOR, PERFORATED THE FOLLOWING INTERVALS: 9967'- 10227' MD 10255'- 10475' MD 10525'- 10570' MD s 10592'- 10702' MD PGP 10735'- 10780' MD 10800'- 10810' MD 10833'- 10853' MD TOTAL PERFORATED INTERVAL = 710' SWS 1.56" 1606 PJ CHARGES, 6 SPF. PERFORATION GUNS ARE 1.56" 6 SPF 1606 PJ, 60 DEG PHASING. ENTRANCE HOLE DIAMETER 0.19 ". PENETRATION 10.7 ". PUMPING AT 0.3 BPM W/ FULL RETURNS WHEN GUNS FIRED. LOST RETURNS UPON FIRING. 03:00 - 04:45 1.75 PERFOB P LOWERI PULL TO SURFACE W/ PERFORATING ASSEMBLY. PUH CLEAN AT 33K LB. CIRCULATING AT 0.8 BPM AT 1443 PSI W/ FULL RETURNS. 04:45 - 05:00 0.25 PERFOB P LOWERI SAFETY MEETING. REVIEW PROCEDURE, HAZARDS AND MITIGATION FOR LAYING OUT 1" CSH WORKSTRING. 05:00 - 07:00 2.00 PERFOB P LOWERI LAY OUT 1" CSH WORKSTRING. 07:00 - 07:15 0.25 PERFOG P LOWERI SAFETY MEETING. REVIEW PROCEDURE, HAZARDS AND MITIGATION FOR LAYING OUT SWS 1.56" FIRED PERF GUNS AND BLANKS. 07:15 - 10:45 3.50 PERFOB P LOWERI LAY OUT SWS 1.56" PJ FIRED PERF GUNS AND BLANKS. ALL SHOTS FIRED. LOAD OUT PERF GUNS FROM PIPE SHED. 10:45 -11:00 0.25 ZONISO P RUNPRD SAFETY MEETING. REVIEW PROCEDURE, HAZARDS AND MITIGATION FOR M/U BAKER 4 -1/2" LINER TOP PACKER BHA. 11:00 -12:00 1.00 ZONISO P RUNPRD M/U BAKER 45 KB LINER TOP PACKER WITH SEAL ASSEMBLY AND 20.47' OF 2 -7/8" STL 13CR PUPJ AS A SPACER TO COVER THE TUBING PUNCH AT 9320'. BHA CAL = 101.27'. 12:00 - 14:00 2.00 ZONISO P RUNPRD RIH WITH BAKER 45 KB PACKER AND SEAL ASSEMBLY WITH 30K SHEAR RING. CIRC 0.2 BPM, 120 PSI. UP WT AT 9300'= 32K. 14:00 - 15:00 1.00 ZONISO P RUNPRD CIRC 0.5 BPM, RIH AND SAW TOP OF DEPLOYMENT SLEEVE AT 9380' UNCORRECTED. STACK 10K DOWN AT 9388.5' PICK UP, BREAKOVER AT 9381. PICK UP OUT OF SLEEVE TO 9366'. Printed: 4/12/2010 1:12:56 PM 0 BP EXPLORATION Page 14 of 15 Operations Summary Report Legal Well Name: Z -03 Common Well Name: Z -03 Spud Date: 9/1/1997 Event Name: REENTER +COMPLETE Start: 3/10/2010 End: 3/27/2010 Contractor Name: NORDIC CALISTA Rig Release: 3/27/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From To Hours Task Code NPT Phase Description of Operations 3/26/2010 14:00 - 15:00 1.00 ZONISO P RUNPRD LAUNCH 5/8" STEEL BALL. CIRC 1.5 BPM, 1000 PSI SLOW PUMP TO 0.5 BPM AT 20 BBL. BALL ON SEAT AT 27.3 BBL. OPEN BAKER CHOKE. RIH. STACK 10K AGAIN AT 9388.5' PICK UP FREE AT 9381.2'. PICK UP 1 FT TO 9380.2'. CLOSE BAKER CHOKE. PRESS 2500 PSI. STACK 10K AT 9387'. PULL TO 20K. 15:00 - 15:30 0.50 ZONISO P RUNPRD ERESSURE TEST LINER TOP PACKER WITH 2150 PSI GOOD TEST. CHART TEST. LOST 50 PSI IN 15 MIN. STACK 10K. PRESS UP TO 3700 PSI AND SHEARED. PICK UP FREE FROM LINER TOP PACKER. 31K. TOP OF 3.70" DEPLOYMENT SLEEVE FROM GR/CCL = 9338' TOP OF BAKER 45 KB LINER TOP PACKER IS AT 9310'. ID = 2.33 ". 15:30 -17:15 1.75 ZONISO P RUNPRD POH WTIH RUNNING TOOLS. CIRC 0.5 BPM, 200 PSI. 17:15 - 17:30 0.25 ZONISO P RUNPRD SAFETY MEETING. REVIEW PROCEDURE, HAZARDS AND MITIGATION FOR UO BAKER LTP RUNNING TOOLS. 17:30 - 18:00 0.50 RIGD P POST UO BAKER LTP RUNNING TOOLS. M/U NOZZLE BHA. MU INJECTOR. 18:00 - 19:30 1.50 RIGD P POST RIH W/ NOZZLE. FP WELLBORE FROM 2600' MD W/ 45 BBLS DIESEL. POOH. 19:30 - 21:00 1.50 RIGD P POST UNSTAB. PJSM W/ GREASE CREW AND BPV CREW FOR GREASING TREE AND SETTING BPV. GREASE TREE AND SET BPV. 21:00 - 23:30 2.50 RIGD P POST MU NOZZLE ASSEMBLY. PICKLE REEL. BLOWDOWN REEL W/ N2. AT - 21:15: MATERIAL RELEASE OCCURED. CH2MHILL GREASE TRUCK RELEASED MOTOR OIL INTO SECONDARY CONTAINMENT UNDER VEHICLE AND ALSO ON TO PAD. CH2MHILL NOTIFIED SPILL RESPONSE AND ESTIMATED VOLUME AT GREATER THAN ONE GALLON AND ESTIMATED EFFECTED AREA TO BE 4'X 4'. NOTIFIED PAD OPERATOR, CTD SUPERINTENDENT AND NORDIC MANAGEMENT. LEFT MESSAGE W/ DRILLING HSE ADVISOR. SRT TO COME EVALUATE TOMORROW IN AM. SRT CONTACT IS 659 -4375. 23:30 - 00:00 0.50 RIGD P POST BREAK OFF INJECTOR. REMOVE CTC. INSTALL GRAPPLE. IAP = 0 PSI OAP = 20 PSI CONTINUED FROM DIMS REPORT 03/27/10. 3/27/2010 00:00 - 01:30 1.50 RIGD P POST CONTINUED FROM DIMS REPORT 03/26/10 IAP = 0 PSI OAP = 20 PSI PULL CT ACROSS AND SECURE TO REEL. 01:30 - 01:50 0.33 RIGD P POST PJSM FOR C/O RAMS. 01:50 - 03:00 1.17 RIGD P POST REMOVE RAMS FOR ROPE. INSPECT CAVITIES. DRESS BOPE RAMS FOR BIG TOOLS. 03:00 - 03:15 0.25 RIGD P POST PJSM FOR ND BOPE AND MPD LOOP. Printed: 4/12/2010 1:12:56 PM 0 BP EXPLORATION Page 15 of 15 Operations Summary Report Legal Well Name: Z -03 Common Well Name: Z -03 Spud Date: 9/1/1997 Event Name: REENTER +COMPLETE Start: 3/10/2010 End: 3/27/2010 Contractor Name: NORDIC CALISTA Rig Release: 3/27/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From -To Hours Task Code NPT Phase Description of Operations 3/27/2010 03:15 - 08:00 4.75 RIGD P POST ND BOPE AND MPD LOOP. NU TREE CAP AND PRESS TEST. CHANGE GRIPPER BLOCKS IN INJECTER HEAD TO 2 -3/8 ". CLEAN AND INSPECT RIG PITS. 08:00 - 08:15 0.25 RIGD P POST SAFETY MEETING. REVIEW PROCEDURE, HAZARDS AND MITIGATION FOR JACKING UP RIG AND PULLING OFF THE WELL. 08:15 -10:00 1.75 RIGD P POST JACK UP RIG AND PULL OFF OF WELL. REMOVE AND STORE MPD LOOP. PICK UP HANDY BERM. CLEAN TREE AREA. RELEASED RIG AT 1000 HRS, 03/27/2010. TOTAL OF 12 DAYS AND 4 HOURS FROM RIG ACCEPT TO RELEASE. 3.5 DAYS LESS THAN PLANNED AND 1.1 MM BELOW THE AFE. ALL FURTHER NORDIC 2 INFORMATION WILL BE IN DIMS Z -16A. Printed: 4/12/2010 1:12:56 PM BAKER HUGMS iNTEQ North America - ALASKA - BP Prudhoe Bay PB Z Pad Z -03 - Slot 03 Z -03A Survey: MWD Survey Report - Geographic 24 March, 2010 RAMM Its Survey Report - Geographic by INTEQ Iw Company: North America - ALASKA - BP Local Co- ordinate Reference: Well Z -03 - Slot 03 Project: Prudhoe Bay TVD Reference: 5 : 03 9/1/1997 06:00 @ 83.75ft (Nabors 18E) Site: PB Z Pad MD Reference: 5: 03 9/1/1997 06:00 @ 83.75ft (Nabors 18E) Well: Z -03 North Reference: True Wellbore: Z -03A Survey Calculation Method: Minimum Curvature Design: Z -03A Database: EDM .16 - Anc Prod - WH24P Project Prudhoe Bay, GPB, PRUDHOE BAY Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Goo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site PB Z Pad, TR -11 -12 Site Position: Northing: 5,957,230.17ft Latitude: 70° 17'33 051 N From: Map Easting: 601,304.82 ft Longitude: 149° 10' 47.365 W Position Uncertainty: 0.00 ft Slot Radius: 0.000in Grid Convergence: 0.77 ° Well Z -03 API No 500292278700 i Well Position +N /-S 0.00 ft Northing: 5,959,099.98 ft Latitude: 70° 1 T 51.723 N +E / -W 0.00 ft Easting: 599,150.99 ft Longitude: 149° 11'49.414 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00ft Wellbore Z -03A API No 500292278701 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (nT) l BGGM2008 4/1 3/2009 22 80.86 57 ,687 Design Z -03A Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 9,466.11 Vertical Section: Depth From (TVD) +N /-S +E/ -W Direction (ft) (ft) 29.70 0.00 0.00 150.41 Survey Program Date: 3/2412010 From To (ft) (ft) ! Survey (Wellbore) Tool Name Description 155.11 9,466.11 1 MWD - Standard (Z -03) MWD MWD - Standard 9,468.90 10,887.00 MWD (Z -03A) MWD MWD - Standard I 3!24/2010 2:23:15PM Page 2 COMPASS 2003.16 Build 71 SAIER ■ s Survey Report - Geographic by INTEQ Company: North America - ALASKA - BP Local Co- ordinate Reference: Well Z -03 - Slot 03 Project: Prudhoe Bay TVD Reference: 5 : 03 9/1/1997 06:00 @ 83.75ft (Nabors 18E) Site: PB Z Pad MD Reference: 5 : 03 9/1/1997 06:00 @ 83.75ft (Nabors 18E) Well: Z -03 North Reference: True Wellbore: Z -03A Survey Calculation Method: Minimum Curvature Design: Z -03A Database: EDM .16 - Anc Prod - WH24P Survey Measured Vertical Map Map Depth Inclination Azimuth Depth +W-S +E/ -W Northing Easting (ft) V) ( °) ( ft) (ft) (ft) (ft) (ft) Latitude Longitude 9,466.11 5.66 135.49 8,491.30 2,739.44 2,202.94 5,956,390.08 601,389.68 70° 17' 24.777 N 149° 10'45.222 W TIP 9,468.90 5.67 135.31 8,494.07 - 2,739.64 2,203.13 5,956,389.89 601,389.88 70° 17'24.775 N 149° 10'45.217 W KOP 9,490.03 8.44 135.39 8,515.04 - 2,741.49 2,204.96 5,956,388.07 601,391.73 70° 17' 24.757 N 149° 10' 45.164 W 9,519.89 12.31 138.00 8,544.41 - 2,745.41 2,208.63 5,956,384.19 601,395.45 70° 17' 24.719 N 149° 10' 45.057 W' 9,554.34 17.05 143.00 8,577.72 - 2,752.18 2,214.13 5,956,377.50 601,401.04 70° 17'24.652 N 149° 10'44.896 W 9,579.84 20.84 142.47 8,601.84 - 2,758.76 2,219.14 5,956,370.98 601,406.14 70° 17'24.587 N 149° 10'44.750 W 9,600.04 24.30 138.12 8,620.49 - 2,764.71 2,224.11 5,956,365.10 601,411.18 70° 17' 24.529 N 149° 10' 44.606 W'i 9,630.18 28.25 128.75 8,647.52 - 2,773.80 2,233.82 5,956,356.14 601,421.01 70° 17' 24.439 N 149° 10' 44.323 W, 9,659.99 31.66 130.16 8,673.35 - 2,783.26 2,245.30 5,956,346.83 601,432.62 70° 17' 24.346 N 149° 10' 43.988 W 9,675.19 33.42 132.03 8,686.16 - 2,788.64 2,251.46 5,956,341.54 601,438.84 70° 17' 24.293 N 149° 10' 43.809 W 9,710.66 37.63 134.50 8,715.02 - 2,802.78 2,266.45 5,956,327.60 601,454.02 70° 17' 24.154 N 149° 10' 43.372 W' 9,731.81 39.14 134.62 8,731.60 - 2,811.99 2,275.81 5,956,318.51 601,463.49 70° 17'24.064 N 149° 10'43.100 W' 9,746.00 40.32 136.61 8,742.51 - 2,818.47 2,282.15 5,956,312.11 601,469.92 70° 17'24.000 N 149° 10'42.915 W' 2 -7/8" 9,759.53 41.48 138.41 8,752.74 - 2,825.01 2,288.13 5,956,305.66 601,475.99 70° 17' 23.936 N 149° 10' 42.741 W 9,789.95 44.29 137.89 8,775.03 - 2,840.42 2,301.94 5,956,290.43 601,490.00 70° 17'23.784 N 149° 10'42.338 W', 9,820.09 48.69 138.44 8,795.77 - 2,856.71 2,316.52 5,956,274.34 601,504.78 70° 17' 23.624 N 149° 10' 41.914 W'!. 9,850.12 52.84 138.08 8,814.76 - 2,874.06 2,332.00 5,956,257.19 601,520.49 70° 17'23.453 N 149° 10'41.463 W' 9,880.10 58.22 139.03 8,831.73 - 2,892.58 2,348.35 5,956,238.89 601,537.08 70° 17' 23.271 N 149° 10'40.987 W''. 9,910.06 62.77 141.64 8,846.48 - 2,912.66 2,364.97 5,956,219.04 601,553.97 70° 17' 23.073 N 149° 10' 40.502 W' 9,940.25 68.19 145.74 8,859.01 - 2,934.79 2,381.21 5,956,197.13 601,570.50 70° 17'22.856 N 149° 10' 40.029 W !, 9,970.17 73.35 149.20 8,868.86 - 2,958.60 2,396.38 5,956,173.52 601,585.98 70° 17'22.621 N 149° 10' 39.588 W 10,000.19 78.13 152.08 8,876.26 - 2,983.95 2,410.64 5,956,148.36 601,600.57 70° 17'22.372 N 149° 10' 39.173 W 10,030.84 82.49 156.36 8,881.42 - 3,011.15 2,423.76 5,956,121.34 601,614.05 70° 17' 22.104 N 149° 10' 38.790 W 10,061.34 84.40 162.42 8,884.90 - 3,039.50 2,434.42 5,956,093.14 601,625.08 70° 17'21.826 N 149° 10' 38.480 W. 10,091.04 85.61 167.60 8,887.49 - 3,068.07 2,442.07 5,956,064.67 601,633.10 70° 17'21.545 N 149° 10'38.257 W' 10,121.32 87.27 174.27 8,889.37 - 3,097.89 2,446.83 5,956,034.92 601,638.25 70° 17' 21.251 N 149° 10' 38.119 W 10,149.43 87.76 179.88 8,890.59 - 3,125.93 2,448.26 5,956,006.90 601,640.06 70° 17'20.975 N 149° 10' 38.078 W 10,181.13 85.27 184.29 8,892.52 - 3,157.54 2,447.11 5,955,975.28 601,639.32 70° 17' 20.665 N 149° 10' 38.111 W 10,210.03 85.33 189.50 8,894.89 - 3,186.12 2,443.65 5,955,946.66 601,636.25 70° 17'20.384 N 149° 10' 38.212 W 10,240.82 84.65 194.66 8,897.58 - 3,216.11 2,437.24 5,955,916.60 601,630.23 70° 17'20.089 N 149° 10' 38.400 W 10,270.68 85.05 200.52 8,900.26 - 3,244.44 2,428.25 5,955,888.15 601,621.62 70° 17' 19.810 N 149° 10' 38.662 W'I 10,299.92 85.15 206.35 8,902.76 - 3,271.16 2,416.67 5,955,861.28 601,610.39 70° 17' 19.547 N 149° 10'38.999 W 10,330.43 85.73 212.79 8,905.19 - 3,297.60 2,401.67 5,955,834.65 601,595.74 70° 17' 19.287 N 149° 10' 39.437 W 10,361.53 85.27 218.67 8,907.63 - 3,322.76 2,383.57 5,955,809.26 601,577.98 70° 17' 19.040 N 149° 10' 39.964 W 10,390.85 86.44 224.27 8,909.75 - 3,344.66 2,364.22 5,955,787.10 601,558.91 70° 17' 18.825 N 149° 10' 40.528 W 10,421.29 85.67 229.72 8,911.85 - 3,365.36 2,342.02 5,955,766.11 601,536.99 70° 17' 18.621 N 149° 10' 41.175 W' 10,451.26 84.22 234.87 8,914.49 - 3,383.62 2,318.41 5,955,747.55 601,513.63 70° 17' 18.442 N 149° 10' 41.864 W 10,480.40 83.95 241.46 8,917.50 - 3,398.90 2,293.80 5,955,731.95 601,489.22 70° 17'18.291 N 149° 10'42.581 W 10,510.68 83.48 247.46 8,920.81 - 3,411.87 2,266.65 5,955,718.62 601,462.25 70° 17' 18.164 N 149° 10'43.372 W 10,540.65 82.09 253.05 8,924.58 - 3,421.91 2,238.68 5,955,708.21 601,434.42 70° IT 18.065 N 149° 10' 44.187 W 10,570.89 81.19 258.29 8,928.98 - 3,429.31 2,209.70 5,955,700.42 601,405.55 70° 17' 17.992 N 149° 10' 45.031 W'. 10,600.61 80.66 263.71 8,933.67 - 3,433.90 2,180.73 5,955,695.45 601,376.64 70° 17' 17.947 N 149° 10'45.875 W', 10,637.16 81.10 271.08 8,939.47 - 3,435.54 2,144.70 5,955,693.34 601,340.64 70° 17' 17.931 N 149° 10' 46.925 W ! 10,661.08 81.50 275.84 8,943.09 - 3,434.11 2,121.11 5,955,694.46 601,317.03 70° 17' 17.945 N 149° 10' 47.612 W' 10,690.12 81.13 281.70 8,947.48 - 3,429.74 2,092.75 5,955,698.46 601,288.62 70° 17' 17.989 N 149° 10'48.439 W 10,720.28 80.67 287.82 8,952.26 - 3,422.16 2,063.97 5,955,705.66 601,259.74 70° IT 18.063 N 149° 10' 49.277 W 10,751.15 74.70 288.58 8,958.84 - 3,412.74 2,035.33 5,955,714.69 601,230.98 70° 17' 18.156 N 149° 10' 50.112 W 10,785.07 67.96 288.86 8,969.69 - 3,402.44 2,004.91 5,955,724.59 601,200.43 70° 17' 18.257 N 149° 10'50.998 W 10,810.85 70.16 290.04 8,978.90 - 3,394.42 1,982.21 5,955,732.31 601,177.63 70° 17' 18.336 N 149° 10' 51.659 W'. 10,840.98 74.91 289.86 8,987.94 - 3,384.62 1,955.20 5,955,741.76 601,150.50 70° 17' 18.433 N 149° 10' 52.446 W' 10,887.00 74.91 289.86 8,999.92 - 3,369.52 1,913.41 5,955,756.30 601,108.52 70° 17' 18.581 N 149° 10' 53.664 W TD - 2 318" 324/2010 2 :23 :15PM Page 3 COMPASS 2003.16 Build 71 TRE TREE _ C E - ' FMC .,� SAF TES: — 4 -1/2" CHROM E TUBING — 2 -3/8" ACTUATOR= BAKER Chrome liner** KB. ELEV 83.75' �rTD sid BF. ELEV = 54.05 F - - 2j - 6v -- 1+q -5 /8 - TY H ES CEMEMTER KOP= 2573' Max Angle = 88' @ 10150' 2240' 4 -1/2" H ES X NIP, ID= 3.813" Datum MD = 10058' Datum TV = 8800' SS GAS LIFT MANDRELS 20" CONDUCTOR, 91.5#, H -40, ID= 19.124 110 ST MD TVD DEV TYPE VLV LATCH PORT DATE 9 3264 3225 28 KBG2 -1 R DOME BK 16 06/27/08 9 -5/8" CSG, 40#, L -80 BTC, ID = 8.835 3104 8 4213 4020 33 KBG2 -1 R DMY BK 0 05/30/08 7 5577 5168 33 KBG2 -1 R DOME BK 16 06/27/08 6 6396 5843 33 KBG2 -1 R DMY BK 0 05/30/08 Minimum ID =1.92" @ 9350 5 7217 6531 33 KBG2 -1R DOME BK 16 06/27/08 -1 " 13 CR85 liner pits 4 7830 7044 34 KBG2 -1 R DMY BK 0 05/30/08 3 8440 7558 32 KBG2 -1 R DOME BK 16 06/27/08 2 8886 7936 28 KBG2 -1 R DMY BK 0 05/30/08 7" MARKER JOINT 7392 1 9205 8223 13 KBG2 -1 R SO BK 24 06/27/08 4 1 /2" BOT KB LT Packer, 30K Shear 9310 9273' 4 -1/2" HES X NIP, ID = 3.813" Tubing Punch fo Certx nt 9320' 9294' 7" X 4 -1/2" BKR S -3 PKR, ID= 3.875" 9318 4 -1/2" HES X NIP, ID = 3.813" 4 -1/2" BOT Packer Whipstock 9469' Cement Retainer 9485 – 9338 Top of 2rorne liner, 13CR85 Tubing Punch 9490' F - 9 - 4 - 4 - & -- 1 — FT of 3 - 3116" Finer 4 -1/2" TBG, 12.6 #, 13CR VAM TOP 9495' .0152 bpf, ID = 3.958" 9502' FISH - OBSTRUCTION (02/27/09) 9711 3 -3/16" finer to TSGR 9505' 7" X 4 -1/2" UMI OVERSHOT 9508' 7" X 5" ZXP LTPw/ HMC LNR HGR, ID= 4.375" 9528 5" X 4 -1 /2" XO, ID = 3.958" 9603 FISH - OLD TAIL PIPE (05/28/08) 7" CSG, 26 #, L -80 BUTT -M, .0383 bpf, ID = 6.276" 9700' 108$T 2 -318" Chrome Liner to TD PERFORATION SUMMARY REF LOG: SWS MGR /CCL OF 03125/10 ANGLE AT TOP PERF: 51" @ 9844' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn /Sqz DATE 1.56 6 9967-10227 O 03/26/10 1.56 6 10255 - 10475 O 03/26/10 1.56 6 10525 - 10570 O 03/26/10 1.56 6 10592 - 10702 O 03/26110 1.56 6 10735 - 10780 O 03126/10 1.56 6 10800 - 10810 O 03/26/10 1.56 6 10833 -10853 O 03/26/10 PBTD 10101' 4 -1/2" LNR, 12.6#, L -80 BUTT -M, 10187' .0152 bpf, ID= 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 09/28/97 JLM ORIGINAL COMPLETION 03/05/09 RLM/SV OBSTRUCTION (02/27109) WELL: Z -03A 06/02/08 N3S RWO 03/27/10 RRW Nordic 2 CTD SIDETRACK PERMIT No: 04/18/08 TFA /TLH TBG CUT (04/07/08) API No: 50- 029 - 22787 -01 10/15/08 HB/JMD DRLG DRAFT CORRECTIONS SEC 19, T11 N, R12E, 976' FNL & 1427' FWL 10/25/081 PJC I DRAWING CORRECTONS 01/03/09 HB /PJC I FINAL DRLG DRFT CORRECTIONS I I BP Exploration (Alaska) SEAN PARNELL, GOVERNOR ALA K OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Mr. John McMullen Engineering Team Leader BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU Z -03A BP Exploration (Alaska) Inc. Permit No: 210 -010 Surface Location: 976' FNL, 1427' FWL, SEC. 19, T1 1N, R12E, UM Bottomhole Location: 4364' FNL, 3295' FWL, SEC. 19, T1 1N, R12E, UM Dear Mr. McMullen: Enclosed is the approved application for permit to re -drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). Sincerely, qDanielT eamount, Jr. Chair DATED this dd of January, 2010 cc: Department of Fish & Game, Habitat Section w/o encl. (via e -mail) Department of Environmental Conservation w/o encl. (via e -mail) STATE OF ALASKA RE CHVED -" ` ALASSPIL AND GAS CONSERVATION COMMIWN AAA /0 PERMIT TO DRILL =' ''- 20 AAC 25.005 1 a. Type of work: 1b. Proposed Well Class: ® Development Oil ❑ Service - Wini ❑ Single Zone Irl ❑ Drill ® Redrill ❑ Stratigraphic Test []Development Gas ❑ Service - Supply ❑ Multiple Zone ❑ Coalbedbawa 1712as Hydrates ❑ Re -Entry ❑ Exploratory ❑ Service - WAG ❑ Service - Disp ❑ Shale Gas 2. Operator Name: 5. Bond: ® Blanket ❑ Single Well 11. Well Name and Number: BP Exploration (Alaska) Inc. Bond No. 6194193 PBU Z - 03A 3. Address: 6. Proposed Depth: 12. Field / Pool(s): P.O. Box 196612, Anchorage, Alaska 99519 - 6612 MD 10930' TVD 8935'ss Prudhoe Bay Field / Prudhoe 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Bay Oil Pool Surface: ADL 028262 976' FNL, 1427' FWL, SEC. 19, T11 N, R12E, UM Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 3735' FNL, 3656' FWL, SEC. 19, T1IN, R12E, UM April 10, 2010 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 4364' FNL, 3295' FWL, SEC. 19, T11 N, R12E, UM 2560 7036' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: 83.75' feet 15. Distance to Nearest Well Open Surface: x 599151 - 5959100 Zone ASP4 GL Elevation above MSL: 54.05' feet to Same Pool: 1694' 16. Deviated Wells: Kickoff Depth: 9495 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 86 deg ree s Downhole: 3720 ' Surface: 2858 18. Casing Program: Specifications Top Setting De th - Bottom Quanti of Cement, c.f. or sacks Hole Casina Weight Grade Coupling Length MD TVD MD TVD (including stag data 4-1/8" 3- 3/16" 6.2# L -80 TCII 262' 9440' 8382'ss 9702' 62 ' n m nted Liner 2-3/8" 4.7# 13 Cr STL 1530' 9400' 8426'ss 1 9 ` 8 35'ss 29 sx Class 'G' 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): 10187 9210 1 None 10101 9124 1 9502' Casing Length Size Cement Volume MD TVID Conductor / Structural 2 x Ar i ' Surface 3072' 9-5/8" 9 sx Class'G' 1427 sx CS III 3104' 3080' Intermed 9670' 7" x las 'G' 9700' 8724' Production Liner 79' 1 4-1/2" 182 sx Class 'G' 9508'-10187' 1 8533'-9210' Perforation Depth MD (ft): 9844'- 9982' Perforation Depth TVD (ft): 8868'- 9005' 20. Attachments: ❑ Property Plat ® BOP Sketch ® Drilling Program ❑ Time vs Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ® Drilling Fluid Program IN 20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. 1 hereby certify that the f regoing is true nd correct. Contact Sean McLaughlin, 564 -4387 Printed Name Jo M f ! Title Engineering Team Leader Prepared By Name/N Signature Phone 564 -4711 Date Terrie Hubble, 564 -4628 Commission Use Only Permit To Dill API Number: Permi Mail We: See cover letter for Number: d 50 029 - 22787 -01 -00 j} other requirements Conditions of If box is checked, well may not be used to explore for, test, or produce co Ibed me ane, gas hydrates, or gas contained shales: Rr Other. -lt 35 P lJ � 1 ( ' - e T Samples Req'd: ❑ a(es (�No Mud Log Req'd: ❑ Yes �No *2-500 r ` nr► s r ! a S L% ) 1-1 2S Measures: Yes ❑ No Directional Survey Req'd: VYes ❑ No O Date APPROVED BY THE COMMISSION t/we�rw COMMISSIONER Form 10-41 Revised 7/2009 This permit is v�al� � ! 1 t�. a date of approval (20 AAC 25.005(8)) /� Submit In Duplicate ", . 11 A 1- o pOr ArZO \ Obp To: Alaska Oil & Gas Conservation Commission From: Sean McLaughlin CTD Engineer Date: January 12, 2010 Re: Z -03A Permit to Drill request Approval is requested for a permit to drill a CTD sidetrack from well Z -03. A 2008 RWO to change out corroded tubing resulted in a piece of tailpipe with a plug stuck in it, stuck in liner at 9600 MD. No communication with reservoir. Also an obstruction in the Unique machine overshot at -9500 MD. This obstruction is thought to be a partially milled piece of the liner tieback sleeve, milled somewhat lengthwise, laying across the wellbore. No access below 9500' MD. The proposed plan for Z -03A is to drill a through tubing sidetrack with the Nordic 2 Coiled Tubing Drilling rig on or around April 10, 2010 The existing perforations will be isolated by the fish, cement, cement retainer, and the primary cement job. The sidetrack, Z -03A, will exit the 4.5" tubing tail and target zone 4. CTD Sidetrack Summary Pre -Rig Work: (scheduled to begin February 15, 2010) 1. O MIT -IA, -OA 2. S Run dummy whipstock drift to obstruction 3. S Dummy GLV's 4. E Punch tubing @ 9490' and 9320'. 5. E Set cement retainer @ 9485'. 6. C Cement up 4 -1/2" x 7" annulas 7. C Cleanout to top of the cement retainer with a 3.8" mill 8. S Dummy WS drift 9. E Set Baker 4.5" monobore WS w, HS( +/ -30 degs) orientation @ 9470'. �c�'�� 10.0 Set BPV 3* 11. O Test: PPPOT -T. Torqued LDS. 3 `'D 12.0 PT MV, SV, WV 13. O Blind and bleed lines, remove well house, level pad Rig Work: (scheduled to begin on April 10, 2010) 1. MIRU and test BOPE to 250 psi low and 3500 psi high. 2. Mill 3.8" window at 9470' and 10' of rathole. 3. Drill Intermediate: 4.125" OH, 232'(12 deg /100 planned) 4. Run 3- 3/16" uncemented liner to cover up the Kingak 5. Drill Lateral: 3" OH, 1228'(18 deg /100 planned) with resistivity . 6. Run 2 -3/8" solid chrome liner leaving TOL at 9400' 7. Pump primary cement leaving TOC at 9400', 6 bbls of 15.8 ppg liner cmt planned ' s 8. Cleanout liner and MGR/CCL log TD 9. Test liner lap to 2000 psi. 1 10. Perforate liner per asset instructions ( -500') 11. Set Liner Top Packer at 9395' 12. Freeze protect well, RDMO Post Rig: 1. Re- install well house and attach production lines. 2. Pull BPV 3. Run GLV's 4. Test separator? ( -500' of perfs) 1 0 Mud Program: • • Milling /drilling: 8.6 ppg Geo -VIS • 11 ppg KWF to stabilized the Kingak while running the drilling liner. Disposal: • All Class II drilling and completion fluids will go to Grind & Inject at DS 4. • All Class II drilling solids will go to Grind & Inject at DS 4. • All Class I wastes will go to Pad 3 for disposal. Hole sizes: 4 -1/8 bi- center hole: 9,470' to 9,702' 3.0" bi- center hole: 9,702'— 10,930' Casing Program: short drilling liner followed by a cemented production liner • 3- 3/16 ", L -80 6.2# TCII 9440' and — 9702' and • 2 -3/8 ", Chrome 4.70# STL 9400' and — 10,930' and • A minimum of 6 bbls 15.8 ppg cement will be used for liner cementing. (Assuming 3.0" bit size and TD @ 10,930', with 20% excess in the open hole interval) • TOC planned at 9400'. • A liner top packer will be run to isolate the annulus. Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. • The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan. Maximum planned hole angle is 86 deg at 10,600'. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property — 7036 ft • Distance to nearest well within pool — 1780' from Z -39A, 1694 from Z -11 A C TD Anti - Collision • There are no collision issues Logging • MWD directional, Gamma Ray and Resistivity logs will be run over all of the open hole section. • Cased hole GR /CCL, logs will be run. Hazards • The maximum recorded H2S level on Z pad is 70 ppm. • Lost circulation risk is low. Reservoir Pressure • The reservoir pressure on Z -03 is estimated at 3,720 psi at 8,624' TVDSS. (8.3 ppg equivalent) • Max. expected surface pressure with gas (0.10 psi /ft) to surface is 2858 psi. Sean McLaughlin CTD Engineer CC: Well File Sondra Stewman/Terrie Hubble LFEAP = FMC SA ES: — 4112" CHROME TtXM — 3 GAP CTLWTOR = BAKER C • Z-03 BETIMOVERSHOT @ 9505' & LTP @ 9508' KB. ELEV = 83.75 . ELEV = 54.05' KOP= 2573' 2101' 9-5/8" TYPE H ES C6VIBVITER Mix Angle = 35' 015780' Datum MD= 9860' 2240' 4 1/7 FI ES X NIP, I = 3.813" Datum TVD = 8800' SS GAS LIFT MANDRELS 20" CONDUCTOR, 91.518, H-40, ID =19.124" 110' ST MD TVD DEV TYPE VLV LATCH PORT DATE DOME 9 3264 3225 28 KBG2 -1 R E BK 16 06/27108 9-5/8" CSG, 401f, L -80 BT-, ID = 8.835" 3104' 8 4213 4020 33 KBG2 -1 R DMY BK 0 05/30/08 f 7 5577 5168 33 KBG2 -1 R DOME BK 16 0687108 Minimum ID = 3.813" @ 2240 6 6396 5843 33 KBG2 -1R DMY BK 0 0500108 4 -112" HES X NIPPLE 5 7217 6531 33 KBG2 -1R DOME BK 16 0627108 4 7830 7044 34 KBG2 -1 R DMY BK 0 05/30/08 3 8440 7558 32 KBG2 -1 R DOME BK 16 0627108 2 8886 7936 28 KBG2 -1 R DMY BK 0 05/301108 7" MARKER JOINT 7392' 1 9205 8223 1 13 KBG2 -1 R SO BK 24 0627/08 9273' 41/2" HES X NIP, — ID — = - 3. - 8137 - 9294' HE X 412" BKR S -3 PAR, ID = 3.875" 9318' 412" HES X NIP, ID = 3.813" 412" TBG, 12.61/, 13CR VAM TOP, 9495' 9502' FISH -OBSTRUCTION (02/27109) .0152 bpf, D = 3.958" 9w5' 7" X 41/2" LM OVERSHOT TOP OF 412" LNR 9508' g5p8' 7" X 5" ZXP LTPw / FMAC LNR HGR, ID = 4.375" 9528' 7" CSG, ZBlit, L -80 BUTT -M, .0383 bpf, D = 6.276" 9700' 9603' FISH - OLD TAIL PEE (05128108) PERFORATION SUMMARY REF LOG: BRCS ON 09/24/97 ANGLE AT TOP PERF: 4' @ 9844' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sgz DATE 2 -1/2" 6 9844- 9857 0 10/02/03 2 -1/2" 6 9864-9882 0 10102103 2-1/2' 6 9888-9896 0 10102103 2 -1/2" 6 9900-9906 0 10102/03 2 -12" 8 9910-9925 0 07119198 2 -1/2" 4 9928-9940 0 08106/99 2 -1/2" 8 9945- 9982 0 07/30/98 PBTD 10101' 410 LNR, 12.68, L -80 BUTT-1K 10187' .0152 bpf, D = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 09/28197 JLM ORIGINAL COMPLETION 0310509 RLM /SV OBSTRUCTION (02/27109) WELL: Z-03 08/02011 N3S RWO PERMIT No: 9 1971310 04/18/08 TFA/TLH TBG CUT (04/07-08) API No: 50-029- 22787 -00 1011508 HB/JMD DRLG DRAFT CORRECTIONS SEC 19, T11N, R12E, 976 FNL 3 142T FWL 10125/08 PJC IDRAWING CORRECTONS 01/03/09 HB /PJC I FINAL DRLG DRFT CORRECTIONS BP Exploration (Alaska) F E Cw Z 03A LHEAD = FMC � SA TES: "" 4 -1/2" CHROME TUBING'"' 3" GAP UATOR= BAKER S BET�OVERSHOT r@ 9505' & LTP 9508 KB. ELEV = 83.75' proposed CTD sidetrac B F. ELEV = 54.05 KO 2573' 2101' 9 -5/8" TYPE H ES CEMHNTER Max Angle = 35' @ 5780' Datum MD = 2240' 41 /2" HES X NIP, ID = 3.813" Datum TV D = 8800' SS GAS LIFT MANDRELS 20" CONDUCTOR, 91.5#, H -40, ID - 110' ST MD TVD DEV TYPE I VLV LATCHI PORT DATE 9 3264 3225 28 KBG2 -1 R DOME BK 16 06/27/08 9 -5/8" CSG, 40#, L -80 BTC, ID = 8.835" 3104' 8 4213 4020 33 KBG2 -1 R DMY BK 0 05130/08 7 5577 5168 33 KBG2 -1 R DOME BK 16 0627108 Minimum ID = 2.375" @ 9330 6 6396 5843 33 KBG2 -1R DMY BK 0 05/30/08 4 -112" KB LTP 1 5 7217 6531 33 KBG2 -1R DOME BK 16 0627/08 4 7830 7044 34 KBG2 -1 R DMY BK 0 05/30 /08 3 8440 7558 32 KBG2 -1 R DOME BK 16 0627 /08 2 8886 7936 28 KBG2 -1 R DMY BK 0 05130 /08 7" MA RKER JOINT 7392' 1 9205 8223 13 1 KBG2 -1 R SO BK 24 0627 /08 9273' 41/2" HES X NIP, ID = 3.813" Tubing Pinch 9320' 9294' 4 -112" KB LTP, ID = 2.375" 9395' 7" X 4-1/2" BKR S -3 PKR, ID = 3.875" 9318 4112" HES X NIP, ID = 3.813" 4 -1/2" BOT Packer Whipstock 9470' 9400' Top of 2 -3/8" chrome liner Cement Retainer 9485' 9440 Top of 3 -3116" liner Tubing Punch 9490' 41/2" TBG, 12.6 #, 13CRVAMTOP 9495' 0152 bpf, ID = 3.958" 9502' FISH -OBSTRUCTION (02/27/09) 9702' 3- 3/16" liner to TSGGR 9505' 7" X — 4- - 1/ - 2 - UMI OV ERS HOT 9508' 7" X 5" ZXP LTP w / HMC LNR HGR, ID = 4.375" 9603 FISH - OLD TA IL PIPE (05/28/08) 109W C hrome Liner — to — TD -- ] 7" CSG, 26 #, L -80 BUTT -M, .0383 bpf, ID = 6.276" 9700' PERFORATION SUMMARY REF LOG: BHCS ON 09/24/97 ANGLE AT TOP PERF: 4' @ 9844' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 2 -1 /2' 6 9844-9857 O 10/02103 2 -1 /2' 6 9864-9882 0 10/02/03 2-1/2' 6 9888-9896 0 10102/03 2 -1 /2' 6 9900-9906 0 10102/03 2 -117' 8 9910-9925 0 07/19/98 2 -112' 4 9928-9940 0 08106/99 2 -112' 8 9945-9982 0 07/30/98 PBTD 10101' 4 -112" LNR, 12.6 #, L -80 BUTT -M, 10187' DATE DATE REV BY COMMENTS PRUDHOE BAY UNIT 09/28/97 JLM ORIGINAL COMPLETION 03 /05 /09 RLMISV OBSTRUCTION (0227 /09) WELL. Z -03 06102/08 N3S RWO 04/27 /09 MSE PROPOSED CTD SIDETRACK PERMIT No: 04/18/08 TFA/TLH TBG CUT (04/07 /08) API No: 50- 029 - 22787 -0 10/15/08 HB/JMD DRLG DRAFT CORRECTIONS SEC 19, T11 N, R1 2F, 976' FNL & 1427' FWL 10/25/08 PJC DRAWING CORRECTONS 01 /03109 HB /PJC FINAL DRLG DRFT CORRECTIONS BP Exploration (Alaska) red It9 BP Exploration Alaska RUMES Baker Hughes INTEQ Planning Report by IiNTEQ 0 Company: North America - ALASKA - BP Local Co- ordinate Reference: Well Z -03 -Slot 03 Project: Prudhoe Bay TVD Reference: Mean Sea Level Site: PB Z Pad MD Reference: 5 : 03 9/1/1997 06:00 @ 83.75ft (Nabors 18E) Wall. Z -03 North Reference: True Welibore: Plan 1, Z -03A Survey Calculation Method: Minimum Curvature Design; Plan 1 Database, EDM .16 - Anc Prod - WH24P Survey Toot Program Date 4/23/2009 From To (ft) (ft) Survey (Wellbore) Tool Name Description 155.11 9,466.11 1 : MWD - Standard (Z -03) MWD MWD - Standard 9,466.11 10,929.83 Plan 1 (Plan 1, Z -03A) MWD MWD - Standard Planned Survey MD' Inc Ail TVDSS N/S E/W Northing , Easting DLeg V. Sec TFace (ft) 0 ( °) ( ft) (ft) (ft) (ft) (ft) ( °/100ft); (ft) (0) 9,466.11 5.66 135.49 8,407.55 - 2,739.44 2,202.94 5,956,390.08 601,389.68 0.00 379.36 0.00 TIP 9,475.00 5.71 134.92 8,416.39 - 2,740.07 2,203.56 5,956,389.47 601,390.31 0.85 379.37 -48.76 KOP 9,495.00 7.51 134.92 8,436.26 - 2,741.69 2,205.19 5,956,387.86 601,391.96 9.00 379.36 0.00 End of 9 Deg /100' DLS 9,500.00 8.11 134.92 8,441.21 - 2,742.17 2,205.67 5,956,387.39 601,392.45 12.00 379.36 0.00 9,600.00 20.11 134.92 8,538.02 - 2,759.36 2,222.90 5,956,370.44 601,409.90 12.00 379.33 0.00 9,700.00 32.11 134.92 8,627.65 - 2,790.37 2,254.01 5,956,339.84 601,441.41 12.00 379.27 0.00 9,701.89 32.34 134.92 8,629.25 - 2,791.09 2,254.72 5,956,339.13 601,442.14 12.00 379.27 0.00 End of 12 Deg /100' DLS 9,800.00 50.00 134.92 8,702.81 - 2,836.51 2,300.27 5,956,294.32 601,488.28 18.00 379.18 0. 9,841.89 57.54 134.92 8,727.56 - 2,860.35 2,324.18 5,956,270.80 601,512.50 18.00 379.13 0.00 5 9,900.00 65.20 143.05 8,755.42 - 2,898.84 2,357.49 5,956,232.75 601,546.30 18.00 382.80 45.00 10,000.00 79.19 154.98 8,786.02 - 2,980.29 2,405.94 5,956,151.96 601,595.82 18.00 406.13 41.09 10,031.89 83.77 158.49 8,790.75 - 3,009.26 2,418.38 5,956,123.16 601,608.65 18.00 417.81 37.40 6 10,100.00 82.85 170.80 8,798.72 - 3,074.35 2,436.27 5,956,058.31 601,627.39 18.00 451.19 95.00 10,200.00 82.10 188.94 8,811.93 - 3,173.06 2,436.51 5,955,959.62 601,628.94 18.00 520.82 93.56 10,211.89 82.06 191.10 8,813.57 - 3,184.66 2,434.46 5,955,948.00 601,627.04 18.00 530.47 91.16 7 10,300.00 83.73 206.99 8,824.53 - 3,267.02 2,406.01 5,955,865.28 601,599.67 18.00 608.83 85.00 412312009 11:13:30AM Page 3 COMPASS 2003.16 Build 70 012 BP Exploration Alaska 8 069 Baker Hughes INTEQ Planning Report by 1NTEQ Company: North America - ALASKA - BP Local Co- ordinate Reference: Well Z -03 - Slot 03 Project: Prudhoe Bay 7VD Reference: Mean Sea Level Site: "PB Z Pad MD Reference: 5 : 03 9/1/1997 06:00 @ 83.75ft (Nabors 18E) Well: ' Z -03 North Reference: True Wellbore: Plan 1, Z -03A Survey Calculation Method: Minimum Curvature Design: Plan 1 Database: EDM .16 - Anc Prod - WH24P Planned Survey MD Inc Azi TVDSS N/S E/W Northing j Fasting DLeg - V. Sec TFa.ce (ft) V) ( °) ( ft) (ft) (ft) (ft) (ft) ( ° /100ft)'' (ft) 0 10,381.89 85.70 221.67 8,832.12 - 3,334.16 2,360.14 5,955,797.54 601,554.70 18.00 688.74 83.0 8 10,400.00 85.71 224.93 8,833.47 - 3,347.30 2,347.75 5,955,784.24 601,542.49 18.00 706.79 90.00 10,500.00 86.00 242.98 8,840.77 - 3,405.74 2,267.44 5,955,724.76 601,462.96 18.00 804.90 89.76 10,561.89 86.37 254.14 8,844.90 - 3,428.28 2,210.05 5,955,701.46 601,405.88 18.00 861.41 88.44 9 10,600.00 86.40 261.01 8,847.30 - 3,436.46 2,172.94 5,955,692.80 601,368.88 18.00 893.44 90.00 10,661.89 86.55 272.17 8,851.12 - 3,440.12 2,111.37 5,955,688.32 601,307.37 18.00 939.57 89.57 10 10,700.00 83.15 278.15 8,854.55 - 3,436.71 2,073.59 5,955,691.23 601,269.55 18.00 963.87 120.00 10,771.89 76.96 289.70 8,867.00 - 3,419.78 2,005.00 5,955,707.26 601,200.75 18.00 1,000.40 119.46 11 10,800.00 72.38 287.46 8,874.43 - 3,411.14 1,979.32 5,955,715.56 601,174.96 18.00 1,012.45 - 155.00 i 10,900.00 56.39 278.23 8,917.60 - 3,390.71 1,891.92 5,955,734.83 601,087.31 18.00 1,059.81 - 154.41 10,930.00 51.75 274.84 8,935.20 - 3,387.93 1,867.80 5,955,737.29 601,063.16 18.00 1,074.89 - 150.37 2.375" 412312009 11:13:30AM Page 4 COMPASS 2003.16 Build 70 A'"", g" to rme onn N WELLBORE DETAILS: Plan 1, Z -03A REFERENCE INFORMATION m Fag Pro ject: Prudhoe Bay Magnets ,uo North 0 Site: PBZ Pad urea Parent Wellbore: Z -03 oa Cidinate(NIE) Reference: Well Z-03 -Slat 03,T North Magneec Well: Z -03 S4englh: 5]686.9an Venial (TVD) Reference: Mean Sea Level Wellbore: Plan 1, Z -03A Tie on MD: 9466.11 MOM Dip Angre: 80.86 Section (VS) Reference: Slot - 03(0 DON, O.00E) bp Plan: Plan 1 (Z -03/Plan 1, Z -03A) Mod 411 Measured Depth Reference 5:03 9/111997 0600 83.75ft (Nabors 18E) Cakulaeon Method: Minimum Curvature I.NTEQ -247 WELL DETAILS: Z -03 -2565 TIP Ground Level: 0.00 2 A. *NI-S +E / - Northing Easting Latiftude Longitude Slot 0.00 0.00 5959099.98 599150.99 70° 17' 51.723 N 149° 11' 49.414 W 03 2 , 1 -2755 0 - - - _ SECTION DETAILS ANNOTATIONS - -2850 Sec MD Inc Azi ssTVD +W -S +E/-W DLeg TFace VSec Target Annotation End o 12 Dt g/ 100 D LS 1 9466.11 5.66 135.49 8407.55 - 2739.44 2202.94 0.00 0.00 379.36 TIP 2945 2 9475.00 5.71 134.92 8416.39 - 2740.07 2203.56 0.85 -48.76 379.37 KOP 3 9495.00 7.51 134.92 8436.26 - 2741.69 2205.19 9.00 0.00 379.36 End of 9 Deg1100' DLS 4 9701.89 32.34 134.92 8629.25 - 2791.09 2254.72 12.00 0.00 379.27 End of 12 Degf100' DLS « -3040 Se 6 5 9841.89 57.54 134.92 8727.56 - 2860.35 2324.18 18.00 0.00 379.13 5 6 10031.89 83.77 158.49 8790.75 - 3009.26 2418.38 18.00 45.00 417.81 6 7 10211.89 82.06 191.10 8813.57 - 3184.66 2434.46 18.00 95.00 530.47 7 3135 • L- 3A T. .jet 10381.89 85.70 221.67 8832.12 - 3334.16 2360.14 18.00 85.00 688.74 8 ^ et 3 Z 3A T rge[ 2 9 10561.89 86.37 254.14 8844.90 - 3428.28 2210.05 18.00 90.00 861.41 9 t,3230 10 10661.89 86.55 272.17 8851.12 - 3440.12 2111.37 18.00 90.00 939.57 10 11 10771.89 76.96 289.70 8867.00 - 3419.78 2005.00 18.00 120.00 1000.40 11 70.3325 Z-(3/Plan I Z -0 t 7 12 10930.00 51.75 274.84 8935.20 - 3387.93 1867.80 18.00 205.00 1074.89 TO at 10930.00 C .-342 \ I 0 -3515 11 9 10 -361 -3705 -3800 -3895 1425 1520 1615 1710 1805 1900 1995 2090 2185 2280 2375 2470 2565 2660 2755 2850 2945 3040 3135 West(- )Bast( +) (95 ft/in) 833 840 - - - IP 847 KOP • 854 End f 9 81100' DLS O ..i 861 868 Eno ` A 875 U 5 Z -03 Targit 2 882 > 7 Z -03A Target 1 9 Z -0 Tar t 3 y 889 II F 896 Z- 3/Plan 1, Z -0 A 903 Mean Sea evel 910 LLt L -210 -140 -70 0 70 140 210 280 350 420 490 560 630 700 770 840 910 980 1050 1120 1190 1260 1330 1400 1470 1540 1610 1680 1750 1820 1890 1960 2030 2100 2170 2240 2310 2380 2450 Vertical Section at 225.00° (70 ft/in) a BP Exploration Alaska Travelling Cylinder Report by INTEQ Company: North America - ALASKA - BP Local Go- ordinate Reference: Well Z -03 - Slot 03 Project: Prudhoe Bay TVD Reference: Mean Sea Level Reference Site: PB Z Pad MD Reference: 5: 03 9/1/1997 06:00 @ 83.75ft (Nabors 18E) Site Error: 0.00ft North Reference: True Referent e,Well: Z -03 Survey Calculation Method: Minimum Curvature Well Error:. 0.00ft Output errors are at 1.00 sigma Reference Wellbore Plan 1, Z -03A Database: EDM .16 - Anc Prod - WH24P Reference Design: Plan 1 Offset TVD Reference: Offset Datum Reference Plan 1 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of refer( Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: 9,466.11 to 10,930.00ft Scan Method: Tray. Cylinder North Results Limited by: Maximum center - center distance of 1,290.03ft Error Surface: Elliptical Conic Survey Tool Program Date 4/23!2009 From To (ft) (ft) Survey, (Wellbore) Tool Name Description 155.11 9,466.11 1 : MWD - Standard (Z -03) MWD MWD - Standard 9,466.11 10,929.83 Plan 1 (Plan 1, Z -03A) MWD MWD - Standard Casing Points; _ Measured Vertical Casing . Noie Depth Depth Diameter Diameter (ft1 (ft) Name (in) iln). 10,930.00 8,935.20 2.375" 2.375 3.000 Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well f- Wellbore - Design (ft) (ft) (ft) (ft) !' PB Z Pad Z -02 - Plan Z -02B - Plan #3 Out of range Z -02 - Z -02A - Z -02A Out of range Z -03 - Z -03 - Z -03 9,475.00 9,475.00 0.00 0.69 -0.33 FAIL - Major Risk Z -04 - Z -04 - Z -04 Out of range Z -108 - Plan Z -108A - Plan #2 Out of range Z -13 - Z -13 - Z -13 Out of range Z -13 - Z-1 3A - Z-1 3A Out of range Z -13 - Z- 13APB1 - wp07 Out of range Z -14 - Z -14 - Z -14 Out of range Z -14 - Z -14B - Plan #8 Out of range Z -14 - Z -14B - Z -14B Out of range Z -14A - Z -14A - Z -14A Out of range Z -21 - Z -21 - Z -21 Out of range Z -21 - Z -21 A - Z -21 A Wp 07 Out of range Z -28 - Z -28 - Z -28 Out of range Z -39 - Z -39 - Z -39 Out of range Z -39 - Z -39 - Z -39 Wp07 Out of range Z -39 - Z -39A - Z -39A 9,825.00 10,375.00 1,257.62 317.25 943.73 Pass - Major Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 412312009 11 :23:39AM Page 2 of 5 COMPASS 2003.16 Build 70 All Measurements are from top of Riser 1/14/2010 i Z -03A top of bag BAG bttm of bag middle of blind /shear Blind /Shears TOTs middle of pipes /slip 2° combi ram /slips Mud Cross middle of flow cross Mud Cross middle of pipe /slip variable bore pipe 3 1/2 " -2 3/8" TOTs middle of pipe /slips ::::2" pipe /slips Swab Valve Flow Tee Alaska Department of Natura 4 sources Land Administration System • Page 1 o%- Alaska Mapper Land Records /Status Plats Recorder's Search State Cabins Natural Resources Alaska DNR Case Summary File Type ADL File Number: 28262 & Printable Case File Summary See Township, Range, Section and Acreage? L�) Yes Q No New Search LAS Menu I Case Abstract I Case Detail I Land Abstract File: ADL 28262 ''gar Search for Status Plat Updates As of 01/21/2010 Customer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER - ALASKA ANCHORAGE AK 995196612 Case Type: 784 OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 08/26/1965 Total Acres: 2480.000 Date Initiated: 05/28/1965 Office ofPrimary Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 05/04/2009 Case Subtype: NS NORTH SLOPE Last Transaction: CHNGTEXT CHANGE LEGAL TEXT Meridian: U Township: WIN Range: 012E Section: 17 Section Acres: 640 Search Plats Meridian: U Township: 011N Range: 012E Section: 18 Section Acres: 599 Meridian: U Township: 011N Range: 012E Section: 19 Section Acres: 601 Meridian: U Township: WIN Range: 012E Section: 20 Section Acres: 640 Legal Description 05 -28 -1965 * ** SALE NOTICE LEGAL DESCRIPTION * ** C14-58 T1 IN, R12E, UM 17, 18, 19, 20 2,480.00 12 -04 -1969 * ** ASSIGNMENT LEGAL DESCRIPTION * ** SEGMENT 1 T I IN, R 12E, UM SECTION 17: 640 ACRES SECTION 18: 599 ACRES SECTION 19: 601 ACRES http://dnr.alaska.gov/projects/las/Case Summary. cfm ?FileType= ADL &FileNumber = 2826... 1/21/2010 • 0 TRANSMITTAL LETTER CHECKLIST WELL NAME 2/-'Iv z' 03X7 PTD# =.C710010 ✓ Development Service Exploratory Stratigraphic Test Non - Conventional Well FIELD: �.�G/Q,�/O� 17,4> POOL: Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD -ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in permit No. , API No. 50- - - API number are between 60 -69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non - Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 Field & Poo PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY U NIT Z -03 --- Program Program DE V_ Well bore seg ❑ PTD #:2100100 Company 13P E XPLORATION (ALASK INC - Initial Class /Type DE V / PEND — GeoArea 890 - -- Unit 11650 _ _ —__ On /Off Shore On_ _ Annular Disposal ❑ Administration 1 Permit-fee attached - - - NA I2 Lease number appropriate --- Yes 3 Unique well name and number Yes _ 4 Well located in a defined pool Yes 5 Well located proper distance from drilling unit boundary - - - - - - - - 6 Well located proper distance from_ other wells Yes - - 7 Sufficient acreage available in_dril_ling unit Yes 2560 acres. 8 If deviated, is wellbore plat included Yes 9 Operator only affected party Yes 10 Operator has-appropriate bond in _force Yes Blanket Bond # 6194193. 11 Permit can be issued without conservation order Yes Appr Date I12 Permit_ can be issued without administrative approval Yes ACS 1/21/2010 13 Can permit be approved before 15 -day wait - - - Yes 14 Well located within area and strata authorized by Injection Order # (put IO# in—comments)—(For NA 15 All wells within 1 /4_miI_e area of review identified (For service well only) NA_ - - 16 Pre - produced injector: duration of pre - production Less than 3 months (For service well only) NA 17 Nonconven. gas conforms to AS31.05.030(j.1.A),0.2.A -D) NA_ 18 Conductor string provided NA Conductor set in Z -03 Engineering 1 Surface casing_ protects all known USDWs NA_ Surface casing set in Z -03 1 20 CMT vol adequate to circulate on conductor _& su_rf_csg NA Surface casing cemented in Z -03 I 21 CMT vol adequate to tie -in long string to surf csg_ NA_ Production casing set in Z_ -03 22 CMT will cover all known productive horizons_ Yes Liner to be cemented and perfed_. 23 Casing designs adequate for C, T, B & permafrost_ Yes 24 Adequate tankage or reserve pit Yes _ Rig equipped with steel pits. All waste to-approved disposal wells. 25 If _a re- drill, has_a 1.0 -403 for abandonment been approved Yes 310 -010 I 26 Adequate wellbore separation proposed Yes Proximity analysis perfromed. Closest well is Z-1 1A at 1694' - - I27 If diverter required, does it _meet regulations NA_ wellhead already in place. BOP installed. Appr Date 128 _Drilling fluid program schematic _& equip list adequate Yes Max formation pressure =3720 psi ( 8.3 ppg EMW) -Will drill with 8.6 ppg mud. GLS 1/22/2010 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) - - - Yes MASP = 2858 psi Will test BOP to 3500 psi 31 Choke manifold complies w /API RP -53 (May 84) Yes 32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas_ probable Yes H2S on Z pad. Rig has sensors and alarms. 34 Mechanical -condition of wells within AOR verified (For service well only) NA r35 _Permit can be issued w/o hydrogen sulfide measures No Max level H2S on _Z pad is 70ppm. Geology 36 Data presented on potential overpressure zones NA_ Appr Date 37 Seismic analysis of shallow gas-zones - - - - - NA ACS 1/21/2010 38 Seabed condition survey (if off- shore) NA_ 39 Contact name /phone for weekly progress reports_ [exploratory only] NA_ Geologic Engineering P Commissioner: Date: Commissioner: Date Com r Date /-1Z Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. tapescan.txt * ** REEL HEADER * * ** MWD 10/06/21 BHI 01 LIS Customer Format Tape * * ** TAPE HEADER * * ** MWD 10/03/23 3073707 01 3" CTK * ** LIS COMMENT RECORD * ** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: ldwg.las version Information VERS. 1.20: OWLS log ASCII Standard - VERSION 1.20 WRAP. NO: one line per frame well Information Block #MNEM.UNIT Data Type Information #--- - - - - -- ------- - - - - -- ------------------------------- STRT.FT 8867.5000: starting Depth STOP.FT 10887.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. - 999.2500: Absent value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: Z -03A FLD FIELD: Prudhoe Bay Unit LOC LOCATION: 70 deg 17' 33.051 "N 149 deg 11' 49.414 "W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 3" CTK DATE. LOG DATE: 23 Mar 2010 API . API NUMBER: 500292278701 Parameter Information Block #MNEM.UNIT Value Description #--- - - - - -- ------------------- - - - - -- ------------------------------- SECT. 19 Section TOWN.N T11N Township RANG. R12E Range PDAT. MSL Permanent Datum EPD .F 0 Elevation Of Perm. Datum LMF . DF Log Measured from FAPD.F 83.75 Feet Above Perm. Datum DMF . DF Drilling Measured From EKB .F 0 Elevation of Kelly Bushing EDF .F 83.75 Elevation of Derrick Floor EGL .F 0 Elevation of Ground Level Page 1 tapescan.txt CASE.F N/A Casing Depth Osi . DIRECTIONAL Other services Line 1 Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All True vertical Depths (TVDSS) are subsea corrected. (4) All Formation Evaluation data is realtime data. (5) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage surface system to log this well.. (6) Tools ran in the string included casing Collar Locator, an Electrical Disconnect and Circulating sub, a Drilling Performance sub (Inner and outer Downhole Pressure, vibration and Downhole weight on Bit), a Directional and Gamma Sub, and a Hydraulic orienting Sub with a Near Bit Inclination Sensor. (7) Data presented here is final and has been depth adjusted to a Primary Depth Control (PDC) log provided by schlumberger CH GR above the dated 25 Mar 2010 per Robert Elliott with BP Exploration (Alaska), Inc. (8) The sidetrack was drilled from z -03A through a milled window in a 4 1/2 and 7 inch liner. Top of window 9469 ft.MD (8410.3 ft.TVDSS) Bottom of window 9479 ft.MD (8420.6 ft.TVDSS) (9) Tied to z -03 at 9466 feet MD (8407.6 feet TVDSS. (10) The resistivity interval from 9479 ft. to 9711 ft. MD (8420.6 ft. to 8631.1.5 ft. TVDSS) was not logged because of running a 3 3/16 liner in the Kingak Shale after drilling. (10) The interval from 10863 ft to 10887 ft MD (8909.9 ft. to 8916.2 ft. TVDSS) was not logged due to sensor to bit offset at well TD. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD -API units) ROP —AVG -> Rate of Penetration, feet /hour RACLX -> Resistivity (AT)(Ls)400kHZ- Compensated Borehole Corrected (OHMM) RACHX -> Resistivity (AT)(LS)2MHz- Compensated Borehole Corrected (OHMM) RPCLX -> Resistivity (PD)(Ls)400kHZ- Compensated Borehole Corrected (OHMM) RPCHX -> Resistivity (PD)(LS)2MHz- Compensated Borehole Corrected (OHMM) TVDSS -> True Vertical Depth (subsea) CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT 9455.2, 9453.77, ! - 1.43652 9460.75, 9459.31, ! - 1.43652 9468.34, 9468.13, ! - 0.205078 9470.39, 9470.39, ! 0 9473.27, 9472.65, ! - 0.616211 9477.58, 9477.37, ! - 0.206055 9479.83, 9479.63, ! - 0.206055 9481.48, 9481.68, ! 0.205078 9487.63, 9487.02, ! - 0.615234 9493.59, 9493.59, ! 0 9499.54, 9499.33, ! - 0.205078 9513.68, 9511.83, ! - 1.84766 9516.14, 9514.5, ! - 1.6416 9518.19, 9517.99, ! - 0.205078 9526.2, 9527.22, ! 1.02637 9529.28, 9531.53, ! 2.25781 9536.05, 9536.25, ! 0.205078 9538.31, 9538.1, ! - 0.205078 9539.95, 9540.36, ! 0.410156 9540.97, 9541.38, ! 0.410156 9544.44, 9545.67, ! 1.23145 Page 2 tapescan.txt 9546.7, 9547.11, ! 0.410156 9554.09, 9551.01, ! - 3.07812 9559.01, 9559.83, ! 0.821289 9563.32, 9564.96, ! 1.6416 9568.08, 9568.28, ! 0.206055 9576.9, 9575.26, ! - 1.6416 9584.38, 9586.02, ! 1.64258 9591.07, 9591.68, ! 0.615234 9597.22, 9598.66, ! 1.43652 9601.33, 9601.33, ! 0 9607.49, 9608.31, ! 0.821289 9612.85, 9613.47, ! 0.616211 9620.04, 9620.45, ! 0.410156 9627.63, 9627.02, ! - 0.615234 9637.34, 9638.16, ! 0.820312 9642.8, 9642.18, ! - 0.616211 9648.96, 9649.98, ! 1.02637 9651.01, 9652.44, ! 1.43652 9656.96, 9657.37, ! 0.410156 9660.86, 9660.45, ! - 0.410156 9665.99, 9665.99, ! 0 9678.13, 9679.57, ! 1.4375 9685.73, 9685.32, ! - 0.410156 9687.37, 9686.75, ! - 0.615234 9693.94, 9693.32, ! - 0.615234 9698.66, 9698.25, ! - 0.410156 9701.33, 9700.51, ! - 0.821289 9705.84, 9704.82, ! - 1.02637 9708.1, 9707.08, ! - 1.02637 9709.33, 9709.54, ! 0.205078 9714.05, 9713.44, ! - 0.616211 9718.57, 9718.16, ! - 0.411133 9727.81, 9726.16, ! - 1.64258 9732.73, 9731.91, ! - 0.821289 9733.96, 9733.35, ! - 0.615234 9737.04, 9736.43, ! - 0.616211 9740.39, 9739.57, ! - 0.820312 9743.06, 9741.83, ! - 1.23242 9747.58, 9746.75, ! - 0.821289 9753.73, 9752.71, ! - 1.02637 9755.17, 9753.73, ! - 1.43652 9760.1, 9759.07, ! - 1.02539 9762.15, 9760.51, ! - 1.6416 9767.08, 9766.05, ! - 1.02637 9767.9, 9767.08, ! - 0.820312 9772.21, 9771.8, ! - 0.410156 9774.67, 9773.44, ! - 1.23145 9776.31, 9775.08, ! - 1.23145 9779.8, 9779.18, ! - 0.616211 9781.03, 9781.44, ! 0.410156 9785.55, 9785.14, ! - 0.411133 9786.37, 9785.96, ! - 0.411133 9789.04, 9788.22, ! - 0.821289 9793.14, 9792.32, ! - 0.820312 9794.5, 9794.7, ! 0.205078 9798.4, 9797.58, ! - 0.820312 9799.42, 9799.42, ! 0 9801.07, 9800.65, ! - 0.411133 9802.3, 9802.09, ! - 0.206055 9804.35, 9804.55, ! 0.206055 9820.97, 9820.56, ! - 0.410156 9822, 9821.8, ! - 0.205078 9823.44, 9823.03, ! - 0.410156 Page 3 tapescan.txt 9835.99, 9835.58, ! - 0.410156 9837.43, 9837.02, ! - 0.410156 9839.48, 9838.86, ! - 0.616211 9843.38, 9842.56, ! - 0.820312 9845.64, 9844.61, ! - 1.02637 9846.87, 9845.23, ! - 1.6416 9849.13, 9846.87, ! - 2.25781 9850.97, 9849.33, ! - 1.6416 9855.49, 9854.46, ! - 1.02637 9858.36, 9856.72, ! - 1.6416 9860.42, 9858.57, ! - 1.84668 9862.47, 9862.47, ! 0 9864.32, 9864.52, ! 0.205078 9871.29, 9871.09, ! - 0.205078 9877.58, 9877.58, ! 0 9882.5, 9881.48, ! - 1.02637 9885.17, 9883.94, ! - 1.23145 9891.94, 9891.33, ! - 0.615234 9896.25, 9895.23, ! - 1.02637 9900.36, 9900.15, ! - 0.205078 9908.54, 9907.72, ! - 0.821289 9911.42, 9911.21, ! - 0.205078 9916.14, 9915.52, ! - 0.615234 9918.19, 9917.58, ! - 0.615234 9921.89, 9921.48, ! - 0.410156 9924.55, 9923.32, ! - 1.23145 9929.28, 9928.25, ! - 1.02637 9931.33, 9931.12, ! - 0.206055 9936.87, 9937.9, ! 1.02637 9941.18, 9941.38, ! 0.205078 9944.67, 9945.29, ! 0.616211 9948.96, 9949.57, ! 0.616211 i 9954.09, 9953.68, - 0.410156 9957.58, 9957.17, ! - 0.411133 9959.42, 9959.22, ! - 0.205078 9964.35, 9964.55, ! 0.206055 9969.87, 9971.1, ! 1.23145 9980.95, 9981.57, ! 0.616211 9989.57, 9989.37, ! - 0.206055 9992.44, 9992.44, ! 0 9997.99, 9999.42, ! 1.43652 10001.1, 10002.1, ! 1.02539 10002.3, 10003.5, ! 1.23145 10007.8, 10009.3, ! 1.43652 10011.7, 10012.4, ! 0.615234 10015.6, 10016.5, ! 0.821289 10018.7, 10019.3, ! 0.616211 10023.2, 10024.1, ! 0.821289 10035.9, 10037.4, ! 1.43652 10042.9, 10045.2, ! 2.25781 10044.8, 10047.4, ! 2.66797 10054.8, 10054.4, ! - 0.411133 10062.2, 10062.4, ! 0.205078 10065.7, 10066.7, ! 1.02637 10078.2, 10078, ! - 0.205078 10083.3, 10083.1, ! - 0.206055 10093.1, 10093.5, ! 0.410156 10096.8, 10097, ! 0.205078 10111.5, 10109.9, ! - 1.64258 10117.9, 10115.8, ! - 2.05176 10139, 10136.5, ! - 2.46289 10141.9, 10141.3, ! - 0.615234 10150.9, 10152.1, ! 1.23145 Page 4 tapescan.txt 10160.4, 10161, ! 0.616211 10167.5, 10166.7, ! - 0.821289 10172.4, 10170.4, ! - 2.05273 10174.9, 10173.5, ! - 1.43652 10177.4, 10177.2, ! - 0.205078 10186.4, 10185, ! - 1.43652 10207.1, 10205.1, ! - 2.05176 10228, 10224.3, ! - 3.69434 10239.1, 10233.1, ! - 5.95312 10246, 10241.1, ! - 4.92676 10253.6, 10250.6, ! - 3.07812 10265.9, 10260.6, ! - 5.33691 10295.5, 10288.9, ! - 6.56836 10310.4, 10303.9, ! - 6.56836 10319.9, 10313.9, ! - 5.95215 10331, 10327.5, ! - 3.48926 10336.1, 10331.8, ! - 4.31055 10338.8, 10335.1, ! - 3.69434 10343.8, 10338.9, ! - 4.92578 10347.1, 10341.8 , ! - 5.33594 10362.9, 10357.4, ! - 5.54199 10368, 10363.7, ! - 4.31055 10374, 10369.5, ! - 4.51562 10379.3, 10376, ! - 3.28418 10392.7, 10390.2, ! - 2.46289 10396.6, 10392.7, ! - 3.89941 10404.4, 10403.2, ! - 1.23145 10431, 10428.3, ! - 2.66895 10437.2, 10434.5, ! - 2.66797 10441.1, 10440.2, ! - 0.821289 10461.2, 10456.9, ! - 4.31055 10465.1, 10462.4, ! - 2.66895 10469.8, 10465.5, ! - 4.31055 10475.5, 10471.2, ! - 4.31055 10482.5, 10482.9, ! 0.410156 10490.7, 10490.9, ! 0.205078 10495.2, 10494.8, ! - 0.410156 10503.6, 10503.8, ! 0.206055 10509.8, 10509.8, ! 0 10513.5, 10513.7, ! 0.205078 10516.4, 10516.2, ! - 0.205078 10521, 10521.8, ! 0.821289 10577.1, 10573.2, ! - 3.89941 10584.9, 10581.4, ! - 3.48926 10598.7, 10594.3, ! - 4.31055 10622.5, 10618, ! - 4.51562 10628.3, 10626.1, ! - 2.25781 10634.9, 10630.4, ! - 4.51562 10649.1, 10647, ! - 2.05273 10658.5, 10657.7, ! - 0.821289 10694, 10693.6, ! - 0.411133 10700, 10697.7, ! - 2.25781 10708, 10706.1, ! - 1.84766 10713.5, 10711.3, ! - 2.25781 10721.9, 10719.1, ! - 2.87305 10727.7, 10725.2, ! - 2.46289 10731.2, 10728.7, ! - 2.46289 10738.1, 10735.6, ! - 2.46289 10742, 10739.7, ! - 2.25781 10754.9, 10752.9, ! - 2.05273 10767.6, 10766.6, ! - 1.02637 10783.8, 10781.8, ! - 2.05273 10787.3, 10785.1, ! - 2.25781 Page 5 M N tapescan.txt 10790, 10788.2, ! - 1.84766 10792.1, 10790.4, ! - 1.64258 10824.1, 10821.9, ! - 2.25781 10827.6, 10824.6, ! - 3.07812 10831.9, 10829.1, ! - 2.87305 10839.1, 10837.5, ! - 1.6416 10844.9, 10842.6, ! - 2.25781 10851.4, 10848.6, ! - 2.87305 EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape subfile: 1 294 records... Minimum record length: 10 bytes Maximum record length: 132 bytes * * ** FILE HEADER * * ** MWD .001 1024 * ** LIS COMMENT RECORD * ** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 The data presented here is final and has been depth adjusted to a Primary Depth Control (PDC) log provided by schlumberger CH GR dated 25 Mar 2010 per Robert Elliott with BP Exploration (Alaska), Inc. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth scale units: Feet Frame spacing: 0.500000 Frame spacing units: [F Number of frames per record is: 36 one depth per frame (value= 0) Datum Specification Block Sub -type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code samples units size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F /HR 4 4 3 RAD MWD 68 1 OHMM 4 4 Page 6 tapescan.txt 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 1 OHMM 4 4 24 Total Data Records: 113 Tape File start Depth = 8867.500000 Tape File End Depth = 10884.000000 Tape File Level Spacing = 0.500000 Tape File Depth units = feet * * ** FILE TRAILER * * ** Tape subfile: 2 126 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes * * ** FILE HEADER * * ** MWD .002 1024 LIS COMMENT RECORD * ** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 This file contains the raw- unedited field MWD data. FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) optical Log Depth Scale units: Feet Frame spacing: 0.250000 Frame spacing units: [F Number of frames per record is: 36 one depth per frame (value= 0) Datum specification Block sub -type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 curves: Name Tool Code Samples units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F /HR 4 4 3 RAD MWD 68 1 OHMM 4 4 Page 7 M N tapescan.txt 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 1 OHMM 4 4 24 Total Data Records: 225 Tape File Start Depth = 8868.750000 Tape File End Depth = 10887.000000 Tape File Level spacing = 0.250000 Tape File Depth units = feet * * ** FILE TRAILER * * ** Tape subfile: 3 238 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes * * ** TAPE TRAILER * * ** MWD 10/03/23 3073707 O1 * * ** REEL TRAILER * * ** MWD 10/06/21 BHI O1 Tape subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes 0 Tape subfile 1 is type: LIS 0 Tape subfile 2 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 8867.5000 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 Page 8 so tapescan.txt 8868.0000 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 10884.0000 - 999.2500 168.0805 - 999.2500 - 999.2500 - 999.2500 - 999.2500 Tape File Start Depth = 8867.500000 Tape File End Depth = 10884.000000 Tape File Level Spacing = 0.500000 Tape File Depth units = feet 0 Tape subfile 3 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 8868.7500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 8869.0000 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 10887.0000 - 999.2500 158.0000 - 999.2500 - 999.2500 - 999.2500 - 999.2500 Tape File Start Depth = 8868.750000 Tape File End Depth = 10887.000000 Tape File Level spacing = 0.250000 Tape File Depth units = feet Tape subfile 4 is type: LIS Page 9
